10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2022

OR

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

For the transition period from ___________________ to ___________________

Commission	Registrant; State of Incorporation;				I.R.S. Employer
File Number	Address; and Telephone Number				Identification No.
333-21011	FIRSTENERGY CORP.				34-1843785
	(An	Ohio	Corporation)
	76 South Main Street
	Akron		OH	44308
	Telephone		(800)	736-3402

SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:

Title of Each Class	Trading Symbol	Name of Each Exchange on Which Registered
Common Stock, $0.10 par value	FE	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  ☑  No  ☐

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 such files).

Yes  ☑  No  ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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.

Large Accelerated Filer	☑
Accelerated Filer	☐
Non-accelerated Filer	☐
Smaller Reporting Company	☐
Emerging Growth Company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standard 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 Exchange Act).

Yes ☐  No ☑

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:

	OUTSTANDING
CLASS	AS OF MARCH 31, 2022
Common Stock, $0.10 par value	570,932,260

FirstEnergy Website and Other Social Media Sites and Applications

FirstEnergy’s Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, amendments to those reports, and all other documents filed with or furnished to the SEC pursuant to Section 13(a) of the Securities Exchange Act of 1934 are made available free of charge on or through the “Investors” page of FirstEnergy’s website at www.firstenergycorp.com. These documents are also available to the public from commercial document retrieval services and the website maintained by the SEC at www.sec.gov.

These SEC filings are posted on the website as soon as reasonably practicable after they are electronically filed with or furnished to the SEC. Additionally, FirstEnergy routinely posts additional important information, including press releases, investor presentations, investor factbook, and notices of upcoming events under the “Investors” section of FirstEnergy’s website and recognizes FirstEnergy’s website as a channel of distribution to reach public investors and as a means of disclosing material non-public information for complying with disclosure obligations under Regulation FD. Investors may be notified of postings to the website by signing up for email alerts and Rich Site Summary feeds on the “Investors” page of FirstEnergy’s website. FirstEnergy also uses Twitter® and Facebook® as additional channels of distribution to reach public investors and as a supplemental means of disclosing material non-public information for complying with its disclosure obligations under Regulation FD. Information contained on FirstEnergy’s website, Twitter® handle or Facebook® page, and any corresponding applications of those sites, shall not be deemed incorporated into, or to be part of, this report.

Forward-Looking Statements: This Form 10-Q includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 based on information currently available to management. Such statements are subject to certain risks and uncertainties and readers are cautioned not to place undue reliance on these forward-looking statements. These statements include declarations regarding management's intents, beliefs and current expectations. These statements typically contain, but are not limited to, the terms “anticipate,” “potential,” “expect,” "forecast," "target," "will," "intend," “believe,” "project," “estimate," "plan" and similar words. Forward-looking statements involve estimates, assumptions, known and unknown risks, uncertainties and other factors that may cause actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements, which may include the following (see Glossary of Terms for definitions of capitalized terms):

•The potential liabilities, increased costs and unanticipated developments resulting from government investigations and agreements, including those associated with compliance with or failure to comply with the DPA.

•The risks and uncertainties associated with government investigations and audits regarding HB 6 and related matters, including potential adverse impacts on federal or state regulatory matters, including, but not limited to, matters relating to rates.

•The risks and uncertainties associated with litigation, arbitration, mediation, and similar proceedings, particularly regarding HB 6 related matters, including risks associated with obtaining court approval of the definitive settlement agreement in the derivative shareholder lawsuits.

•Weather conditions, such as temperature variations and severe weather conditions, or other natural disasters affecting future operating results and associated regulatory actions or outcomes in response to such conditions.

•Legislative and regulatory developments, including, but not limited to, matters related to rates, compliance and enforcement activity, cybersecurity, and climate change.

•The ability to accomplish or realize anticipated benefits from our FE Forward initiative and our other strategic and financial goals, including, but not limited to, overcoming current uncertainties and challenges associated with the ongoing government investigations, executing our transmission and distribution investment plans, greenhouse gas reduction goals, controlling costs, improving our credit metrics, growing earnings, strengthening our balance sheet, and satisfying the conditions necessary to close the sale of the minority interest in FET.

•The risks associated with cyber-attacks and other disruptions to our, or our vendors’, information technology system, which may compromise our operations, and data security breaches of sensitive data, intellectual property and proprietary or personally identifiable information.

•Mitigating exposure for remedial activities associated with retired and formerly owned electric generation assets.

•The ability to access the public securities and other capital and credit markets in accordance with our financial plans, the cost of such capital and overall condition of the capital and credit markets affecting us, including the increasing number of financial institutions evaluating the impact of climate change on their investment decisions.

•The extent and duration of the COVID-19 pandemic and the related impacts to our business, operations and financial condition resulting from the outbreak of COVID-19 including, but not limited to, disruption of businesses in our territories, supply chain disruptions, additional costs, workforce impacts and governmental and regulatory responses to the pandemic, such as moratoriums on utility disconnections and workforce vaccination mandates.

•Actions that may be taken by credit rating agencies that could negatively affect either our access to or terms of financing or our financial condition and liquidity.

•Changes in assumptions regarding factors such as economic conditions within our territories, the reliability of our transmission and distribution system, or the availability of capital or other resources supporting identified transmission and distribution investment opportunities.

•Changes in customers’ demand for power, including, but not limited to, economic conditions, the impact of climate change, or energy efficiency and peak demand reduction mandates.

•Changes in national and regional economic conditions, including recession and inflationary pressure, affecting us and/or our customers and those vendors with which we do business.

•The potential of non-compliance with debt covenants in our credit facilities.

•The ability to comply with applicable reliability standards and energy efficiency and peak demand reduction mandates.

•Changes to environmental laws and regulations, including, but not limited to, those related to climate change.

•Changing market conditions affecting the measurement of certain liabilities and the value of assets held in our pension trusts, or causing us to make contributions sooner, or in amounts that are larger, than currently anticipated.

•Labor disruptions by our unionized workforce.

•Changes to significant accounting policies.

•Any changes in tax laws or regulations, or adverse tax audit results or rulings.

•The risks and other factors discussed from time to time in our SEC filings.

Dividends declared from time to time on our common stock during any period may in the aggregate vary from prior periods due to circumstances considered by the FE Board at the time of the actual declarations. A security rating is not a recommendation to buy or hold securities and is subject to revision or withdrawal at any time by the assigning rating agency. Each rating should be evaluated independently of any other rating.

These forward-looking statements are also qualified by, and should be read together with, the risk factors included in FirstEnergy’s filings with the SEC, including, but not limited to, the most recent Annual Report on Form 10-K and any subsequent Quarterly Reports on Form 10-Q and Current Reports on Form 8-K. The foregoing review of factors also should not be construed

as exhaustive. New factors emerge from time to time, and it is not possible for management to predict all such factors, nor assess the impact of any such factor on FirstEnergy’s business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statements. FirstEnergy expressly disclaims any obligation to update or revise, except as required by law, any forward-looking statements contained herein or in the information incorporated by reference as a result of new information, future events or otherwise.

TABLE OF CONTENTS

	Page
Part I. Financial Information
Glossary of Terms	ii
Item 1. Financial Statements
FirstEnergy Corp.
Consolidated Statements of Income	1
Consolidated Statements of Comprehensive Income	2
Consolidated Balance Sheets	3
Consolidated Statements of Stockholders’ Equity	4
Consolidated Statements of Cash Flows	5
Notes To Consolidated Financial Statements	6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3. Quantitative and Qualitative Disclosures About Market Risk	64
Item 4. Controls and Procedures	64
Part II. Other Information
Item 1. Legal Proceedings	64
Item 1A. Risk Factors	64
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	64
Item 3. Defaults Upon Senior Securities	64
Item 4. Mine Safety Disclosures	64
Item 5. Other Information	64
Item 6. Exhibits	65

i

GLOSSARY OF TERMS

The following abbreviations and acronyms are used in this report to identify FirstEnergy Corp. and its current and former subsidiaries:

AE Supply	Allegheny Energy Supply Company, LLC, an unregulated generation subsidiary
AGC	Allegheny Generating Company, a generation subsidiary of MP
ATSI	American Transmission Systems, Incorporated, a subsidiary of FET, which owns and operates transmission facilities
CEI	The Cleveland Electric Illuminating Company, an Ohio electric utility operating subsidiary
FE	FirstEnergy Corp., a public utility holding company
FENOC	Energy Harbor Nuclear Corp. (formerly known as FirstEnergy Nuclear Operating Company), a subsidiary of EH, which operates NG’s nuclear generating facilities
FES	Energy Harbor LLC. (formerly known as FirstEnergy Solutions Corp.), a subsidiary of EH, which provides energy-related products and services
FES Debtors	FES, FENOC, FG, NG, FE Aircraft Leasing Corp., Norton Energy Storage LLC, and FGMUC
FESC	FirstEnergy Service Company, which provides legal, financial, and other corporate support services
FET	FirstEnergy Transmission, LLC, the parent company of ATSI, KATCo, MAIT and TrAIL, and has a joint venture in PATH
FEV	FirstEnergy Ventures Corp., which invests in certain unregulated enterprises and business ventures
FG	Energy Harbor Generation LLC (formerly known as FirstEnergy Generation, LLC), a subsidiary of EH, which owns and operates fossil generating facilities
FGMUC	FirstEnergy Generation Mansfield Unit 1 Corp., a subsidiary of FG
FirstEnergy	FirstEnergy Corp., together with its consolidated subsidiaries
Global Holding	Global Mining Holding Company, LLC, a joint venture between FEV, WMB Marketing Ventures, LLC and Pinesdale LLC
Global Rail	Global Rail Group, LLC, a subsidiary of Global Holding that owns coal transportation operations near Roundup, Montana
GPU	GPU, Inc., former parent of JCP&L, ME and PN, that merged with FE on November 7, 2001
GPUN	GPU Nuclear, Inc., a subsidiary of FE, which formerly operated TMI-2
JCP&L	Jersey Central Power & Light Company, a New Jersey electric utility operating subsidiary
KATCo	Keystone Appalachian Transmission Company, a subsidiary of FET
MAIT	Mid-Atlantic Interstate Transmission, LLC, a subsidiary of FET, which owns and operates transmission facilities
ME	Metropolitan Edison Company, a Pennsylvania electric utility operating subsidiary
MP	Monongahela Power Company, a West Virginia electric utility operating subsidiary
NG	Energy Harbor Nuclear Generation LLC (formerly known as FirstEnergy Nuclear Generation, LLC), a subsidiary of EH, which owns nuclear generating facilities
OE	Ohio Edison Company, an Ohio electric utility operating subsidiary
Ohio Companies	CEI, OE and TE
PATH	Potomac-Appalachian Transmission Highline, LLC, a joint venture between FE and a subsidiary of AEP
PATH-Allegheny	PATH Allegheny Transmission Company, LLC
PATH-WV	PATH West Virginia Transmission Company, LLC
PE	The Potomac Edison Company, a Maryland and West Virginia electric utility operating subsidiary
Penn	Pennsylvania Power Company, a Pennsylvania electric utility operating subsidiary of OE
Pennsylvania Companies	ME, PN, Penn and WP
PN	Pennsylvania Electric Company, a Pennsylvania electric utility operating subsidiary
Signal Peak	Signal Peak Energy, LLC, an indirect subsidiary of Global Holding that owns mining operations near Roundup, Montana
TE	The Toledo Edison Company, an Ohio electric utility operating subsidiary
TrAIL	Trans-Allegheny Interstate Line Company, a subsidiary of FET, which owns and operates transmission facilities
Transmission Companies	ATSI, MAIT and TrAIL
Utilities	OE, CEI, TE, Penn, JCP&L, ME, PN, MP, PE, and WP
WP	West Penn Power Company, a Pennsylvania electric utility operating subsidiary

ii

The following abbreviations and acronyms may be used to identify frequently used terms in this report:
2021 Credit Facilities	Collectively, the six separate senior unsecured five-year syndicated revolving credit facilities entered into by FE, FET, the Utilities, and the Transmission Companies, on October 18, 2021	D.C. Circuit	United States Court of Appeals for the District of Columbia Circuit
ACE	Affordable Clean Energy	DMR	Distribution Modernization Rider
ADIT	Accumulated Deferred Income Taxes	DOE	United States Department of Energy
AEP	American Electric Power Company, Inc.	DPA	Deferred Prosecution Agreement entered into on July 21, 2021 between FE and S.D. Ohio
AEPSC	American Electric Power Service Corporation	DPL	Dayton Power & Light
AFS	Available-for-sale	DSIC	Distribution System Improvement Charge
AFUDC	Allowance for Funds Used During Construction	DSP	Default Service Plan
AMI	Advance Metering Infrastructure	DTA	Deferred Tax Asset
AMT	Alternative Minimum Tax	EDC	Electric Distribution Company
AOCI	Accumulated Other Comprehensive Income (Loss)	EE&C	Energy Efficiency and Conservation
ARO	Asset Retirement Obligation	EEI	Edison Electric Institute
ARP	Alternative Revenue Program	EGS	Electric Generation Supplier
ASC	Accounting Standard Codification	EGU	Electric Generation Units
ASU	Accounting Standards Update	EH	Energy Harbor Corp.
Bankruptcy Court	U.S. Bankruptcy Court in the Northern District of Ohio in Akron	EmPOWER Maryland	EmPOWER Maryland Energy Efficiency Act
BGS	Basic Generation Service	ENEC	Expanded Net Energy Cost
Brookfield	North American Transmission Company II LLC, a controlled investment vehicle entity of Brookfield Infrastructure Partners	EPA	United States Environmental Protection Agency
Brookfield Guarantors	Brookfield Super-Core Infrastructure Partners L.P., Brookfield Super-Core Infrastructure Partners (NUS) L.P., and Brookfield Super-Core Infrastructure Partners (ER) SCSp	EPS	Earnings per Share
CAA	Clean Air Act	ERO	Electric Reliability Organization
CCR	Coal Combustion Residuals	ESG	Environmental, Social, Corporate Governance
CERCLA	Comprehensive Environmental Response, Compensation, and Liability Act of 1980	ESP IV	Electric Security Plan IV
CFIUS	Committee on Foreign Investments in the United States	Exchange Act	Securities and Exchange Act of 1934, as amended
CFR	Code of Federal Regulations	Facebook®	Facebook is a registered trademark of Facebook, Inc.
CO2	Carbon Dioxide	FASB	Financial Accounting Standards Board
Code of Business Conduct	The FirstEnergy Code of Business Conduct and Ethics as approved by the FE Board on July 20, 2021	FCA	Financial Conduct Authority
COVID-19	Coronavirus disease	FE Board	FE Board of Directors
CPP	EPA's Clean Power Plan	FE Revolving Facility	FE and the Utilities’ former five-year syndicated revolving credit facility, as amended, and replaced by the 2021 Credit Facilities on October 18, 2021
CSAPR	Cross-State Air Pollution Rule	FERC	Federal Energy Regulatory Committee
CSR	Conservation Support Rider	FES Bankruptcy	FES Debtors' voluntary petitions for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code with the Bankruptcy Court
CTA	Consolidated Tax Adjustment	FET Board	The Board of Directors of FET
CWA	Clean Water Act	FET LLC Agreement	Third Amended and Restated Limited Liability Company Operating Agreement of FET
DCR	Delivery Capital Recovery	FET P&SA	Purchase and Sale Agreement entered into on November 6, 2021, by and between FE, FET, Brookfield and Brookfield Guarantors

iii

FET Revolving Facility	FET and certain of its subsidiaries’ former five-year syndicated revolving credit facility, as amended, and replaced by the 2021 Credit Facilities on October 18, 2021	NSR	New Source Review
Fitch	Fitch Ratings Service	NYPSC	New York State Public Service Commission
FMB	First Mortgage Bond	NUG	Non-Utility Generation
FPA	Federal Power Act	OAG	Ohio Attorney General
FTR	Financial Transmission Right	OCA	Office of Consumer Advocate
GAAP	Accounting Principles Generally Accepted in the United States of America	OCC	Ohio Consumers' Counsel
GHG	Greenhouse Gases	ODSA	Ohio Development Service Agency
HB 6	House Bill 6, as passed by Ohio's 133rd General Assembly	Ohio Stipulation	Stipulation and Recommendation, dated November 1, 2021, entered into by and among the Ohio Companies, the OCC, PUCO Staff, and several other signatories
HB 128	House Bill 128, as passed by Ohio's 134th General Assembly	OPEB	Other Post-Employment Benefits
IBA	ICE Benchmark Administration Limited	OPEIU	Office and Professional Employees International Union
IBEW	International Brotherhood of Electrical Workers	OPIC	Other Paid-in Capital
ICP 2007	FirstEnergy Corp. 2007 Incentive Compensation Plan	OSHA	Occupational Safety and Health Administration
ICP 2015	FirstEnergy Corp. 2015 Incentive Compensation Plan	OVEC	Ohio Valley Electric Corporation
ICP 2020	FirstEnergy Corp. 2020 Incentive Compensation Plan	PA DEP	Pennsylvania Department of Environmental Protection
IRS	Internal Revenue Service	PCRB	Pollution Control Revenue Bond
ISO	Independent System Operator	PIR	Phase-In Recovery Rider
ITC	Investment Tax Credit	PJM	PJM Interconnection, LLC
kV	Kilovolt	PJM Tariff	PJM Open Access Transmission Tariff
KWH	Kilowatt-hour	POLR	Provider of Last Resort
LED	Light Emitting Diode	PPA	Purchase Power Agreement
LIBOR	London Inter-Bank Offered Rate	PPB	Parts per Billion
LOC	Letter of Credit	PPUC	Pennsylvania Public Utility Commission
LSE	Load Serving Entity	PUCO	Public Utilities Commission of Ohio
LTIIPs	Long-Term Infrastructure Improvement Plans	PURPA	Public Utility Regulatory Policies Act of 1978
MDPSC	Maryland Public Service Commission	RCRA	Resource Conservation and Recovery Act
MGP	Manufactured Gas Plants	REC	Renewable Energy Credit
MISO	Midcontinent Independent System Operator, Inc.	Regulation FD	Regulation Fair Disclosure promulgated by the SEC
Moody’s	Moody’s Investors Service, Inc.	RFC	ReliabilityFirst Corporation
MW	Megawatt	RFP	Request for Proposal
MWH	Megawatt-hour	RGGI	Regional Greenhouse Gas Initiative
NAAQS	National Ambient Air Quality Standards	ROE	Return on Equity
NAV	Net Asset Value	RSS	Rich Site Summary
N.D. Ohio	Northern District of Ohio	RTEP	Regional Transmission Expansion Plan
NDT	Nuclear Decommissioning Trust	RTO	Regional Transmission Organization
NERC	North American Electric Reliability Corporation	SBC	Societal Benefits Charge
NJBPU	New Jersey Board of Public Utilities	SCOH	Supreme Court of Ohio
NJ Rate Counsel	New Jersey Division of Rate Counsel	S.D. Ohio	Southern District of Ohio
NOL	Net Operating Loss	SEC	United States Securities and Exchange Commission
NOx	Nitrogen Oxide	SEET	Significantly Excessive Earnings Test
NPDES	National Pollutant Discharge Elimination System	SF6	Sulfur hexafluoride
NRC	Nuclear Regulatory Commission	SIP	State Implementation Plan(s) Under the Clean Air Act

iv

SO2	Sulfur Dioxide	Twitter®	Twitter is a registered trademark of Twitter, Inc.
SLC	Special Litigation Committee of the FE Board	Tax Act	Tax Cuts and Jobs Act adopted December 22, 2017
SOFR	Secured Overnight Financing Rate	TMI-1	Three Mile Island Unit 1
SOS	Standard Offer Service	UWUA	Utility Workers Union of America
SREC	Solar Renewable Energy Credit	VEPCO	Virginia Electric and Power Company
S&P	Standard & Poor’s Ratings Service	VIE	Variable Interest Entity
SSO	Standard Service Offer	VSCC	Virginia State Corporation Commission
TMI-2	Three Mile Island Unit 2	WVPSC	Public Service Commission of West Virginia
TO	Transmission Owner

v

PART I. FINANCIAL INFORMATION

ITEM I.         Financial Statements

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	For the Three Months Ended March 31,
(In millions, except per share amounts)	2022		2021
REVENUES:
Distribution services and retail generation	$	2,397	$	2,236
Transmission	451		401
Other	141		89
Total revenues(1)	2,989		2,726
OPERATING EXPENSES:
Fuel	140		118
Purchased power	875		718
Other operating expenses	820		752
Provision for depreciation	340		323
Amortization (deferral) of regulatory assets, net	(37)		92
General taxes	292		273
Gain on sale of Yards Creek (Note 9)	—		(109)
Total operating expenses	2,430		2,167
OPERATING INCOME	559		559
OTHER INCOME (EXPENSE):
Miscellaneous income, net	106		135
Interest expense	(313)		(285)
Capitalized financing costs	19		13
Total other expense	(188)		(137)
INCOME BEFORE INCOME TAXES	371		422
INCOME TAXES	83		87
NET INCOME	$	288	$	335
EARNINGS PER SHARE OF COMMON STOCK (Note 3):
Basic - Earnings Per Share of Common Stock	$	0.51	$	0.62
Diluted - Earnings Per Share of Common Stock	$	0.50	$	0.62
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic	570		543
Diluted	571		544

(1) Includes excise and gross receipts tax collections of $103 million and $95 million during the three months ended March 31, 2022 and 2021, respectively.

The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.

1

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	For the Three Months Ended March 31,
(In millions)	2022		2021
NET INCOME	$	288	$	335
OTHER COMPREHENSIVE LOSS:
Pension and OPEB prior service costs	(2)		(3)
Other comprehensive loss	(2)		(3)
Income tax benefits on other comprehensive loss	(1)		(1)
Other comprehensive loss, net of tax	(1)		(2)
COMPREHENSIVE INCOME	$	287	$	333

The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.

2

FIRSTENERGY CORP.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions, except share amounts)	March 31, 2022		December 31, 2021
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	283	$	1,462
Restricted cash	27		49
Receivables-
Customers	1,258		1,192
Less — Allowance for uncollectible customer receivables	132		159
	1,126		1,033
Other, net of allowance for uncollectible accounts of $10 in 2022 and 2021	246		246
Materials and supplies, at average cost	273		260
Prepaid taxes and other	295		187
	2,250		3,237
PROPERTY, PLANT AND EQUIPMENT:
In service	46,349		46,002
Less — Accumulated provision for depreciation	12,834		12,672
	33,515		33,330
Construction work in progress	1,481		1,414
	34,996		34,744
INVESTMENTS AND OTHER NONCURRENT ASSETS:
Goodwill	5,618		5,618
Investments (Note 6)	646		655
Regulatory assets	70		71
Other	1,037		1,107
	7,371		7,451
	$	44,617	$	45,432
LIABILITIES AND CAPITALIZATION
CURRENT LIABILITIES:
Currently payable long-term debt	$	1,055	$	1,606
Short-term borrowings	350		—
Accounts payable	1,090		943
Accrued interest	289		283
Accrued taxes	650		647
Accrued compensation and benefits	276		313
Dividends Payable	223		222
Other	427		402
	4,360		4,416
CAPITALIZATION:
Stockholders’ equity-
Common stock, $0.10 par value, authorized 700,000,000 shares - 570,932,260 and 570,261,104 shares outstanding as of March 31, 2022 and December 31, 2021, respectively	57		57
Other paid-in capital	10,031		10,238
Accumulated other comprehensive loss	(16)		(15)
Accumulated deficit	(1,317)		(1,605)
Total stockholders’ equity	8,755		8,675
Long-term debt and other long-term obligations	21,754		22,248
	30,509		30,923
NONCURRENT LIABILITIES:
Accumulated deferred income taxes	3,544		3,437
Retirement benefits	2,620		2,669
Regulatory liabilities	2,025		2,124
Other	1,559		1,863
	9,748		10,093
COMMITMENTS, GUARANTEES AND CONTINGENCIES (Note 8)
	$	44,617	$	45,432

The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.

3

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Unaudited)

	Three Months Ended March 31, 2022
	Common Stock			OPIC		AOCI		Accumulated Deficit		Total Stockholders’ Equity
(In millions)	Shares	Amount
Balance, January 1, 2022	570	$	57	$	10,238	$	(15)	$	(1,605)	$	8,675
Net income								288		288
Other comprehensive loss, net of tax						(1)				(1)
Stock Investment Plan and share-based benefit plans	1			20						20
Cash dividends declared on common stock ($0.39 per share in March)				(223)						(223)
Other				(4)						(4)
Balance, March 31, 2022	571	$	57	$	10,031	$	(16)	$	(1,317)	$	8,755

	Three Months Ended March 31, 2021
	Common Stock			OPIC		AOCI			Accumulated Deficit		Total Stockholders’ Equity
(In millions)	Shares	Amount
Balance, January 1, 2021	543	$	54	$	10,076	$	(5)	0	$	(2,888)	$	7,237
Net income									335		335
Other comprehensive loss, net of tax						(2)					(2)
Share-based benefit plans	1			2							2
Cash dividends declared on common stock ($0.39 per share in March)				(212)							(212)
Balance, March 31, 2021	544	$	54	$	9,866	$	(7)		$	(2,553)	$	7,360

The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.

4

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
(In millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	288	$	335
Adjustments to reconcile net income to net cash from operating activities-
Depreciation and amortization	359		454
Deferred income taxes and investment tax credits, net	77		82
Retirement benefits, net of payments	(96)		(105)
Gain on sale of Yards Creek	—		(109)
Changes in current assets and liabilities-
Receivables	(93)		161
Materials and supplies	(13)		14
Prepaid taxes and other current assets	(105)		(121)
Accounts payable	147		43
Accrued taxes	(133)		(127)
Accrued interest	6		7
Accrued compensation and benefits	(106)		(129)
Other current liabilities	10		(7)
Other	14		35
Net cash provided from operating activities	355		533
CASH FLOWS FROM FINANCING ACTIVITIES:
New financing-
Long-term debt	—		500
Short-term borrowings, net	350		—
Redemptions and repayments-
Long-term debt	(1,046)		(29)
Short-term borrowings, net	—		(750)
Make-whole premiums paid on debt redemptions	(38)		—
Common stock dividend payments	(222)		(212)
Other	(8)		(18)
Net cash used for financing activities	(964)		(509)
CASH FLOWS FROM INVESTING ACTIVITIES:
Property additions	(520)		(604)
Proceeds from sale of Yards Creek	—		155
Sales of investment securities held in trusts	6		5
Purchases of investment securities held in trusts	(9)		(7)
Asset removal costs	(49)		(47)
Other	(20)		(1)
Net cash used for investing activities	(592)		(499)
Net change in cash, cash equivalents, and restricted cash	(1,201)		(475)
Cash, cash equivalents, and restricted cash at beginning of period	1,511		1,801
Cash, cash equivalents, and restricted cash at end of period	$	310	$	1,326

The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.

5

FIRSTENERGY CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note Number		Page Number
1	Organization and Basis of Presentation	7
2	Revenue	9
3	Earnings Per Share of Common Stock	11
4	Pension and Other Post-Employment Benefits	12
5	Income Taxes	12
6	Fair Value Measurements	13
7	Regulatory Matters	15
8	Commitments, Guarantees and Contingencies	22
9	Segment Information	27

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

1. ORGANIZATION AND BASIS OF PRESENTATION

Unless otherwise indicated, defined terms and abbreviations used herein have the meanings set forth in the accompanying Glossary of Terms.

FE was incorporated under Ohio law in 1996. FE’s principal business is the holding, directly or indirectly, of all of the outstanding equity of its principal subsidiaries: OE, CEI, TE, Penn (a wholly owned subsidiary of OE), JCP&L, ME, PN, FESC, MP, AGC (a wholly owned subsidiary of MP), PE, WP, and FET and its principal subsidiaries (ATSI, MAIT and TrAIL). In addition, FE holds all of the outstanding equity of other direct subsidiaries including: AE Supply, FirstEnergy Properties, Inc., FEV, FirstEnergy License Holding Company, GPUN, Allegheny Ventures, Inc., and Suvon, LLC, doing business as both FirstEnergy Home and FirstEnergy Advisors.

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity. FirstEnergy’s ten utility operating companies comprise one of the nation’s largest investor-owned electric systems, based on serving over six million customers in the Midwest and Mid-Atlantic regions. FirstEnergy’s transmission operations include approximately 24,000 miles of lines and two regional transmission operation centers. AGC and MP control 3,580 MWs of total capacity.

PN, as lessee of the property of its subsidiary, the Waverly Electric Light & Power Company, serves approximately 4,000 customers in the Waverly, New York vicinity. On February 10, 2021, PN entered into an agreement to transfer its customers and the related assets in Waverly, New York to Tri-County Rural Electric Cooperative; the completion of such transfer is subject to several closing conditions including regulatory approval, which are ongoing.

These interim financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and disclosures normally included in financial statements and notes prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. These interim financial statements should be read in conjunction with the financial statements and notes included in the Annual Report on Form 10-K for the year ended December 31, 2021.

FE and its subsidiaries follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The accompanying interim financial statements are unaudited, but reflect all adjustments, consisting of normal recurring adjustments, that, in the opinion of management, are necessary for a fair statement of the financial statements. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of operations for any future period. FE and its subsidiaries have evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued.

FE and its subsidiaries consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. FE and its subsidiaries consolidate a VIE when it is determined that it is the primary beneficiary. Investments in affiliates over which FE and its subsidiaries have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported as an investment in the Consolidated Balance Sheets and the percentage of FE’s ownership share of the entity’s earnings is reported in the Consolidated Statements of Income and Comprehensive Income.

Certain prior year amounts have been reclassified to conform to the current year presentation.

Capitalized Financing Costs

For the three months ended March 31, 2022 and 2021, capitalized financing costs on FirstEnergy’s Consolidated Statements of Income include $13 million and $7 million, respectively, of allowance for equity funds used during construction and $6 million of capitalized interest in both periods.

COVID-19

FirstEnergy is continuously evaluating the COVID-19 global pandemic and taking steps to mitigate known risks. FirstEnergy provides a critical and essential service to its customers and the health and safety of its employees and customers is its first priority. FirstEnergy continues to provide flexibility for approximately 7,000 of its 12,400 employees to work from home. Pandemic safety and cleaning protocols were implemented for those workers who have continued to report to a FirstEnergy work location during the pandemic, ensuring FirstEnergy employees can report directly to job sites and work with the same small group of employees every day. FirstEnergy continues to assess its work from home policies to allow for a flexible workplace to continue for its employees after the pandemic.

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FirstEnergy continues to effectively manage operations during the pandemic in order to provide critical service to customers. FirstEnergy has experienced supply chain challenges during the COVID-19 pandemic. Lead times have increased across numerous material categories, with some as much as doubling from previous times. Some key suppliers have struggled with labor shortages and raw material availability, which along with increasing inflationary pressure, have increased the costs of certain materials, equipment and contractors. FirstEnergy has taken steps to mitigate these risks and does not currently expect service disruptions or any material impact on its capital spending plan. However, the situation remains fluid and future impacts to FirstEnergy that are presently unknown or unanticipated may occur.

Customer Receivables

Receivables from customers include distribution services and retail generation sales to residential, commercial and industrial customers of the Utilities. The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for credit losses.

FirstEnergy reviews its allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Utilities are able to utilize to ensure payment. This analysis includes consideration of the outbreak of COVID-19 and the impact on customer receivable balances outstanding and write-offs since the pandemic began. During the first quarter of 2022, various regulatory actions including extensions on moratoriums, certain restrictions on disconnections, and extended installment plan offerings continue to impact the level of past due balances in certain states. However, certain states have resumed normal collections activity and arrears levels have declined towards pre-pandemic levels. As a result of this analysis, FirstEnergy recognized a $25 million decrease to its allowance for uncollectible customer receivables during the first quarter of 2022, of which $15 million was applied to existing deferred regulatory assets. Additionally, as a result of these pandemic-related moratoriums and certain customer installment or extended payment plans offered, the allowance for uncollectible accounts on receivables in 2022 continue to be elevated due to the extension of when certain write-offs would have otherwise occurred.

Receivables from customers also include PJM receivables resulting from transmission and wholesale sales. FirstEnergy’s uncollectible risk on PJM receivables is minimal due to the nature of PJM’s settlement process whereby members of PJM legally agree to share the cost of defaults and as a result there is no allowance for doubtful accounts.

Activity in the allowance for uncollectible accounts on customer receivables for the three months ended March 31, 2022 and for the year ended December 31, 2021 are as follows:

	(In millions)
Balance, January 1, 2021	$	164
Charged to income (1)	54
Charged to other accounts (2)	42
Write-offs	(101)
Balance, December 31, 2021	$	159
Charged to income(3)	(5)
Charged to other accounts (2)	39
Write-offs	(61)
Balance, March 31, 2022	$	132

(1) $12 million of which was deferred for future recovery in the twelve months ended December 31, 2021.

(2) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.

(3) $(11) million of which was deferred for future refund to customers in the three months ended March 31, 2022.

Sale of Minority Interest in FirstEnergy Transmission, LLC

On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA, with Brookfield and Brookfield Guarantors, pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. KATCo, which is currently a subsidiary of FET, will become a wholly owned subsidiary of FE prior to the closing of the transaction and will remain in the Regulated Transmission segment. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. On January 5, 2022, the parties to this transaction submitted an application to FERC requesting approval of the transaction no later than April 30, 2022. On April 14, 2022, CFIUS notified FET and Brookfield that it has determined that there were no unresolved national security issues and its review of the transaction was concluded. On April 21, 2022, FERC approved the matter. The transaction is now expected to close at the end of May 2022.

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Pursuant to the terms of the FET P&SA, in connection with the closing, Brookfield, FET and FirstEnergy Corp will enter into the FET LLC Agreement. The FET LLC Agreement, among other things, provides for the governance, exit, capital and distribution, and other arrangements for FET from and following the closing. Under the FET LLC Agreement, Brookfield will be entitled to appoint a number of directors to the FET Board, in approximate proportion to Brookfield’s ownership percentage in FET (rounded to the next whole number). Upon the closing, the FET Board will consist of five directors, one appointed by Brookfield and four appointed by FE. The FET LLC Agreement contains certain investor protections, including, among other things, requiring Brookfield's approval for FET and its subsidiaries to take certain major actions. Under the terms of the FET LLC Agreement, for so long as Brookfield holds a 9.9% interest in FET, Brookfield’s consent is required for FET or any of its subsidiaries to incur indebtedness (other than the refinancing of existing indebtedness on commercially reasonable terms reflecting then-current credit market conditions) that would reasonably be expected to result in FET’s consolidated Debt-to-Capital Ratio (as defined in the FET LLC Agreement) equaling or exceeding (i) prior to the fifth anniversary of the effective date, 65%, and (ii) thereafter, 70%.

New Accounting Pronouncements

Recently Issued Pronouncements - FirstEnergy has assessed new authoritative accounting guidance issued by the FASB that has not yet been adopted and none are currently expected to have a material impact to the financial statements.

2. REVENUE

FirstEnergy accounts for revenues from contracts with customers under ASC 606, “Revenue from Contracts with Customers.” Revenue from leases, financial instruments, other contractual rights or obligations and other revenues that are not from contracts with customers are outside the scope of the standard and accounted for under other existing GAAP.

FirstEnergy has elected to exclude sales taxes and other similar taxes collected on behalf of third parties from revenue as prescribed in the standard. As a result, tax collections and remittances are excluded from recognition in the income statement and instead recorded through the balance sheet. Excise and gross receipts taxes that are assessed on FirstEnergy are not subject to the election and are included in revenue. FirstEnergy has elected the optional invoice practical expedient for most of its revenues and utilizes the optional short-term contract exemption for transmission revenues due to the annual establishment of revenue requirements, which eliminates the need to provide certain revenue disclosures regarding unsatisfied performance obligations.

FirstEnergy’s revenues are primarily derived from electric service provided by the Utilities and Transmission Companies.

The following represents a disaggregation of revenue from contracts with customers for the three months ended March 31, 2022 and 2021:

	For the Three Months Ended March 31, 2022
Revenues by Type of Service	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments (1)		Total
	(In millions)
Distribution services	$	1,348	$	—	$	(28)	$	1,320
Retail generation	1,094		—		(17)		1,077
Wholesale sales	90		—		6		96
Transmission	—		451		—		451
Other	26		—		—		26
Total revenues from contracts with customers	$	2,558	$	451	$	(39)	$	2,970
Other revenue unrelated to contracts with customers	31		2		(14)		19
Total revenues	$	2,589	$	453	$	(53)	$	2,989

(1) Includes eliminations and reconciling adjustments of inter-segment revenues.

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	For the Three Months Ended March 31, 2021
Revenues by Type of Service	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments (1)		Total
	(In millions)
Distribution services	$	1,339	$	—	$	(26)	$	1,313
Retail generation	935		—		(12)		923
Wholesale sales	69		—		4		73
Transmission	—		401		—		401
Other	33		—		—		33
Total revenues from contracts with customers	$	2,376	$	401	$	(34)	$	2,743
ARP (2)	(27)		—		—		(27)
Other revenue unrelated to contracts with customers	21		4		(15)		10
Total revenues	$	2,370	$	405	$	(49)	$	2,726

(1) Includes eliminations and reconciling adjustments of inter-segment revenues.

(2) Reflects amount the Ohio Companies refunded to customers that was previously collected under decoupling mechanisms, with interest. See Note 7, “Regulatory Matters,” for further discussion on Ohio decoupling rates.

Other revenue unrelated to contracts with customers includes revenue from late payment charges of $10 million and $9 million for the three months ended March 31, 2022 and 2021, respectively. Other revenue unrelated to contracts with customers also includes revenue from derivatives of $9 million for the three months ended March 31, 2022.

Regulated Distribution

The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies and also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. Each of the Utilities earns revenue from state-regulated rate tariffs under which it provides distribution services to residential, commercial and industrial customers in its service territory. The Utilities are obligated under the regulated construct to deliver power to customers reliably, as it is needed, which creates an implied monthly contract with the end-use customer. See Note 7, “Regulatory Matters,” for additional information on rate recovery mechanisms. Distribution and electric revenues are recognized over time as electricity is distributed and delivered to the customer and the customers consume the electricity immediately as delivery occurs.

Retail generation sales relate to POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey and Maryland, as well as generation sales in West Virginia that are regulated by the WVPSC. Certain of the Utilities have default service obligations to provide power to non-shopping customers who have elected to continue to receive service under regulated retail tariffs. The volume of these sales varies depending on the level of shopping that occurs. Supply plans vary by state and by service territory. Default service for the Ohio Companies, Pennsylvania Companies, JCP&L and PE’s Maryland jurisdiction are provided through a competitive procurement process approved by each state’s respective commission. Retail generation revenues are recognized over time as electricity is delivered and consumed immediately by the customer.

The following table represents a disaggregation of the Regulated Distribution segment revenue from contracts with distribution service and retail generation customers for the three months ended March 31, 2022 and 2021, by class:

	For the Three Months Ended March 31,
Revenues by Customer Class	2022		2021
	(In millions)
Residential	$	1,542	$	1,457
Commercial	597		541
Industrial	283		258
Other	20		18
Total Revenues	$	2,442	$	2,274

Wholesale sales primarily consist of generation and capacity sales into the PJM market from FirstEnergy’s regulated electric generation capacity and NUGs. Certain of the Utilities may also purchase power in the PJM markets to supply power to their customers. Generally, these power sales from generation and purchases to serve load are netted hourly and reported as either revenues or purchased power on the Consolidated Statements of Income based on whether the entity was a net seller or buyer

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each hour. Capacity revenues are recognized ratably over the PJM planning year at prices cleared in the annual PJM Reliability Pricing Model Base Residual Auction and Incremental Auctions. Capacity purchases and sales through PJM capacity auctions are reported within revenues on the Consolidated Statements of Income. Certain capacity income (bonuses) and charges (penalties) related to the availability of units that have cleared in the auctions are unknown and not recorded in revenue until, and unless, they occur.

The Utilities’ distribution customers are metered on a cycle basis. An estimate of unbilled revenues is calculated to recognize electric service provided from the last meter reading through the end of the month. This estimate includes many factors, among which are historical customer usage, load profiles, estimated weather impacts, customer shopping activity and prices in effect for each class of customer. In each accounting period, the Utilities accrue the estimated unbilled amount as revenue and reverse the related prior period estimate. Customer payments vary by state but are generally due within 30 days.

ASC 606 excludes industry-specific accounting guidance for recognizing revenue from ARPs as these programs represent contracts between the utility and its regulators, as opposed to customers. Therefore, revenues from these programs are not within the scope of ASC 606 and regulated utilities are permitted to continue to recognize such revenues in accordance with existing practice but are presented separately from revenue arising from contracts with customers. FirstEnergy had ARPs in Ohio and has reflected refunds of decoupling revenue owed to customers as reductions to ARPs in 2021. Please see Note 7, “Regulatory Matters,” for further discussion on decoupling revenues in Ohio.

Regulated Transmission

The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission Companies and certain of FirstEnergy's utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to distribution facilities. The segment's revenues are derived from forward-looking formula rates. See Note 7, “Regulatory Matters,” for additional information.

Forward-looking formula rates recover costs that the regulatory agencies determine are permitted to be recovered and provide a return on transmission capital investment. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual costs. Revenues and cash receipts for the stand-ready obligation of providing transmission service are recognized ratably over time.

The following table represents a disaggregation of revenue from contracts with regulated transmission customers for the three months ended March 31, 2022 and 2021, by transmission owner:

	For the Three Months Ended March 31,
Transmission Owner	2022		2021
	(In millions)
ATSI	217		$	206
TrAIL	63		59
MAIT	79		67
JCP&L	60		36
MP, PE and WP	32		33
Total Revenues	$	451	$	401

3. EARNINGS PER SHARE OF COMMON STOCK

Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised.

Diluted EPS reflects the dilutive effect of potential common shares from share-based awards. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average market price for the period.

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The following table reconciles basic and diluted EPS of common stock:

	For the Three Months Ended March 31,
Reconciliation of Basic and Diluted EPS	2022		2021
(In millions, except per share amounts)
Net Income	$	288	$	335
Share count information:
Weighted average number of basic shares outstanding	570		543
Assumed exercise of dilutive stock options and awards	1		1
Weighted average number of diluted shares outstanding	571		544
EPS of Common Stock:
Basic EPS of common stock	$	0.51	$	0.62
Diluted EPS of common stock	$	0.50	$	0.62

For the three months ended March 31, 2022 and March 31, 2021, no shares from stock options and awards were excluded from the calculation of diluted shares outstanding, as their inclusion would have been antidilutive.

4. PENSION AND OTHER POST-EMPLOYMENT BENEFITS

The components of the consolidated net periodic costs (credits) for pension and OPEB were as follows:

Components of Net Periodic Benefit Costs (Credits)	Pension				OPEB
For the Three Months Ended March 31,	2022		2021		2022		2021
	(In millions)
Service costs	$	46	$	49	$	1	$	1
Interest costs	68		56		3		3
Expected return on plan assets	(164)		(163)		(10)		(10)
Amortization of prior service costs (credits)(1)	1		1		(3)		(4)
Net periodic credits, including amounts capitalized	$	(49)	$	(57)	$	(9)	$	(10)
Net periodic credits, recognized in earnings	$	(69)	$	(78)	$	(9)	$	(10)

(1) The income tax benefits associated with pension and OPEB prior service costs amortized out of AOCI were $1 million as of March 31, 2022 and 2021.

On March 11, 2021, President Biden signed into law the American Rescue Plan Act of 2021, which among other things, extended shortfall amortization periods and modification of the interest rate stabilization rules for single-employer plans thereby impacting funding requirements. As a result, FirstEnergy does not currently expect to have a required contribution to the pension plan based on various assumptions, including annual expected rate of returns for assets of 7.5%. However, FirstEnergy may elect to contribute to the pension plan voluntarily.

Service costs, net of capitalization, are reported within Other operating expenses on FirstEnergy’s Consolidated Statements of Income. Non-service costs, other than the pension and OPEB mark-to-market adjustment, which is separately shown, are reported within Miscellaneous income, net, within Other Income (Expense) on FirstEnergy’s Consolidated Statements of Income.

5. INCOME TAXES

FirstEnergy’s interim effective tax rates reflect the estimated annual effective tax rates for 2022 and 2021. These tax rates are affected by estimated annual permanent items, such as AFUDC equity and other flow-through items, as well as discrete items that may occur in any given period but are not consistent from period to period.

FirstEnergy’s effective tax rate on continuing operations for the three months ended March 31, 2022 and 2021, was 22.4% and 20.6%, respectively. The change in effective tax rate was primarily due to a valuation allowance against certain municipal deferred tax assets.

In February 2022, the IRS completed its examination of FirstEnergy’s 2020 federal income tax return and issued a Full Acceptance Letter with no adjustment to FirstEnergy’s taxable income. There was no material change to FirstEnergy’s reserve for uncertain tax positions for the first three months ended March 31, 2022, and it remains reasonably possible that

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approximately $31 million of unrecognized tax benefits may be resolved in the next twelve months as a result of settlements with taxing authorities or the statute of limitations expiring, of which $24 million would ultimately affect FirstEnergy’s effective tax rate.

6. FAIR VALUE MEASUREMENTS

RECURRING FAIR VALUE MEASUREMENTS

Authoritative accounting guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to Level 1 measurements and the lowest priority to Level 3 measurements. The three levels of the fair value hierarchy and a description of the valuation techniques are as follows:

Level 1	-	Quoted prices for identical instruments in active market.
Level 2	-	Quoted prices for similar instruments in active market.
	-	Quoted prices for identical or similar instruments in markets that are not active.
	-	Model-derived valuations for which all significant inputs are observable market data.

Models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.

Level 3 - Valuation inputs are unobservable and significant to the fair value measurement.

FirstEnergy produces a long-term power and capacity price forecast annually with periodic updates as market conditions change. When underlying prices are not observable, prices from the long-term price forecast are used to measure fair value.

FTRs are financial instruments that entitle the holder to a stream of revenues (or charges) based on the hourly day-ahead congestion price differences across transmission paths. FTRs are acquired by FirstEnergy in the annual, monthly and long-term PJM auctions and are initially recorded using the auction clearing price less cost. After initial recognition, FTRs’ carrying values are periodically adjusted to fair value using a mark-to-model methodology, which approximates market. The primary inputs into the model, which are generally less observable than objective sources, are the most recent PJM auction clearing prices and the FTRs’ remaining hours. The model calculates the fair value by multiplying the most recent auction clearing price by the remaining FTR hours less the prorated FTR cost. Significant increases or decreases in inputs in isolation may have resulted in a higher or lower fair value measurement.

FirstEnergy primarily applies the market approach for recurring fair value measurements using the best information available. Accordingly, FirstEnergy maximizes the use of observable inputs and minimizes the use of unobservable inputs. There were no changes in valuation methodologies used as of March 31, 2022, from those used as of December 31, 2021. The determination of the fair value measures takes into consideration various factors, including but not limited to, nonperformance risk, counterparty credit risk and the impact of credit enhancements (such as cash deposits, LOCs and priority interests). The impact of these forms of risk was not significant to the fair value measurements.

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The following tables set forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy:

	March 31, 2022								December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(In millions)
Derivative assets FTRs(1)	$	—	$	—	$	1	$	1	$	—	$	—	$	9	$	9
Equity securities	2		—		—		2		2		—		—		2
U.S. state debt securities	—		258		—		258		—		273		—		273
Cash, cash equivalents and restricted cash(2)	310		—		—		310		1,511		—		—		1,511
Other(3)	—		45		—		45		—		42		—		42
Total assets	$	312	$	303	$	1	$	616	$	1,513	$	315	$	9	$	1,837
Liabilities
Derivative liabilities FTRs(1)	$	—	$	—	$	—	$	—	$	—	$	—	$	(1)	$	(1)
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	—	$	(1)	$	(1)
Net assets (liabilities)	$	312	$	303	$	1	$	616	$	1,513	$	315	$	8	$	1,836

(1)Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.

(2)Restricted cash of $27 million and $49 million as of March 31, 2022 and December 31, 2021 respectively, primarily relates to cash collected from MP, PE and the Ohio Companies’ customers that is specifically used to service debt of their respective securitization or funding companies.

(3)Primarily consists of short-term investments.

Level 3 Quantitative Information

The following table provides quantitative information for FTRs contracts that are classified as Level 3 in the fair value hierarchy for the period ended March 31, 2022:

	Fair Value, Net (In millions)		Valuation Technique	Significant Input	Range					Weighted Average	Units
FTRs	$	1	Model	RTO auction clearing prices	$	0.20	to	$	4.00	$0.90	Dollars/MWH

INVESTMENTS

All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash equivalents include equity securities, AFS debt securities and other investments. FirstEnergy has no debt securities held for trading purposes.

Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on AFS debt securities are recognized in AOCI. However, the spent nuclear fuel disposal trusts of JCP&L, ME and PN are subject to regulatory accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets.

Spent Nuclear Fuel Disposal Trusts

JCP&L holds debt securities within the spent nuclear fuel disposal trust, which are classified as AFS securities, recognized at fair market value. The trust is intended for funding spent nuclear fuel disposal fees to the DOE associated with the previously owned Oyster Creek and TMI-1 nuclear power plants.

The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held in spent nuclear fuel disposal trusts as of March 31, 2022, and December 31, 2021:

	March 31, 2022(1)								December 31, 2021(2)
	Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value		Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value
	(In millions)
Debt securities	$	279	$	—	$	(21)	$	258	$	280	$	2	$	(9)	$	273

(1) Excludes short-term cash investments of $13 million.

    (2) Excludes short-term cash investments of $11 million.

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Proceeds from the sale of investments in AFS debt securities, realized gains and losses on those sales and interest and dividend income for the three months ended March 31, 2022 and 2021, were as follows:

	For the Three Months Ended March 31,
	2022		2021
	(In millions)
Sale proceeds	$	6	$	5
Realized gains	—		—
Realized losses	(1)		—
Interest and dividend income	3		3

Other Investments

Other investments include employee benefit trusts, which are primarily invested in corporate-owned life insurance policies and equity method investments. Other investments were $375 million and $371 million as of March 31, 2022, and December 31, 2021, respectively, and are excluded from the amounts reported above.

LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS

All borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature, FirstEnergy believes that their costs approximate their fair market value. The following table provides the approximate fair value and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance costs, unamortized fair value adjustments, premiums and discounts as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	(In millions)
Carrying value	$	22,900	$	23,946
Fair value	$	23,754	$	27,043

The fair values of long-term debt and other long-term obligations reflect the present value of the cash outflows relating to those securities based on the current call price, the yield to maturity or the yield to call, as deemed appropriate at the end of each respective period. The yields assumed were based on securities with similar characteristics offered by corporations with credit ratings similar to those of FirstEnergy. FirstEnergy classified short-term borrowings, long-term debt and other long-term obligations as Level 2 in the fair value hierarchy as of March 31, 2022, and December 31, 2021.

In December 2021, notice of redemption was provided for all remaining $850 million of FE’s 4.25% Notes, Series B, due 2023, which was completed on January 20, 2022, with a make-whole premium of approximately $38 million.

On January 27, 2022, CEI instructed its indenture trustee to provide notice of redemption for all remaining $150 million of CEI’s 2.77% Senior Notes, Series A, due 2034, for redemption which occurred on March 14, 2022.

Also on January 27, 2022, TE instructed its indenture trustee to provide notice of partial redemption for $25 million of TE’s 2.65% Senior Secured Notes, due 2028, for partial redemption which occurred on February 11, 2022.

7. REGULATORY MATTERS

STATE REGULATION

Each of the Utilities' retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE in Virginia, ATSI in Ohio, and the Transmission Companies in Pennsylvania are subject to certain regulations of the VSCC, PUCO and PPUC, respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and operate the new transmission facility.

MARYLAND

PE operates under MDPSC approved base rates that were effective as of March 23, 2019. PE also provides SOS pursuant to a combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively

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procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS. PE expects to file a new base rate case in early 2023, consistent with the MDPSC’s order issued on March 22, 2019.

The EmPOWER Maryland program requires each electric utility to file a plan to reduce electric consumption and demand 0.2% per year, up to the ultimate goal of 2% annual savings, for the duration of the 2021-2023 EmPOWER Maryland program cycles to the extent the MDPSC determines that cost-effective programs and services are available. PE's approved 2021-2023 EmPOWER Maryland plan continues and expands upon prior years' programs for a projected total investment of approximately $148 million over the three-year period. PE recovers program investments with a return through an annually reconciled surcharge, with most costs subject to recovery over a five-year period with a return on the unamortized balance. Maryland law only allows for the utility to recover lost distribution revenue attributable to energy efficiency or demand reduction programs through a base rate case proceeding, and to date, such recovery has not been sought or obtained by PE.

NEW JERSEY

JCP&L operates under NJBPU approved rates that were effective for customers as of November 1, 2021. JCP&L provides BGS for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from customers as a charge separate from base rates.

JCP&L has instituted energy efficiency and peak demand reduction programs in accordance with the New Jersey Clean Energy Act as approved by the NJBPU in April 2021. The NJBPU approved plans include recovery of lost revenues resulting from the programs and a three-year plan including total program costs of $203 million, of which $158 million of investment is recovered over a ten-year amortization period with a return as well as operations and maintenance expenses and financing costs of $45 million recovered on an annual basis.

In December 2017, the NJBPU issued proposed rules to modify its current CTA policy in base rate cases to: (i) calculate savings using a five-year look back from the beginning of the test year; (ii) allocate savings with 75% retained by the company and 25% allocated to customers; and (iii) exclude transmission assets of electric distribution companies in the savings calculation. On January 17, 2019, the NJBPU approved the proposed CTA rules with no changes. On May 17, 2019, the NJ Rate Counsel filed an appeal with the Appellate Division of the Superior Court of New Jersey and on June 7, 2021, the Superior Court issued an order reversing the NJBPU’s CTA rules and remanded the case back to the NJBPU. Specifically, the Court’s ruling requires 100% of the CTA savings to be credited to customers in lieu of the NJBPU’s current policy requiring 25%. On December 6, 2021, the NJBPU issued proposed amended rules modifying its current CTA policy in base rate cases consistent with the Superior Court’s June 7, 2021 order. Comments were filed on March 3, 2022. Once the proposed rules are final, they will be applied on a prospective basis in a future base rate case, however, it is not expected to have a material adverse effect on FirstEnergy’s results or financial condition.

On October 28, 2020, the NJBPU approved a stipulated settlement between JCP&L and various parties, resolving JCP&L’s request for distribution base rate increase. The settlement provided for a $94 million annual base distribution revenues increase for JCP&L based on an ROE of 9.6%, which became effective for customers on November 1, 2021. The settlement additionally provided that JCP&L would be subject to a management audit. The management audit began in May 2021 and is currently ongoing.

On August 27, 2020, JCP&L filed an AMI Program with the NJBPU, which proposed the deployment of approximately 1.2 million advanced meters over a three-year period beginning on January 1, 2023, at a total cost of approximately $418 million, including the pre-deployment phase. The then proposed 3-year deployment was part of the 20-year AMI Program that was projected to cost approximately $732 million and proposed a cost recovery mechanism through a separate AMI tariff rider. On September 14, 2021, JCP&L submitted a supplemental filing, which reflected increases in the AMI Program’s costs. Under the revised AMI Program, during the first six years of the AMI Program from 2022 through 2027, JCP&L estimates costs of $494 million, consisting of capital expenditures of approximately $390 million, incremental operations and maintenance expenses of approximately $73 million and cost of removal of $31 million. On February 8, 2022, JCP&L filed with the NJBPU a stipulation entered into with the NJBPU staff, NJ Rate Counsel and others, that, pending NJBPU approval, would affirm the terms of the revised AMI Program. The Stipulation, which was approved by NJBPU order on February 23, 2022, also provides that the revised AMI Program-related capital costs, the legacy meter stranded costs, and the operations and maintenance expense will be deferred and placed in regulatory assets, with such amounts sought to be recovered in the JCP&L’s subsequent base rate cases.

On July 2, 2020, the NJBPU issued an order allowing New Jersey utilities to track and create a regulatory asset for future recovery of all prudently incurred incremental costs arising from the COVID-19 pandemic beginning March 9, 2020 and continuing until the New Jersey Governor issues an order stating that the COVID-19 pandemic is no longer in effect. New Jersey utilities can request recovery of such regulatory asset in a stand-alone COVID-19 regulatory asset filing or future base rate case. On October 28, 2020, the NJBPU issued an order expanding the scope of the proceeding to examine all pandemic issues, including recovery of the COVID-19 regulatory assets, by way of a generic proceeding. Through various executive orders issued

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by the New Jersey Governor, the moratorium period was extended to December 31, 2021. On December 21, 2021, the moratorium on residential disconnections for certain entities providing utility service was extended until March 15, 2022. The moratorium on residential disconnections was not extended for investor-owned electric utilities such as JCP&L, but does require that investor-owned electric public utilities offer qualifying residential customers deferred payment arrangements meeting certain minimum criteria prior to disconnecting service. Additionally, while the moratorium on residential disconnections for certain entities providing electric service was not extended after March 15, 2022, new legislation was enacted on March 25, 2022, prohibiting utilities from disconnecting electric service to customers that have applied for utility bill assistance before June 15, 2022 until such time as the state agency administering the assistance program makes a decision on the application and further requiring that all utilities offer a deferred payment arrangement meeting certain minimum criteria after the state agency’s decision on the application has been made.

Pursuant to an NJBPU order requiring all New Jersey electric distribution companies to file electric vehicle programs, JCP&L filed its program on March 1, 2021. JCP&L’s proposed electric vehicle program consisted of six sub-programs, including a consumer education and outreach initiative that would begin on January 1, 2022, and continue over a four-year period. The total proposed budget for the electric vehicle program is approximately $50 million, including investments of $16 million and operations and maintenance expenses of $34 million. JCP&L is proposing to recover the electric vehicle program costs via a non-bypassable rate clause applicable to all distribution customer rate classes, which became effective on January 1, 2022. On May 26, 2021, a procedural schedule was set to include evidentiary hearings the week of October 18, 2021. On July 16, 2021, the procedural schedule was extended by thirty days as requested by JCP&L to continue settlement discussions. On August 19, 2021, the presiding commissioner issued an order modifying the procedural schedule by extending the procedural schedule by ninety days as requested by JCP&L to continue settlement discussions. On November 12, 2021, JCP&L filed a letter with the presiding commissioner requesting a suspension of the procedural schedule in order to allow the parties to continue settlement discussion. On November 23, 2021, the presiding commissioner entered an order suspending the procedural schedule. JCP&L expects an order from the NJBPU by the end of the second quarter of 2022.

OHIO

The Ohio Companies operate under PUCO approved base distribution rates that became effective in 2009. The Ohio Companies currently operate under ESP IV, effective June 1, 2016 and continuing through May 31, 2024, that continues the supply of power to non-shopping customers at a market-based price set through an auction process. ESP IV also continues the Rider DCR, which supports continued investment related to the distribution system for the benefit of customers, with increased revenue caps of $20 million per year from June 1, 2019 through May 31, 2022; and $15 million per year from June 1, 2022 through May 31, 2024. In addition, ESP IV includes: (1) continuation of a base distribution rate freeze through May 31, 2024; (2) a goal across FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and (3) contributions, totaling $51 million to: (a) fund energy conservation programs, economic development and job retention in the Ohio Companies’ service territories; (b) establish a fuel-fund in each of the Ohio Companies’ service territories to assist low-income customers; and (c) establish a Customer Advisory Council to ensure preservation and growth of the competitive market in Ohio.

On September 8, 2020, the OCC filed motions in the Ohio Companies’ corporate separation audit and DMR audit dockets, requesting the PUCO to open an investigation and management audit, hire an independent auditor, and require FirstEnergy to show it did not improperly use money collected from consumers or violate any utility regulatory laws, rules or orders in its activities regarding HB 6. On December 30, 2020, in response to the OCC's motion, the PUCO reopened the DMR audit docket, and directed PUCO staff to solicit a third-party auditor and conduct a full review of the DMR to ensure funds collected from customers through the DMR were only used for the purposes established in ESP IV. On June 2, 2021, the PUCO selected an auditor and the auditor filed the final audit report on January 14, 2022, which made certain findings and recommendations. The report found that spending of DMR revenues was not required to be tracked, and that DMR revenues, like all rider revenues, are placed into the regulated money pool as a matter of routine, where the funds lose their identity. Therefore, the report could not suggest that DMR funds were used definitively for direct or indirect support for grid modernization. The report also concluded that there was no documented evidence that ties revenues from the DMR to lobbying for the passage of HB 6, but also could not rule out with certainty uses of DMR funds to support the passage of HB 6. The report further recommended that the regulated companies' money pool be audited more frequently and the Ohio Companies adopt formal dividend policies.

On September 15, 2020, the PUCO opened a new proceeding to review the political and charitable spending by the Ohio Companies in support of HB 6 and the subsequent referendum effort, and directing the Ohio Companies to show cause, demonstrating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers. The Ohio Companies initially filed a response stating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers, but on August 6, 2021, filed a supplemental response explaining that, in light of the facts set forth in the DPA and the findings of the Rider DCR audit report further discussed below, political or charitable spending in support of HB 6, or the subsequent referendum effort, affected pole attachment rates paid by approximately $15 thousand. On October 26, 2021, the OCC filed a motion requesting the PUCO to order an independent external audit to investigate FE’s political and charitable spending related to HB 6, and to appoint an independent review panel to retain and oversee the auditor. In November and December 2021, parties filed comments and reply comments regarding the Ohio Companies’ original and supplemental responses to the PUCO’s September 15, 2020, show cause directive. On March 9, 2022, the PUCO directed its staff to seek the services of a third-party auditor to determine whether the show cause

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demonstration submitted by the Ohio Companies is sufficient to ensure that the cost of any political or charitable spending in support of HB 6 or the subsequent referendum effort was not included, directly or indirectly, in any rates or charges paid by ratepayers.

In connection with an ongoing audit of the Ohio Companies’ policies and procedures relating to the code of conduct rules between affiliates, on November 4, 2020, the PUCO initiated an additional corporate separation audit as a result of the FirstEnergy leadership transition announcement made on October 29, 2020, as further discussed below. The additional audit is to ensure compliance by the Ohio Companies and their affiliates with corporate separation laws and the Ohio Companies’ corporate separation plan. The additional audit is for the period from November 2016 through October 2020. The final audit report was filed on September 13, 2021. The audit report makes no findings of major non-compliance with Ohio corporate separation requirements, minor non-compliance with eight requirements, and findings of compliance with 23 requirements. Parties filed comments and reply comments on the audit report, and a PUCO attorney examiner has issued a procedural schedule setting an evidentiary hearing on August 22, 2022.

In the fourth quarter of 2020, motions were filed with the PUCO requesting that the PUCO amend the Ohio Companies’ riders for collecting the OVEC related charges required by HB 6, which the Ohio Companies are further required to remit to other Ohio electric distribution utilities or to the State Treasurer, to provide for refunds in the event such provisions of HB 6 are repealed. The Ohio Companies contested the motions, which are pending before the PUCO.

On November 1, 2021, the Ohio Companies, together with the OCC, PUCO Staff, and several other signatories, entered into an Ohio Stipulation with the intent of resolving the ongoing energy efficiency rider audits, various SEET proceedings, including the Ohio Companies’ 2017 SEET proceeding, and the Ohio Companies’ quadrennial ESP review, each of which was pending before the PUCO. Specifically, the Ohio Stipulation provides that the Ohio Companies’ current ESP IV passes the required statutory test for their prospective SEET review as part of the Quadrennial Review of ESP IV, and except for limited circumstances, the signatory parties have agreed not to challenge the Ohio Companies’ SEET return on equity calculation methodology for their 2021-2024 SEET proceedings. The Ohio Stipulation additionally affirms that: (i) the Ohio Companies’ ESP IV shall continue through its previously authorized term of May 31, 2024; and (ii) the Ohio Companies will file their next base rate case in May 2024, and further, no signatory party will seek to adjust the Ohio Companies’ base distribution rates before that time, except in limited circumstances. The Ohio Companies further agreed to refund $96 million to customers in connection with the 2017-2019 SEET cases, and to provide $210 million in future rate reductions for all customers, including $80 million in 2022, $60 million in 2023, $45 million in 2024, and $25 million in 2025. The PUCO approved the 2017-2019 SEET refunds and 2022 rate reductions December 1, 2021, and refunds began in January 2022. Future rate reductions are recognized as a reduction to regulated distribution segment’s revenue in the Consolidated Statements of Income as they are provided to the Ohio Companies’ customers.

In connection with an ongoing annual audit of the Ohio Companies’ Rider DCR for 2020, and as a result of disclosures in FirstEnergy’s Form 10-K for the year ended December 31, 2020 (filed on February 18, 2021), the PUCO expanded the scope of the audit on March 10, 2021, to include a review of certain transactions that were either improperly classified, misallocated, or lacked supporting documentation, and to determine whether funds collected from customers were used to pay the vendors, and if so, whether or not the funds associated with those payments should be returned to customers through Rider DCR or through an alternative proceeding. On August 3, 2021, the auditor filed its final report on this phase of the audit, and the parties submitted comments and reply comments on this audit report in October 2021. Additionally, on September 29, 2021, the PUCO expanded the scope of the audit in this proceeding to determine if the costs of the naming rights for FirstEnergy Stadium have been recovered from the Ohio Companies’ customers. On November 19, 2021, the auditor filed its final report, in which the auditor concluded that the FirstEnergy Stadium naming rights expenses were not recovered from Ohio customers. On December 15, 2021, the PUCO further expanded the scope of the audit to include an investigation into an apparent nondisclosure of a side agreement in the Ohio Companies’ ESP IV settlement proceedings, but stayed its expansion of the audit until otherwise ordered by the PUCO.

See Note 8, "Commitments, Guarantees and Contingencies" below for additional details on the government investigations and subsequent litigation surrounding the investigation of HB 6.

PENNSYLVANIA

The Pennsylvania Companies operate under rates approved by the PPUC, effective as of January 27, 2017. On November 18, 2021, the PPUC issued orders to each of the Pennsylvania Companies directing they operate under DSPs for the June 1, 2019 through May 31, 2023 delivery period, which DSPs provide for the competitive procurement of generation supply for customers who do not receive service from an alternative EGS. Under the 2019-2023 DSPs, supply will be provided by wholesale suppliers through a mix of 3, 12 and 24-month energy contracts, as well as two RFPs for 2-year SREC contracts for ME, PN and Penn. On December 14, 2021, the Pennsylvania Companies filed proposed DSPs for provision of generation for the June 1, 2023 through May 31, 2027 delivery period, to be sourced through competitive procurements for customers who do not receive service from an alternative EGS. An evidentiary hearing was held on April 13, 2022, and the parties filed a partial settlement with the PPUC resolving most of the issues in the proceeding on April 20, 2022. The remaining issues in the proceeding, which are limited to the treatment of customer-generated energy and renewable energy credit production will be resolved through briefing. Under the

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2023-2027 DSPs, supply is proposed to be provided through a mix of 12 and 24-month energy contracts, as well as long-term solar PPAs.

In March 2018, the PPUC approved adjusted customer rates of the Pennsylvania Companies to reflect the net impact of the Tax Act. As a result, the Pennsylvania Companies established riders that, beginning July 1, 2018, refunded to customers tax savings attributable to the Tax Act as compared to the amounts established in their most recent base rate proceedings on a current and going forward basis. The amounts recorded as savings for the total period of January 1 through June 30, 2018, were tracked and were to be addressed for treatment in a future proceeding. On May 17, 2021, the Pennsylvania Companies filed petitions with the PPUC proposing to refund the net savings for the January through June 2018 period to customers beginning January 1, 2022. On November 18, 2021, the PPUC approved the Pennsylvania Companies' proposed refunds, but also revised a previous methodology for calculating the net tax savings, which resulted in additional tax savings attributable to the Tax Act to be refunded to customers and directed the Pennsylvania Companies to file new petitions to propose the timing and methodology to provide these additional refunds to customers. The Pennsylvania Companies recalculated the net impact for 2018 through 2021 under the revised PPUC methodology in comparison to amounts already refunded to customers under the existing riders, which resulted in an additional $61 million in savings, with interest, to be provided to customers. As a result, FirstEnergy recognized a pre-tax charge of $61 million in the fourth quarter of 2021 associated with the additional refund and based on the November 2021 PPUC order and methodology. The Pennsylvania Companies filed petitions to propose the timing and methodology of the refund of these amounts on February 17, 2022. If approved, the Pennsylvania Companies would refund these amounts beginning July 1, 2022, and continuing through the end of the year.

Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, Pennsylvania EDCs implement energy efficiency and peak demand reduction programs. On June 18, 2020, the PPUC entered a Final Implementation Order for a Phase IV EE&C Plan, operating from June 2021 through May 2026. The Final Implementation Order set demand reduction targets, relative to 2007 to 2008 peak demands, at 2.9% MW for ME, 3.3% MW for PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania Companies’ historic 2009 to 2010 reference load at 3.1% MWH for ME, 3.0% MWH for PN, 2.7% MWH for Penn, and 2.4% MWH for WP. The Pennsylvania Companies’ Phase IV plans were approved by PPUC without modification on March 25, 2021.

Pennsylvania EDCs are permitted to seek PPUC approval of an LTIIP for infrastructure improvements and costs related to highway relocation projects, after which a DSIC may be approved to recover LTIIP costs. On January 16, 2020, the PPUC approved the Pennsylvania Companies’ LTIIPs for the five-year period beginning January 1, 2020 and ending December 31, 2024 for a total capital investment of approximately $572 million for certain infrastructure improvement initiatives. On June 25, 2021, the Pennsylvania OCA filed a complaint against Penn’s quarterly DSIC rate, disputing the recoverability of the Companies’ automated distribution management system investment under the DSIC mechanism. On January 26, 2022, the parties filed a joint petition for settlement that resolves all issues in this matter pending PPUC approval.

Following the Pennsylvania Companies’ 2016 base rate proceedings, the PPUC ruled in a separate proceeding related to the DSIC mechanisms that the Pennsylvania Companies were not required to reflect federal and state income tax deductions related to DSIC-eligible property in DSIC rates. The decision was appealed to the Pennsylvania Supreme Court and in July 2021 the court upheld the Pennsylvania Commonwealth Court’s reversal of the PPUC’s decision and remanded the matter back to the PPUC for determination as to how DSIC calculations shall account for ADIT and state taxes. The matter awaits further action by the PPUC. The adverse ruling by the Pennsylvania Supreme Court is not expected to result in a material impact to FirstEnergy.

WEST VIRGINIA

MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate under WVPSC approved rates that became effective in February 2015. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s ENEC rate is updated annually.

On December 30, 2020, MP and PE filed with the WVPSC a determination of the rate impact of the Tax Act with respect to ADIT. The filing proposed an annual revenue reduction of $2.6 million, effective January 1, 2022, with reconciliation and any resulting adjustments incorporated into annual ENEC proceedings. On August 12, 2021, a unanimous settlement was reached with all the parties agreeing to a $7.7 million rate reduction beginning January 1, 2022, with a true-up in the ENEC proceeding each year. On November 30, 2021, the WVPSC approved the settlement on all terms, except for the proposed effective date of the rate reduction, which was held in abeyance until further notice.

On August 27, 2021, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates of $19.6 million beginning January 1, 2022, which represented a 1.5% increase to the rates currently in effect. WVPSC issued an order on December 29, 2021, granting the requested $19.6 million increase in ENEC rates. Among other things, the order requires MP and PE to refund to its large industrial customers their respective portion of the $7.7 million rate reduction discussed above and also requires MP and PE to negotiate a PPA for its capacity shortfall and a reasonable reserve margin if certain conditions are met. By order dated March 2, 2022, the WVPSC reopened the case to determine whether rates should be increased to recover growing ENEC under-recoveries. MP and PE proposed a $94 million rate increase to address the growing under-recoveries and a hearing was held on March 24, 2022. Any interim rate increase approved by WVPSC would be expected to begin May 1, 2022.

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On December 3, 2021 and on December 27, 2021, the WVPSC approved settlements granting MP and PE a $16 million increase in rates effective January 1, 2022, and permitting the continuation of the vegetation management program and surcharge for another two years. WVPSC additionally ordered MP and PE to perform equipment inspections within a reasonable time after vegetation management occurs on a circuit.

On November 22, 2021, MP and PE filed with the WVPSC their plan to construct 50 MWs of solar generation at five sites in West Virginia. The plan includes a tariff to offer solar power to West Virginia customers and cost recovery for MP and PE from other customers through a surcharge for any solar investment not fully subscribed by their customers. A hearing was held on March 16 and 17, 2022, and an order is expected in the second quarter of 2022. The solar generation project, if approved, is expected to cost approximately $110 million and begin being in-serviced by the end of 2023 with all construction completed at the other sites no later than the end of 2025.

On December 17, 2021, MP and PE filed with the WVPSC for approval of environmental compliance projects at the Ft. Martin and Harrison Power Stations to comply with the EPA’s ELG and operate these plants beyond 2028. The request includes a surcharge to recover the expected $142 million capital investment and $3 million in annual operation and maintenance expense. A hearing has been set for in August 2022, with a ruling from the WVPSC expected in the fall of 2022. If approved, construction would be expected to be completed by the end of 2025. See Note 8, “Commitments, Guarantees and Contingencies - Environmental Matters - Clean Water Act" below, for additional details on the EPA's ELG.

FERC REGULATORY MATTERS

Under the FPA, FERC regulates rates for interstate wholesale sales, transmission of electric power, accounting and other matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the Utilities, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP, PE, WP and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and conditions. Transmission facilities of JCP&L, MP, PE, WP and the Transmission Companies are subject to functional control by PJM and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.

FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or erect barriers to entry into markets. The Utilities and AE Supply each have been authorized by FERC to sell wholesale power in interstate commerce at market-based rates and have a market-based rate tariff on file with FERC, although in the case of the Utilities major wholesale purchases remain subject to review and regulation by the relevant state commissions.

Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-keeping and reporting requirements on the Utilities, AE Supply, and the Transmission Companies. NERC is the ERO designated by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are located within the RFC region. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards implemented and enforced by RFC.

FirstEnergy believes that it is in material compliance with all currently effective and enforceable reliability standards. Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial condition, results of operations, and cash flows.

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FERC Audit

FERC’s Division of Audits and Accounting initiated a nonpublic audit of FESC in February 2019. Among other matters, the audit is evaluating FirstEnergy’s compliance with certain accounting and reporting requirements under various FERC regulations. On February 4, 2022, FERC filed the final audit report for the period of January 1, 2015 through September 30, 2021, which included several findings and recommendations. FirstEnergy has accepted the findings and recommendations of the final audit report. The audit report included a finding and related recommendation that FirstEnergy may have used an inappropriate methodology for allocation of certain costs to regulatory capital accounts under certain FERC regulations and reporting. As such, FirstEnergy is currently performing an analysis of these costs and how it impacted certain wholesale transmission customer rates. FirstEnergy is unable to predict or estimate the final outcome of this analysis and audit, however, it could result in refunds, with interest, to certain wholesale transmission customers and/or write-offs of previously capitalized costs if they are determined to be nonrecoverable.

ATSI Transmission Formula Rate

On May 1, 2020, ATSI filed amendments to its formula rate to recover regulatory assets for certain costs that ATSI incurred as a result of its 2011 move from MISO to PJM, certain costs allocated to ATSI by FERC for transmission projects that were constructed by other MISO transmission owners, and certain costs for transmission-related vegetation management programs. A portion of these costs would have been charged to the Ohio Companies. Additionally, ATSI proposed certain income tax-related adjustments and certain tariff changes addressing the revenue credit components of the formula rate template. On June 30, 2020, FERC issued an initial order accepting the tariff amendments subject to refund and setting the matter for hearing and settlement proceedings. ATSI and the parties to the FERC proceeding subsequently were able to reach settlement, and on October 14, 2021, filed the settlement with FERC. As a result of the filed settlement, FirstEnergy recognized a $21 million pre-tax charge during the third quarter of 2021, which reflects the difference between amounts originally recorded as regulatory assets and amounts which will ultimately be recovered as a result of the pending settlement. From a segment perspective, during the third quarter of 2021, the Regulated Transmission segment recorded a pre-tax charge of $48 million and the Regulated Distribution segment recognized a $27 million reduction to a reserve previously recorded in 2010. In addition, the settlement provides for partial recovery of future incurred costs allocated to ATSI by MISO for the above-referenced transmission projects that were constructed by other MISO transmission owners, which is not expected to have a material impact on FirstEnergy or ATSI. The uncontested settlement was approved by FERC on March 24, 2022 without modification.

FERC Actions on Tax Act

On March 15, 2018, FERC initiated proceedings on the question of how to address possible changes to ADIT and bonus depreciation as a result of the Tax Act. Such possible changes could impact FERC-jurisdictional rates, including transmission rates. On November 21, 2019, FERC issued a final rule (Order No. 864). Order No. 864 requires utilities with transmission formula rates to update their formula rate templates to include mechanisms to: (i) deduct any excess ADIT from or add any deficient ADIT to their rate base; (ii) raise or lower their income tax allowances by any amortized excess or deficient ADIT; and (iii) incorporate a new permanent worksheet into their rates that will annually track information related to excess or deficient ADIT. Per FERC directives, ATSI submitted its compliance filing on May 1, 2020. MAIT submitted its compliance filing on June 1, 2020. On November 18, 2021, FERC issued an order that: (i) accepted ATSI proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed ATSI to make a further compliance filing by January 17, 2022; and (iii) set the amount of ATSI’s recorded ADIT balances as of December 31, 2017, for hearing and settlement procedures. ATSI submitted the compliance filing, and is participating in settlement negotiations. On December 3, 2021, FERC issued an order that (i) accepted MAIT’s proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed MAIT to make a further compliance filing by February 1, 2022; and (iii) set the amount of MAIT’s recorded ADIT balances as of December 31, 2017 for hearing and settlement procedures. MAIT submitted the compliance filing, and is participating in settlement negotiations. On May 15, 2020, TrAIL submitted its compliance filing and on June 1, 2020, PATH submitted its required compliance filing. On May 4, 2021, FERC staff requested additional information about PATH’s proposed rate base adjustment mechanism, and PATH submitted the requested information on June 3, 2021. On July 12, 2021, FERC staff requested additional information about TrAIL’s proposed rate base adjustment mechanism. TrAIL filed its response on August 6, 2021. On March 31, 2022, FERC issued an order, ruling that TrAIL’s compliance filing partially complied with the requirements of Order No. 864 and directing TrAIL to submit a further compliance filing on or before May 31, 2022 to address certain additional items that according to FERC further will enhance transparency. The PATH compliance filing remains pending before FERC. MP, WP and PE (as holders of a “stated” transmission rate when Order No. 864 issued) are addressing these requirements in the transmission formula rates amendments that were filed on October 29, 2020, and which have been accepted by FERC effective January 1, 2021, subject to refund, pending further hearing and settlement procedures. MP, WP and PE are engaged in settlement negotiations with other parties to this proceeding.

ATSI ROE – Ohio Consumers Counsel v. ATSI, et al.

On February 24, 2022, the OCC filed a complaint with FERC against ATSI, AEP’s Ohio affiliates and AEPSC, and Duke Energy Ohio, LLC asserting that FERC should reduce the ROE utilized in the utilities’ transmission formula rates by eliminating the 50 basis point adder associated with RTO membership, effective February 24, 2022. The OCC contends that this result is required

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because Ohio law mandates that transmission owning utilities join an RTO and that the 50 basis point adder is applicable only where RTO membership is voluntary. ATSI disagrees with OCC’s characterization and set forth its reasons for such disagreement in a combined motion to dismiss and answer that was filed with FERC on March 31, 2022. On that same date, AEP and Duke filed separate motions to dismiss and answers to the OCC complaint, and several other parties filed comments. ATSI is currently evaluating whether to file an additional answer to respond to certain of the comments.

Transmission ROE Methodology

On March 20, 2020, FERC initiated a rulemaking proceeding on the transmission rate incentives provisions of Section 219 of the 2005 Energy Policy Act. FirstEnergy submitted comments through EEI and as part of a consortium of PJM Transmission Owners. In a supplemental rulemaking proceeding that was initiated on April 15, 2021, FERC requested comments on, among other things, whether to require utilities that have been members of an RTO for three years or more and that have been collecting an “RTO membership” ROE incentive adder to file tariff updates that would terminate collection of the incentive adder. Initial comments on the proposed rule were filed on June 25, 2021, and reply comments were filed on July 26, 2021. The rulemaking remains pending before FERC. FirstEnergy is a member of PJM and its transmission subsidiaries could be affected by the supplemental proposed rule. FirstEnergy participated in comments on the supplemental rulemaking that were submitted by a group of PJM transmission owners and by various industry trade groups. If there were to be any changes to FirstEnergy transmission incentive ROE, such changes will be applied on a prospective basis.

Allegheny Power Zone Transmission Formula Rate Filings

On October 29, 2020, MP, PE and WP filed tariff amendments with FERC to implement a forward-looking formula transmission rate, to be effective January 1, 2021. In addition, on October 30, 2020, KATCo filed a proposed new tariff to establish a forward-looking formula rate and requested that the new rate become effective January 1, 2021. In its filing, KATCo explained that while it currently owns no transmission assets, it may build new transmission facilities in the Allegheny zone, and that it may seek required state and federal authorizations to acquire transmission assets from PE and WP by January 1, 2022. These transmission rate filings were accepted for filing by FERC on December 31, 2020, effective January 1, 2021, subject to refund, pending further hearing and settlement procedures and were consolidated into a single proceeding. MP, PE and WP, and KATCo are engaged in settlement negotiations with the other parties to the formula rate proceedings.

8. COMMITMENTS, GUARANTEES AND CONTINGENCIES

GUARANTEES AND OTHER ASSURANCES

FirstEnergy has various financial and performance guarantees and indemnifications, which are issued in the normal course of business. These contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications. FirstEnergy enters into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party.

As of March 31, 2022, outstanding guarantees and other assurances aggregated approximately $1.1 billion, consisting of parental guarantees on behalf of its consolidated subsidiaries ($602 million) and other assurances ($468 million).

COLLATERAL AND CONTINGENT-RELATED FEATURES

In the normal course of business, FE and its subsidiaries may enter into physical or financially settled contracts for the sale and purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require FE or its subsidiaries to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon FE’s or its subsidiaries’ credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty.

As of March 31, 2022, $52 million of collateral has been posted by FE or its subsidiaries and is included in Prepaid taxes and other current assets on FirstEnergy’s Consolidated Balance Sheets.

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These credit-risk-related contingent features stipulate that if the subsidiary 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. The following table discloses the potential additional credit rating contingent contractual collateral obligations as of March 31, 2022:

Potential Collateral Obligations		Utilities and Transmission Companies		FE		Total
	(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade		$	43	$	—	$	43
Surety Bonds (Collateralized Amount) (1)		57		258		315
Total Exposure from Contractual Obligations		$	100	$	258	$	358

(1)Surety Bonds are not tied to a credit rating. Surety Bonds’ impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with the respect to $39 million of surety bond obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.

ENVIRONMENTAL MATTERS

Various federal, state and local authorities regulate FirstEnergy with regard to air and water quality, hazardous and solid waste disposal, and other environmental matters. While FirstEnergy’s environmental policies and procedures are designed to achieve compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and potential revision by the implementing agencies. FirstEnergy cannot predict the timing or ultimate outcome of any of these reviews or how any future actions taken as a result thereof may materially impact its business, results of operations, cash flows and financial condition.

Clean Air Act

FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP(s) by burning lower-sulfur fuel, utilizing combustion controls and post-combustion controls and/or using emission allowances.

CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and SO2 emission allowances between power plants located in the same state and interstate trading of NOx and SO2 emission allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx and SO2 emissions from power plants in 13 states, including West Virginia. This followed the 2014 U.S. Supreme Court ruling generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on September 7, 2016, reducing summertime NOx emissions from power plants in 22 states in the eastern U.S., including West Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable attainment deadlines.

Also in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone NAAQS. The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126 petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA issued a revised CSAPR Update that addresses, among other things, the remands of the prior CSAPR Update and the New York Section 126 petition. In December 2021, MP purchased NOx emissions allowances to comply with 2021 ozone season requirements. On April 6, 2022, the EPA published proposed rules seeking to impose further significant reductions in EGU NOx emissions in 25 states, including West Virginia. The EPA held a virtual public hearing regarding the proposed rules on April 21, 2022, with comments due June 6, 2022. Depending on the outcome of any appeals and how the EPA and the states ultimately implement the revised CSAPR Update, the future cost of compliance may materially impact FirstEnergy's operations, cash flows and financial condition.

Climate Change

There are several initiatives to reduce GHG emissions at the state, federal and international level. Certain northeastern states are participating in the RGGI and western states led by California, have implemented programs, primarily cap and trade mechanisms, to control emissions of certain GHGs. Additional policies reducing GHG emissions, such as demand reduction programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.

In September 2016, the U.S. joined in adopting the agreement reached on December 12, 2015, at the United Nations Framework Convention on Climate Change meetings in Paris to reduce GHGs. The Paris Agreement’s non-binding obligations to limit global

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warming to below two degrees Celsius became effective on November 4, 2016. On June 1, 2017, the Trump Administration announced that the U.S. would cease all participation in the Paris Agreement. On January 20, 2021, President Biden signed an executive order re-adopting the agreement on behalf of the U.S. In November 2020, FirstEnergy published its Climate Story which includes its climate position and strategy, as well as a new comprehensive and ambitious GHG emission goal. FirstEnergy pledged to achieve carbon neutrality by 2050 and set an interim goal for a 30% reduction in GHGs within FirstEnergy’s direct operational control by 2030, based on 2019 levels. Future resource plans to achieve carbon reductions, including any determination of retirement dates of the regulated coal-fired generation, will be developed by working collaboratively with regulators in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory disallowances. If MP is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s financial condition, results of operations, and cash flow. Furthermore, FirstEnergy cannot currently estimate the financial impact of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions, or litigation alleging damages from GHG emissions, could require material capital and other expenditures or result in changes to its operations.

In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air Act,” concluding that concentrations of several key GHGs constitute an "endangerment" and may be regulated as "air pollutants" under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generating plants. Subsequently, the EPA released its final CPP regulations in August 2015 to reduce CO2 emissions from existing fossil fuel-fired EGUs and finalized separate regulations imposing CO2 emission limits for new, modified, and reconstructed fossil fuel-fired EGUs. Numerous states and private parties filed appeals and motions to stay the CPP with the D.C. Circuit in October 2015. On February 9, 2016, the U.S. Supreme Court stayed the rule during the pendency of the challenges to the D.C. Circuit and U.S. Supreme Court. On March 28, 2017, an executive order, entitled “Promoting Energy Independence and Economic Growth,” instructed the EPA to review the CPP and related rules addressing GHG emissions and suspend, revise or rescind the rules if appropriate. On June 19, 2019, the EPA repealed the CPP and replaced it with the ACE rule that established guidelines for states to develop standards of performance to address GHG emissions from existing coal-fired generation. On January 19, 2021, the D.C. Circuit vacated and remanded the ACE rule declaring that the EPA was “arbitrary and capricious” in its rule making and, as such, the ACE rule is no longer in effect and all actions thus far taken by states to implement the federally mandated rule are now null and void. The D.C. Circuit decision was appealed by several states, including West Virginia, as well as other interested parties. On February 28, 2022, the U.S. Supreme Court heard oral arguments on the matter is subject to legal challenge. Depending on the outcomes of the appeal and how any final rules are ultimately implemented, the future cost of compliance may be material.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal CWA and its amendments, apply to FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to FirstEnergy’s operations.

On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category (40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of pollutants in ash transport water. The treatment obligations were to phase-in as permits are renewed on a five-year cycle from 2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water, (with some limited discharge allowances), and extending the deadline for compliance to December 31, 2025 for both. In addition, the EPA allows for less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system, and unit retirement date. The EPA is reconsidering the ELG rule with a publicly announced target of issuing a proposed revised rule in the Fall of 2022 and a final rule by the Spring of 2023. In the interim, the rule issued on August 31, 2020, remains in effect. Depending on the outcome of appeals and how final rules are ultimately implemented, the compliance with these standards, could require additional capital expenditures or changes in operations at Ft. Martin and Harrison power stations from what was filed with the WVPSC in December 2021 that seeks approval of environmental compliance projects to comply with the EPA’s ELG.

After the completion of a negotiated settlement, a complaint was filed by the EPA and PA DEP on January 10, 2022 in Federal District Court for the Western District of Pennsylvania, alleging, among other things, that WP violated the CWA in connection with past boron exceedances at WP’s Springdale and Mingo landfills. On January 11, 2022, WP entered into a consent decree with the EPA and PA DEP resolving the matters addressed in the complaint, which, among other things, required a civil penalty of $610 thousand. The District Court entered the Consent Decree as final on March 17, 2022 and WP subsequently paid the penalty amount as required therein.

Regulation of Waste Disposal

Federal and state hazardous waste regulations have been promulgated as a result of the RCRA, as amended, and the Toxic Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending the EPA’s evaluation of the need for future regulation.

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In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generating plants. On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29, 2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and initiate closure to April 11, 2021. The final rule also allows for an extension of the closure deadline based on meeting proscribed site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to extend the closure date of McElroy's Run CCR impoundment facility until 2024, which request is pending technical review by the EPA. AE Supply continues to operate McElroy’s Run as a disposal facility for FG’s Pleasants Power Station.

FE or its subsidiaries have been named as potentially responsible parties at waste disposal sites, which may require cleanup under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on the Consolidated Balance Sheets as of March 31, 2021, based on estimates of the total costs of cleanup, FirstEnergy’s proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of approximately $110 million have been accrued through March 31, 2022, of which, approximately $70 million are for environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through a non-bypassable SBC. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites, but the loss or range of losses cannot be determined or reasonably estimated at this time.

OTHER LEGAL PROCEEDINGS

United States v. Larry Householder, et al.

On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Also, on July 21, 2020, and in connection with the investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s Office for the S.D. Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020.

On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves this matter. Under the DPA, FE has agreed to the filing of a criminal information charging FE with one count of conspiracy to commit honest services wire fraud. The DPA requires that FirstEnergy, among other obligations: (i) continue to cooperate with the U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, which shall consist of (x) $115 million paid by FE to the United States Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and detect violations of the U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million payment will neither be recovered in rates or charged to FirstEnergy customers nor will FirstEnergy seek any tax deduction related to such payment. The entire amount of the monetary penalty was recognized as expense in the second quarter of 2021, and paid in the third quarter of 2021. Under the terms of the DPA, the criminal information will be dismissed after FirstEnergy fully complies with its obligations under the DPA.

Legal Proceedings Relating to United States v. Larry Householder, et al.

On August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of possible securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers. On April 28, 2021, the SEC issued an additional subpoena to FE. While no contingency has been reflected in its consolidated financial statements, FE believes that it is probable that it will incur a loss in connection with the resolution of the SEC investigation. Given the ongoing nature and complexity of the review, inquiries and investigations, FE cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the SEC investigation.

In addition to the subpoenas referenced above under “—United States v. Larry Householder, et. al.” and the SEC investigation, certain FE stockholders and FirstEnergy customers filed several lawsuits against FirstEnergy and certain current and former directors, officers and other employees, and the complaints in each of these suits is related to allegations in the complaint and supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover an unspecified amount of damages (unless otherwise noted). Unless otherwise indicated, no contingency has been reflected in FirstEnergy’s consolidated financial statements with respect to these lawsuits as a loss is neither probable, nor is a loss or range of a loss reasonably estimable.

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•In re FirstEnergy Corp. Securities Litigation (Federal District Court, S.D. Ohio); on July 28, 2020 and August 21, 2020, purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those actions have been consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017 and July 21, 2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by issuing misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11, 12(a)(2) and 15 of the Securities Act of 1933 as a result of alleged misrepresentations or omissions in connection with offerings of senior notes by FE in February and June 2020. FE believes that it is probable that it will incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•MFS Series Trust I, et al. v. FirstEnergy Corp., et al. and Brighthouse Funds II – MFS Value Portfolio, et al. v. FirstEnergy Corp., et al. (Federal District Court, S.D. Ohio) on December 17, 2021 and February 21, 2022, purported stockholders of FE filed complaints against FE, certain current and former officers, and certain current and former officers of EH. The complaints allege that the defendants violated Sections 10(b) and 20(a) of the Exchange Act by issuing alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seek the same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will incur losses in connection with the resolution of these lawsuits. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•State of Ohio ex rel. Dave Yost, Ohio Attorney General v. FirstEnergy Corp., et al. and City of Cincinnati and City of Columbus v. FirstEnergy Corp. (Common Pleas Court, Franklin County, OH, all actions have been consolidated); on September 23, 2020 and October 27, 2020, the OAG and the cities of Cincinnati and Columbus, respectively, filed complaints against several parties including FE (the OAG also named FES as a defendant), each alleging civil violations of the Ohio Corrupt Activity Act in connection with the passage of HB 6. On January 13, 2021, the OAG filed a motion for a temporary restraining order and preliminary injunction against FirstEnergy seeking to enjoin FirstEnergy from collecting the Ohio Companies' decoupling rider. On January 31, 2021, FE reached a partial settlement with the OAG and the cities of Cincinnati and Columbus with respect to the temporary restraining order and preliminary injunction request and related issues. In connection with the partial settlement, the Ohio Companies filed an application on February 1, 2021, with the PUCO to set their respective decoupling riders (CSR) to zero. On February 2, 2021, the PUCO approved the application of the Ohio Companies setting the rider to zero and no additional customer bills will include new decoupling rider charges after February 8, 2021. The cases are stayed pending final resolution of the United States v. Larry Householder, et al. criminal proceeding described above, although on August 13, 2021, new defendants were added to the complaint, including two former officers of FirstEnergy. On November 9, 2021, the OAG filed a motion to lift the agreed-upon stay, which FE opposed on November 19, 2021; the motion remains pending. On December 2, 2021, the cities and FE entered a stipulated dismissal with prejudice of the cities’ suit.

•Smith v. FirstEnergy Corp. et al., Buldas v. FirstEnergy Corp. et al., and Hudock and Cameo Countertops, Inc. v. FirstEnergy Corp. et al. (Federal District Court, S.D. Ohio, all actions have been consolidated); on July 27, 2020, July 31, 2020, and August 5, 2020, respectively, purported customers of FE filed putative class action lawsuits against FE and FESC, as well as certain current and former FE officers, alleging civil Racketeer Influenced and Corrupt Organizations Act violations and related state law claims. FE agreed to a settlement to resolve these claims on April 11, 2022. In the fourth quarter of 2021, FirstEnergy recognized a pre-tax reserve of $37.5 million in the aggregate with respect to these lawsuits and the Emmons lawsuit below.

•Emmons v. FirstEnergy Corp. et al. (Common Pleas Court, Cuyahoga County, OH); on August 4, 2020, a purported customer of FirstEnergy filed a putative class action lawsuit against FE, FESC, the Ohio Companies, along with FES, alleging several causes of action, including negligence and/or gross negligence, breach of contract, unjust enrichment, and unfair or deceptive consumer acts or practices. FE agreed to a settlement to resolve these claims on April 11, 2022. In the fourth quarter of 2021, FirstEnergy recognized a pre-tax reserve of $37.5 million in the aggregate with respect to this lawsuit and the lawsuits above consolidated with Smith in the S.D. Ohio alleging, among other things, civil violations of the Racketeer Influenced and Corrupt Organizations Act.

On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve the following shareholder derivative lawsuits relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder that were filed in the S.D. Ohio, the N.D. Ohio, and the Ohio Court of Common Pleas, Summit County:

•Gendrich v. Anderson, et al. and Sloan v. Anderson, et al. (Common Pleas Court, Summit County, OH, all actions have been consolidated); on July 26, 2020 and July 31, 2020, respectively, purported stockholders of FE filed shareholder derivative action lawsuits against certain FE directors and officers, alleging, among other things, breaches of fiduciary duty.

•Miller v. Anderson, et al. (Federal District Court, N.D. Ohio); Bloom, et al. v. Anderson, et al.; Employees Retirement System of the City of St. Louis v. Jones, et al.; Electrical Workers Pension Fund, Local 103, I.B.E.W. v. Anderson et al.; Massachusetts Laborers Pension Fund v. Anderson et al.; The City of Philadelphia Board of Pensions and Retirement v. Anderson et al.; Atherton v. Dowling et al.; Behar v. Anderson, et al. (Federal District Court, S.D. Ohio, all actions

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have been consolidated); beginning on August 7, 2020, purported stockholders of FE filed shareholder derivative actions alleging the FE Board and officers breached their fiduciary duties and committed violations of Section 14(a) of the Exchange Act.

On March 11, 2022, the parties executed a stipulation and agreement of settlement, and filed a motion the same day requesting preliminary settlement approval in the S.D. Ohio. The settlement agreement, if approved, will fully resolve the shareholder derivative lawsuits above and stipulates a series of corporate governance enhancements, that has resulted or is expected to result in the following:

•Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D. Pappas and Luis A. Reyes, and Ms. Julia L. Johnson are not standing for re-election at FE’s 2022 annual shareholder meeting;

•A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;

•The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political and lobbying action plans prepared by management;

•An FE Board committee of recently appointed independent directors will oversee the implementation and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;

•FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced disclosure in its annual proxy statement; and

•FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.

The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any court-ordered attorney’s fees awarded to plaintiffs.

In letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that the Division is conducting an investigation of FirstEnergy’s lobbying and governmental affairs activities concerning HB 6, and staff directed FirstEnergy to preserve and maintain all documents and information related to the same as such have been developed as part of an ongoing non-public audit being conducted by FERC's Division of Audits and Accounting. While no contingency has been reflected in the consolidated financial statements, FirstEnergy believes that it is probable that it will incur a loss in connection with the resolution of the FERC investigation. Given the ongoing nature and complexity of the review, inquiries and investigations, FirstEnergy cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the FERC investigation.

The outcome of any of these lawsuits, governmental investigations and audit is uncertain and could have a material adverse effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.

Other Legal Matters

There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to FirstEnergy’s normal business operations pending against FE or its subsidiaries. The loss or range of loss in these matters is not expected to be material to FE or its subsidiaries. The other potentially material items not otherwise discussed above are described under Note 7, “Regulatory Matters.”

FirstEnergy accrues legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such costs. In cases where FirstEnergy determines that it is not probable, but reasonably possible that it has a material obligation, it discloses such obligations and the possible loss or range of loss if such estimate can be made. If it were ultimately determined that FE or its subsidiaries have legal liability or are otherwise made subject to liability based on any of the matters referenced above, it could have a material adverse effect on FE’s or its subsidiaries’ financial condition, results of operations, and cash flows.

9. SEGMENT INFORMATION

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable segments, Regulated Distribution and Regulated Transmission.

The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies, serving approximately six million customers within 65,000 square miles of Ohio, Pennsylvania, West Virginia, Maryland, New Jersey and New York, and purchases power for its POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey and Maryland. This segment also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. The segment’s results reflect the costs of securing and delivering electric generation from transmission facilities to customers, including the deferral and amortization of certain related costs.

On April 6, 2020, JCP&L signed an asset purchase agreement with Yards Creek Energy, LLC, a subsidiary of LS Power to sell its 50% interest in the Yards Creek pumped-storage hydro generation facility. With the receipt of all required regulatory approvals,

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the transaction was consummated on March 5, 2021 and resulted in a $109 million gain within the regulated distribution segment in the first quarter of 2021. The gain from the transaction was applied against and reduced JCP&L’s existing regulatory asset for previously deferred storm costs and, as a result, was offset by expense in the “Amortization (deferral) of regulatory assets, net”, line on the Consolidated Statements of Income, resulting in no earnings impact to FirstEnergy or JCP&L.

The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission Companies and certain of FirstEnergy’s utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to distribution facilities. The segment’s revenues are primarily derived from forward-looking formula rates. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual rate base and costs. The segment’s results also reflect the net transmission expenses related to the delivery of electricity on FirstEnergy’s transmission facilities. On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA, with Brookfield and Brookfield Guarantors pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. CFIUS completed its review on April 14, 2022 and FERC approved the transaction on April 21, 2022. The transaction is expected to close at the end of May 2022. KATCo, which is currently a subsidiary of FET, will become a wholly owned subsidiary of FE prior to the closing of the transaction and will remain in the Regulated Transmission segment.

Corporate/Other reflects corporate support and other costs not charged or attributable to the Utilities or Transmission Companies, including FE’s retained Pension and OPEB assets and liabilities of the FES Debtors, interest expense on FE’s holding company debt and other investments or businesses that do not constitute an operating segment. Reconciling adjustments for the elimination of inter-segment transactions are shown separately in the following table of Segment Financial Information. As of March 31, 2022, 67 MWs of electric generating capacity, representing AE Supply’s OVEC capacity entitlement, is included in Corporate/Other. As of March 31, 2022, Corporate/Other had approximately $7.4 billion of FE holding company debt.

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Financial information for each of FirstEnergy’s business segments and reconciliations to consolidated amounts is presented in the tables below. FirstEnergy evaluates segment performance based on Net income (loss).

Segment Financial Information

For the Three Months Ended	Regulated Distribution		Regulated Transmission		Corporate/ Other		Reconciling Adjustments		FirstEnergy Consolidated
	(In millions)
March 31, 2022
External revenues	$	2,532	$	451	$	6	$	—	$	2,989
Internal revenues	57		2		—		(59)		—
Total revenues	$	2,589	$	453	$	6	$	(59)	$	2,989
Depreciation	235		86		2		17		340
Amortization (deferral) of regulatory assets, net	(38)		1		—		—		(37)
Miscellaneous income (expense), net	85		6		17		(2)		106
Interest expense	129		59		127		(2)		313
Income taxes (benefits)	69		41		(27)		—		83
Net income (loss)	265		125		(102)		—		288
Property additions	$	317	$	197	$	6	$	—	$	520
March 31, 2021
External revenues	$	2,321	$	401	$	4	$	—	$	2,726
Internal revenues	49		4		—		(53)		—
Total revenues	$	2,370	$	405	$	4	$	(53)	$	2,726
Depreciation	226		81		1		15		323
Amortization of regulatory assets, net	87		5		—		—		92
Miscellaneous income (expense), net	107		11		22		(5)		135
Interest expense	128		61		101		(5)		285
Income taxes (benefits)	82		33		(28)		—		87
Net income (loss)	313		109		(87)		—		335
Property additions	$	321	$	273	$	10	$	—	$	604
As of March 31, 2022
Total assets	$	30,883	$	13,070	$	664	$	—	$	44,617
Total goodwill	$	5,004	$	614	$	—	$	—	$	5,618
As of December 31, 2021
Total assets	$	30,812	$	13,237	$	1,383	$	—	$	45,432
Total goodwill	$	5,004	$	614	$	—	$	—	$	5,618

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ITEM 2.        Management’s Discussion and Analysis of Financial Condition and Results of Operations

FIRSTENERGY CORP.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRSTENERGY’S BUSINESS

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable segments, Regulated Distribution and Regulated Transmission.

The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies, serving approximately six million customers within 65,000 square miles of Ohio, Pennsylvania, West Virginia, Maryland, New Jersey and New York, and purchases power for its POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey and Maryland. This segment also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. The segment’s results reflect the costs of securing and delivering electric generation from transmission facilities to customers, including the deferral and amortization of certain related costs.

The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission Companies and certain of FirstEnergy’s utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to distribution facilities. The segment’s revenues are primarily derived from forward-looking formula rates. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual rate base and costs. The segment’s results also reflect the net transmission expenses related to the delivery of electricity on FirstEnergy’s transmission facilities. On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA, with Brookfield and Brookfield Guarantors pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. CFIUS completed its review on April 14, 2022 and FERC approved the transaction on April 21, 2022. The transaction is expected to close at the end of May 2022.

Corporate/Other reflects corporate support and other costs not charged or attributable to the Utilities or Transmission Companies, including FE’s retained Pension and OPEB assets and liabilities of the FES Debtors, interest expense on FE’s holding company debt and other investments or businesses that do not constitute an operating segment. Additionally, reconciling adjustments for the elimination of inter-segment transactions are included in Corporate/Other. As of March 31, 2022, 67 MWs of electric generating capacity, representing AE Supply’s OVEC capacity entitlement, was included in continuing operations of Corporate/Other. As of March 31, 2022, Corporate/Other had approximately $7.4 billion of FE holding company debt.

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EXECUTIVE SUMMARY

FirstEnergy is a forward-thinking, electric utility centered on integrity, powered by a diverse team of employees, committed to making customers’ lives brighter, the environment better and our communities stronger.

FirstEnergy's core values encompass what matters most to the company. They guide the decisions we make and the actions we take. FirstEnergy's core values should inspire our actions today and shine a light on who we aspire to be in the future.

FirstEnergy Core Values:

•Integrity: We always act ethically with honesty, humility and accountability.

•Safety: We keep ourselves and others safe.

•Diversity, Equity and Inclusion: We embrace differences, ensure every employee is treated fairly and create a culture where everyone feels they belong.

•Performance Excellence: We pursue excellence and seek opportunities for growth, innovation and continuous improvement.

•Stewardship: We positively impact our customers, communities and other stakeholders, and strive to protect the environment.

Employees are encouraged and expected to have conversations with their leaders and peers about the core values and FirstEnergy's commitment to building a culture centered on integrity.

At FirstEnergy, we are dedicated to staying true to our mission and core values. We understand the impact our company can make in the world around us, which means pursuing initiatives and goals that align with our foundational principles, support our ESG and strategic priorities, and positively impact our stakeholders.

To solidify our role as an industry leader, we have developed a long-term strategy with priorities that are centered on our mission statement. These priorities reflect a strong foundation with an unrelenting customer focus that emphasizes modern experiences, new growth and affordable energy bills, and is leading and enabling the energy transition to a clean, resilient and secure electric grid.

We are proud of the steps we’ve already taken to demonstrate our commitment to our strategy and look forward to improving our performance and executing on these strategic priorities.

FirstEnergy's Business

As a fully regulated electric utility, FirstEnergy is focused on stable and predictable earnings and cash flow from its Regulated Distribution and Regulated Transmission businesses that deliver enhanced customer service and reliability.

FirstEnergy's Regulated Distribution business is comprised of a geographically and regulatory diverse collection of electric utilities delivering customer-focused sustainable growth. This business operates in a territory of 65,000 square miles, across the Midwest & Mid-Atlantic regions, one of the largest contiguous territories in the United States, and allows the Utilities to be uniquely positioned for growth through investments that strengthen the grid and enable the clean energy transition, with approximately $9 billion in investment plans (or 53% of the total FirstEnergy investment plan) from 2021 to 2025. Through its investment plan, Regulated Distribution has improved reliability and added operating flexibility to the distribution infrastructure, which provide benefits to the customers and communities those Utilities serve.

In addition to our investments to rebuild critical infrastructure and improve reliability, current and future distribution investment opportunities that support our ESG and strategic priorities include:

•Advanced Metering Infrastructure – install smart meters and related infrastructure;

•Grid Modernization Investments that support distribution automation and voltage and var optimization;

•Installation of electric vehicle charging stations;

•Connected LED Streetlights – strategic goal to convert 100% of streetlights owned by the Utilities to smart LEDs by 2030;

•Alternative Generation that lowers our carbon footprint;

•Information Systems – enhance our core information infrastructure of our distribution systems; and

•Supporting economic development to attract new business.

FirstEnergy's Regulated Transmission business is a premier, high quality transmission business, with over 24,000 miles of transmission lines in operation and one of the largest transmission systems in PJM. The Transmission Companies and certain of FirstEnergy's utilities (JCP&L, MP, PE and WP) are focused on "Energizing the Future" with investments that support clean

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energy, improve grid reliability and resiliency and support a carbon neutral future. "Energizing the Future" is the centerpiece of FirstEnergy’s regulated investment strategy with all investments recovered under FERC-regulated forward-looking formula rates, and approximately $8 billion in investment plans (or 45% of the total FirstEnergy investment plan) from 2021 to 2025. FirstEnergy believes there are incremental investment opportunities for its existing transmission infrastructure of over $20 billion beyond those identified through 2025, which are expected to strengthen grid and cyber-security and make the transmission system more reliable, robust, secure and resistant to extreme weather events, with improved operational flexibility.

In addition to our Energizing the Future investments, current and future transmission investment opportunities that support our ESG and strategic priorities include:

•Transmission Asset Health Center: real-time monitoring to reduce outages and lower expenses;

•Integrating digital technology to enhance equipment monitoring and lower costs;

•Exploring real-time technologies: emerging technologies to enhance data collection; and

•Making smart investments to modernize the grid to integrate future renewables.

On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA with Brookfield and the Brookfield Guarantors, pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. CFIUS completed its review on April 14, 2022 and FERC approved the transaction on April 21, 2022. The transaction is expected to close at the end of May 2022.

On December 13, 2021, FE privately issued to BIP Securities II-B L.P., an affiliate of Blackstone Infrastructure Partners L.P., 25,588,535 shares of FE’s common stock, par value $0.10 per share, at a price of $39.08 per share, representing an investment of $1.0 billion. In addition, FE nominated Sean T. Klimczak, the Blackstone Infrastructure Partners-selected representative, to stand for election to the FE Board at the 2022 annual shareholders’ meeting. On April 21, 2022, FERC approved the Blackstone representative’s ability to participate as a voting member of the FE Board.

On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into six separate senior unsecured five-year syndicated revolving credit facilities. These new credit facilities provide substantial liquidity to support the Regulated Distribution and Regulated Transmission businesses, and each of the operating companies within the businesses. See “Capital Resources and Liquidity" below for additional details.

Together, these transactions enhance FirstEnergy's credit profile, provide funding for the strategic investments discussed above, and address all of FirstEnergy's equity plans, with the exception of annual issuances of up to $100 million under regular dividend reinvestment plans and employee benefit stock investment plans, through at least 2025.

FE Forward

FirstEnergy is also working to transform how it conducts business and serves its customers, to achieve value potential in a sustainable way and help FirstEnergy achieve its strategic priorities. In February 2021, FirstEnergy announced a new initiative to build upon FirstEnergy’s strong operations and business fundamentals and deliver immediate value and resilience, with substantial working capital improvements and capital efficiencies ramping up through 2024. Called "FE Forward," the initiative plays a critical first step in FirstEnergy’s transformation journey as it looks to enhance the organization, focus on performance excellence, and refocus the investment strategy through a range of opportunities.

By 2024, FE Forward is projected to generate approximately $380 million in annualized capital expenditure efficiencies, as well as, approximately $250 million in working capital improvements by 2023. This program includes an estimated $150 million of costs to achieve through 2023, which are expected to be self-funded through these efficiencies. FirstEnergy plans to redeploy the capital expenditure efficiencies in a more diverse capital program that over the long-term, continues to support our strategy as discussed above and using 2022 as baseline, operating expenses are projected to naturally decline 1% annually allowing for strategic flexibility and customer affordability. FE Forward is not a downsizing effort and there will not be any involuntary employee reductions in connection with this program. FirstEnergy expects that FE Forward will be a significant catalyst to augment its growth potential by taking a more strategic approach to operating expenditures and reinvesting in a more diverse capital program that over the long-term continues to support a smarter and cleaner electric grid, and maintain affordable customer bills. Specifically, FirstEnergy currently expects to redeploy these capital efficiencies into several projects, including, grid modernization, energy efficiency programs, smart meter and electric vehicle charging, and solar generation investments. As part of these efforts, FirstEnergy will evaluate the appropriate cadence to initiate rates cases on a state-by-state basis to best support FirstEnergy’s customer-focused strategic priorities.

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	For the Years Ended December 31,
FE Forward Expected Capital Expenditure Efficiencies and Working Capital Improvements	2021 Actual		2022 Forecast		2023 Forecast		2024 Forecast		2025 Forecast		Total
	(In millions)
Gross Capital Expenditure Efficiencies	$	210	$	280	$	380	$	380	$	380	$	1,630
Cost to Achieve (+/- 10%)	(40)		(80)		(30)		—		—		(150)
Net Capital Expenditure Efficiencies	$	170	$	200	$	350	$	380	$	380	$	1,480
Working Capital Improvements	130		120		—		—		—		250
Total Cash Flow Improvements	$	300	$	320	$	350	$	380	$	380	$	1,730

Climate Story

Our long-term strategy reiterates and supports our position that climate change is among the most important issues of our time and our commitment to doing our part to ensure a bright and sustainable future for the communities we serve. As part of our Climate Strategy, we’re focused on enabling our customers to thrive in a reduced carbon future. This includes transmission and distribution investments discussed above, investments in solar generation and supporting clean energy options, our efforts towards electrifying the economy, and driving energy efficiency.

Additionally, we plan to reduce our company-wide GHG emissions within our direct operational control (Scope 1) by 30% by 2030 (from our 2019 baseline), as we work toward carbon neutrality by 2050. Key steps in reducing our emissions and improving the efficiency of our operations include:

•Replacing Aging Equipment: We are responsibly replacing aging equipment on our transmission system that contains SF6, a greenhouse gas commonly used in electric utility equipment;

•Electrifying our Vehicle Fleet: We are targeting 30% electrification of our light-duty and aerial truck fleet by 2030 and 100% electrification by 2050. To reach our electrification goal, we’ve committed to 100% electric or hybrid vehicle purchases for our light-duty and aerial truck fleet moving forward, beginning with the first hybrid electric vehicle additions to the fleet in 2021;

•Using Generation Efficiencies and Flexibility: We are utilizing operational flexibilities, such as heat rate improvements through equipment upgrades, operational monitoring systems, and auxiliary power reductions at our generation facilities that will enable us to reach our interim 2030 goal of a 30% GHG reduction from 2019 levels, while continuing to provide customers with safe and reliable electricity; and

•Transitioning Away from Coal Generation: We expect to thoughtfully transition away from our regulated coal generation fleet no later than 2050, and in 2021, FirstEnergy sought approval to construct a solar generation source of at least 50 MWs in West Virginia. Also in 2021, FirstEnergy filed plans with the WVPSC to comply with EPA ELG rules that would keep MP’s generation plants responsibly operating beyond 2028, however, FirstEnergy intends to begin a broad stakeholder dialogue regarding planned operational end dates of 2035 and 2040 for Ft. Martin and Harrison, respectively, which further supports our Climate Strategy.

Future resource plans to achieve carbon reductions, including potential changes in operations or any determination of retirement dates of the regulated coal-fired generating facilities, will be developed by working collaboratively with regulators in West Virginia. Determination of the useful life of the regulated coal-fired generating facilities could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment or regulatory disallowances. If MP is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s financial condition, results of operations, and cash flow.

HB 6 and Related Investigations

On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves the U.S. Attorney’s Office investigation into FirstEnergy relating to FirstEnergy’s lobbying and governmental affairs activities concerning HB 6 related to the federal criminal allegations made in July 2020, against former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Among other things, the DPA required FE to pay a monetary penalty of $230 million, which FE paid in the third quarter of 2021. Under the DPA, FE agreed to the filing of a criminal information charging FE with one count of conspiracy to commit honest services wire fraud. The $230 million payment will neither be recovered in rates or charged to FirstEnergy customers nor will FirstEnergy seek any tax deduction related to such payment. The criminal information will be dismissed after FirstEnergy fully complies with its obligations under the DPA.

The OAG, certain FE shareholders and FE customers filed several lawsuits against FirstEnergy and certain current and former directors, officers and other employees, each relating to the allegations against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve multiple shareholder derivative lawsuits that were filed in the S.D. Ohio,

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the N.D. Ohio, and the Ohio Court of Common Pleas, Summit County. On March 11, 2022, the parties executed a stipulation and agreement of settlement, and filed a motion the same day requesting preliminary settlement approval in the S.D. Ohio. The settlement agreement, if approved, will fully resolve these shareholder derivative lawsuits and includes a series of corporate governance enhancements, that has resulted or is expected to result in the following:

•Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D. Pappas and Luis A. Reyes, and Ms. Julia L. Johnson, are not standing for re-election at FE’s 2022 annual shareholder meeting;

•A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;

•The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political and lobbying action plans prepared by management;

•An FE Board committee of recently appointed independent directors will oversee the implementation and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;

•FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced disclosure in its annual proxy statement; and

•FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.

The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any court-ordered attorney’s fees awarded to plaintiffs.

In addition, on August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of possible securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers. Subsequently, on April 28, 2021, the SEC issued an additional subpoena to FE. Further, in letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that it is investigating FirstEnergy’s lobbying and governmental affairs activities concerning HB 6.

FirstEnergy has taken numerous steps to address challenges posed by the HB 6 investigations and improve its compliance culture, including the ongoing refreshment of the FE Board, the hiring of key senior executives committed to supporting transparency and integrity, and strengthening and enhancing FirstEnergy’s compliance culture through several initiatives. Although the outcome of the HB 6 investigations and state regulatory audits remain unknown, FirstEnergy has also taken several proactive steps to reduce regulatory uncertainty affecting the Ohio Companies.

Despite the many disruptions FirstEnergy is currently facing, the leadership team remains committed and focused on executing its strategy and running the business. See “Outlook - Other Legal Proceedings” below for additional details on the government investigations, the DPA, and subsequent litigation surrounding the investigation of HB 6. See also “Outlook - State Regulation - Ohio” below for details on the PUCO proceeding reviewing political and charitable spending and legislative activity in response to the investigation of HB 6. The outcome of the government investigations, PUCO proceedings, legislative activity, and any of these lawsuits is uncertain and could have a material adverse effect on FirstEnergy’s financial condition, results of operations, and cash flows.

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FINANCIAL OVERVIEW AND RESULTS OF OPERATIONS

(In millions)	For the Three Months Ended March 31,
	2022		2021		Change
Revenues	$	2,989	$	2,726	$	263	10	%
Operating expenses	2,430		2,167		263		12	%
Operating income	559		559		—		—	%
Other expenses, net	(188)		(137)		(51)		(37)	%
Income before income taxes	371		422		(51)		(12)	%
Income taxes	83		87		(4)		(5)	%
Net income	$	288	$	335	$	(47)	(14)	%

The financial results discussed below include revenues and expenses from transactions among FirstEnergy’s business segments. A reconciliation of segment financial results is provided in Note 9, “Segment Information,” of the Notes to Consolidated Financial Statements.

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Summary of Results of Operations — First Three Months of 2022 Compared with First Three Months of 2021

Financial results for FirstEnergy’s business segments in the first three months of 2022 and 2021 were as follows:

First Three Months 2022 Financial Results	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments		FirstEnergy Consolidated
	(In millions)
Revenues:
Electric	$	2,532	$	451	$	(39)	$	2,944
Other	57		2		(14)		45
Total Revenues	2,589		453		(53)		2,989
Operating Expenses:
Fuel	140		—		—		140
Purchased power	870		—		5		875
Other operating expenses	798		90		(68)		820
Provision for depreciation	235		86		19		340
Amortization (deferral) of regulatory assets, net	(38)		1		—		(37)
General taxes	215		66		11		292
Total Operating Expenses	2,220		243		(33)		2,430
Operating Income (Loss)	369		210		(20)		559
Other Income (Expense):
Miscellaneous income, net	85		6		15		106
Interest expense	(129)		(59)		(125)		(313)
Capitalized financing costs	9		9		1		19
Total Other Expense	(35)		(44)		(109)		(188)
Income (Loss) Before Income Taxes (Benefits)	334		166		(129)		371
Income taxes (benefits)	69		41		(27)		83
Net Income (Loss)	$	265	$	125	$	(102)	$	288

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First Three Months 2021 Financial Results	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments		FirstEnergy Consolidated
	(In millions)
Revenues:
Electric	$	2,316	$	401	$	(34)	$	2,683
Other	54		4		(15)		43
Total Revenues	2,370		405		(49)		2,726
Operating Expenses:
Fuel	118		—		—		118
Purchased power	714		—		4		718
Other operating expenses	728		67		(43)		752
Provision for depreciation	226		81		16		323
Amortization of regulatory assets, net	87		5		—		92
General taxes	201		62		10		273
Gain on sale of Yards Creek	(109)		—		—		(109)
Total Operating Expenses	1,965		215		(13)		2,167
Operating Income (Loss)	405		190		(36)		559
Other Income (Expense):
Miscellaneous income, net	107		11		17		135
Interest expense	(128)		(61)		(96)		(285)
Capitalized financing costs	11		2		—		13
Total Other Expense	(10)		(48)		(79)		(137)
Income (Loss) Before Income Taxes (Benefits)	395		142		(115)		422
Income taxes (benefits)	82		33		(28)		87
Net Income (Loss)	$	313	$	109	$	(87)	$	335

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Changes Between First Three Months 2022 and First Three Months 2021 Financial Results	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments		FirstEnergy Consolidated
	(In millions)
Revenues:
Electric	$	216	$	50	$	(5)	$	261
Other	3		(2)		1		2
Total Revenues	219		48		(4)		263
Operating Expenses:
Fuel	22		—		—		22
Purchased power	156		—		1		157
Other operating expenses	70		23		(25)		68
Provision for depreciation	9		5		3		17
Amortization (deferral) of regulatory assets, net	(125)		(4)		—		(129)
General taxes	14		4		1		19
Gain on sale of Yards Creek	109		—		—		109
Total Operating Expenses	255		28		(20)		263
Operating Income (Loss)	(36)		20		16		—
Other Income (Expense):
Miscellaneous income, net	(22)		(5)		(2)		(29)
Interest expense	(1)		2		(29)		(28)
Capitalized financing costs	(2)		7		1		6
Total Other Expense	(25)		4		(30)		(51)
Income (Loss) Before Income Taxes (Benefits)	(61)		24		(14)		(51)
Income taxes (benefits)	(13)		8		1		(4)
Net Income (Loss)	$	(48)	$	16	$	(15)	$	(47)

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Regulated Distribution — First Three Months of 2022 Compared with First Three Months of 2021

Regulated Distribution’s net income decreased $48 million in the first three months of 2022, as compared to the same period of 2021, primarily resulting from higher other operating expenses, customer rate credits associated with the PUCO-approved Ohio Stipulation, and higher pension and OPEB expenses, partially offset by higher weather-related demand, as well as the absence of a $27 million refund for previously collected decoupling revenues in Ohio, with interest.

Revenues —

The $219 million increase in total revenues resulted from the following sources:

	For the Three Months Ended March 31,
Revenues by Type of Service	2022		2021		Increase
	(In millions)
Distribution services(1)	$	1,348	$	1,312	$	36
Generation sales:
Retail	1,094		935		159
Wholesale	90		69		21
Total generation sales	1,184		1,004		180
Other	57		54		3
Total Revenues	$	2,589	$	2,370	$	219

(1) Includes $(27) million of ARP revenues for the three months ended March 31, 2021. Amounts reflect the Ohio Companies refund to customers that was previously collected under decoupling mechanisms, with interest. See “Outlook,” below for further discussion on Ohio decoupling rates.

Distribution services revenues increased $36 million in the first three months 2022, as compared to the same period of 2021, primarily resulting from higher recovery of transmission expenses, higher weather-related usage and customer demand, and the absence of a $27 million refund for previously collected decoupling revenues in Ohio, partially offset by customer rate credits associated with the PUCO-approved Ohio Stipulation.

Distribution services by customer class are summarized in the following table:

	For the Three Months Ended March 31,
(In thousands)	Actual				Weather-Adjusted
Electric Distribution MWH Deliveries	2022	2021	Increase		2022	2021	Increase (Decrease)
Residential	15,213	14,890	2.2	%	15,170	15,397	(1.5)	%
Commercial(1)	9,291	8,631	7.6	%	9,265	8,853	4.7	%
Industrial	13,583	13,257	2.5	%	13,583	13,258	2.5	%
Total Electric Distribution MWH Deliveries	38,087	36,778	3.6	%	38,018	37,508	1.4	%

(1) Includes street lighting.

Residential and commercial distribution deliveries were impacted by higher weather-related customer usage. Heating degree days were 4% above 2021 and 1% below normal. Increases in industrial deliveries were primarily from the steel and other manufacturing sectors.

Compared to pre-pandemic levels in 2019, weather-adjusted residential distribution deliveries in the first quarter of 2022 were relatively unchanged, while commercial and industrial deliveries were down by approximately 4.1% and 2.7%, respectively, and reflects a continued trend over the last several quarters of customer usage returning back to pre-pandemic levels.

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The following table summarizes the price and volume factors contributing to the $180 million increase in generation revenues for the first three months of 2022, as compared to the same period of 2021:

Source of Change in Generation Revenues	Increase (Decrease)
	(In millions)
Retail:
Change in sales volumes	$	62
Change in prices	97
	159
Wholesale:
Change in sales volumes	(15)
Change in prices	15
Capacity revenue	21
	21
Change in Generation Revenues	$	180

The increase in retail generation sales volumes was primarily due to higher weather-related usage and decreased customer shopping in New Jersey, Ohio and Pennsylvania. Total generation provided by alternative suppliers as a percentage of total MWH deliveries in the first three months of 2022, as compared to the same period of 2021, decreased to 44% from 46% in New Jersey, 84% from 85% in Ohio, and to 59% from 61% in Pennsylvania. The increase in retail generation prices primarily resulted from higher non-shopping generation auction rates in Pennsylvania. Retail generation sales, excluding those in West Virginia, have no material impact to earnings.

Wholesale generation revenues increased $21 million in the first three months of 2022, as compared to the same period in 2021, primarily due to an increase in spot market energy prices and higher capacity revenues, partially offset by lower volumes due to lower generation output. The difference between current wholesale generation revenues and certain energy costs incurred are deferred for future recovery or refund, with no material impact to earnings.

Operating Expenses —

Total operating expenses increased $255 million, primarily due to the following:

•Fuel costs increased $22 million during the first three months of 2022, as compared to the same period of 2021, primarily due to higher unit costs, partially offset by lower generation output. Due to the ENEC, fuel expense has no material impact on current earnings.

•Purchased power costs increased $156 million during the first three months of 2022, as compared to the same period of 2021, primarily due to higher market prices, increased volumes as described above and increased capacity expenses.

Source of Change in Purchased Power	Increase
	(In millions)
Purchases:
Change due to unit costs	$	83
Change due to volumes	46
	129
Capacity	27
Change in Purchased Power Costs	$	156

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•Other operating expenses increased $70 million in the first three months of 2022, as compared to the same period of 2021, primarily due to:

•Higher network transmission expenses of $29 million. These costs are deferred for future recovery, resulting in no material impact on current period earnings.

•Higher expenses of $20 million resulting from lower capitalization of vegetation management costs.

•Higher expenses of $13 million resulting from lower capitalization of corporate support costs.

•Higher employee benefit costs of approximately $7 million.

•Higher storm expenses of $6 million, of which $2 million was deferred for future recovery, resulting in no material impact on current period earnings.

•Higher West Virginia vegetation management, energy efficiency and other state mandated program costs of $3 million, which are deferred for future recovery, resulting in no material impact on earnings.

•Higher other operating and maintenance expenses of $2 million, primarily associated with higher regulated generation planned outage spend.

•Lower uncollectible expenses of $10 million, of which $5 million was deferred for future recovery.

•Depreciation expense increased $9 million in the first three months of 2022, as compared to the same period of 2021, primarily due to a higher asset base.

•Amortization (deferral) of regulatory assets, net decreased $125 million in the first three months of 2022, as compared to the same period of 2021, primarily due to:

◦$109 million decrease due to the absence of the reduction of the New Jersey storm cost regulatory asset as a result of the Yards Creek sale,

◦$32 million related to net decreases in other amortizations, partially offset by

◦$16 million of lower generation and transmission related deferrals.

•General taxes increased $14 million in the first three months of 2022, as compared to the same period of 2021, primarily due to higher Ohio property and Pennsylvania gross receipt taxes.

•The absence of the gain on sale of the Yards Creek Generating Facility of $109 million which was netted against the New Jersey storm deferral, as described above, resulting in no impact to earnings.

Other Expense —

Other expense increased $25 million in the first three months of 2022, as compared to the same period of 2021, primarily due to higher pension and OPEB non-service costs and lower asset performance on company-owned life insurance plans.

Income Taxes —

Regulated Distribution’s effective tax rate was 20.7% and 20.8% for the three months ended March 31, 2022 and 2021, respectively.     

Regulated Transmission — First Three Months of 2022 Compared with First Three Months of 2021

Regulated Transmission’s net income increased $16 million in the first three months of 2022, as compared to the same period of 2021, primarily due to higher rate base at MAIT and JCPL, and higher capitalized financing costs.

Revenues —

Total revenues increased $48 million, primarily due to the recovery of incremental operating expenses and a higher rate base.

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The following table shows revenues by transmission asset owner:

	For the Three Months Ended March 31,
Revenues by Transmission Asset Owner	2022		2021		Increase (Decrease)
	(In millions)
ATSI	$	217	$	207	$	10
TrAIL	65		61		4
MAIT	79		68		11
JCP&L	60		36		24
MP, PE and WP	32		33		(1)
Total Revenues	$	453	$	405	$	48

Operating Expenses —

Total operating expenses increased $28 million in the first three months of 2022, as compared to the same period of 2021, primarily due to higher operation and maintenance costs and increased property taxes and depreciation due to a higher asset base, partially offset by lower amortization of regulatory assets. Nearly all operating expenses are recovered through formula rates, resulting in no material impact on current period earnings.

Other Expense —

Total other expense decreased $4 million in the first three months of 2022, as compared to the same period of 2021, primarily due to higher capitalized financing costs.

Income Taxes —

Regulated Transmission’s effective tax rate was 24.7% and 23.2% for the three months ended March 31, 2022 and 2021, respectively.

Corporate / Other — First Three Months of 2022 Compared with First Three Months of 2021

Financial results at Corporate/Other resulted in a $15 million increase in net loss in the first three months of 2022, as compared to the same period of 2021, primarily due to higher interest expense from a make-whole premium resulting from the redemption of $850 million of FE’s notes, see “Capital Resources and Liquidity” below, and a valuation reserve against certain municipal deferred tax assets in the first quarter of 2022, partially offset by higher investment earnings and lower investigation and other related costs.

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REGULATORY ASSETS AND LIABILITIES

Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers through regulated rates. Regulatory liabilities represent amounts that are expected to be credited to customers through future regulated rates or amounts collected from customers for costs not yet incurred. FirstEnergy, the Utilities and the Transmission Companies net their regulatory assets and liabilities based on federal and state jurisdictions.

Management assesses the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet date and whenever new events occur. Factors that may affect probability relate to changes in the regulatory environment, issuance of a regulatory commission order or passage of new legislation. Upon material changes to these factors, where applicable, FirstEnergy will record new regulatory assets and liabilities and will assess whether it is probable that currently recorded regulatory assets and liabilities will be recovered or settled in future rates.

The following table provides information about the composition of net regulatory assets and liabilities as of March 31, 2022, and December 31, 2021, and the changes during the three months ended March 31, 2022:

Net Regulatory Assets (Liabilities) by Source	March 31, 2022		December 31, 2021		Change
	(In millions)
Customer payables for future income taxes	$	(2,303)	$	(2,345)	$	42
Spent nuclear fuel disposal costs	(87)		(101)		14
Asset removal costs	(650)		(646)		(4)
Deferred transmission costs	(30)		(3)		(27)
Deferred generation costs	163		118		45
Deferred distribution costs	75		49		26
Storm-related costs	673		660		13
Uncollectible and COVID-19 related costs	55		56		(1)
Energy efficiency program costs	47		47		—
New Jersey societal benefit costs	106		109		(3)
Regulatory transition costs	(18)		(18)		—
Vegetation management	39		33		6
Other	(25)		(12)		(13)
Net Regulatory Liabilities included on the Consolidated Balance Sheets	$	(1,955)	$	(2,053)	$	98

The following is a description of the regulatory assets and liabilities described above:

Customer payables for future income taxes - Reflects amounts to be recovered or refunded through future rates to pay income taxes that become payable when rate revenue is provided to recover items such as AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes such as the Tax Act. These amounts are being amortized over the period in which the related deferred tax assets reverse, which is generally over the expected life of the underlying asset.

Spent nuclear fuel disposal costs - Reflects amounts collected from customers, and the investment income, losses and changes in fair value of the trusts for spent nuclear fuel disposal costs related to the former nuclear generating facilities, Oyster Creek and TMI-1.

Asset removal costs - Primarily represents the rates charged to customers that include a provision for the cost of future activities to remove assets, including obligations for which an ARO has been recognized, that are expected to be incurred at the time of retirement.

Deferred transmission costs - Reflects differences between revenues earned based on actual costs for the formula-rate Transmission Companies and the amounts billed, which amounts are recorded as a regulatory asset or liability and recovered or refunded, respectively, in subsequent periods. Also included is the recovery of non-market based costs or fees charged to certain of the Utilities by various regulatory bodies including FERC and RTOs, which can include PJM charges and credits for service including, but not limited to, procuring transmission services and transmission enhancement.

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Deferred generation costs - Primarily relates to regulatory assets associated with the securitized recovery of certain fuel and purchased power regulatory assets at the Ohio Companies (amortized through 2034) as well as the ENEC at MP and PE. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. The ENEC rate is updated annually.

Deferred distribution costs - Primarily relates to the Ohio Companies’ deferral of certain expenses resulting from distribution and reliability related expenditures, including interest (amortized through 2036) and remaining refunds owed to customers associated with the PUCO-approved Ohio Stipulation.

Storm-related costs - Relates to the deferral of storm costs, which vary by jurisdiction. Approximately $190 million and $148 million are currently being recovered through rates as of March 31, 2022 and December 31, 2021, respectively.

Uncollectible and COVID-19 related costs - Includes the deferral of costs arising from COVID-19, including uncollectible expenses under new and existing riders prior to the pandemic.

Energy efficiency program costs - Relates to the recovery of costs in excess of revenues associated with energy efficiency programs including New Jersey energy efficiency and renewable energy programs, the Pennsylvania Companies’ EE&C programs, the Ohio Companies’ Demand Side Management and Energy Efficiency Rider, and PE’s EmPOWER Maryland Surcharge. Investments in certain of these energy efficiency programs earn a long-term return.

New Jersey societal benefit costs - Primarily relates to regulatory assets associated with MGP remediation, universal service and lifeline funds, and consumer education in New Jersey.

Regulatory transition costs - Includes the recovery of PN above-market NUG costs; and JCP&L costs associated with BGS, capacity and ancillary services, net of revenues from the sale of the committed supply in the wholesale market.

Vegetation management - Relates to regulatory assets in New Jersey and West Virginia associated with the recovery of certain distribution vegetation management costs as well as MAIT vegetation management costs (amortized through 2024).

The following table provides information about the composition of net regulatory assets that do not earn a current return as of March 31, 2022 and December 31, 2021, of which approximately $332 million and $228 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral and the jurisdiction.

Regulatory Assets by Source Not Earning a Current Return	March 31, 2022		December 31, 2021		Change
	(In millions)
Deferred transmission costs	$	9	$	13	$	(4)
Deferred generation costs	112		50		62
Storm-related costs	569		549		20
COVID-19 related costs	63		65		(2)
Regulatory transition costs	12		13		(1)
Vegetation management	28		31		(3)
Other	14		11		3
Regulatory Assets Not Earning a Current Return	$	807	$	732	$	75

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CAPITAL RESOURCES AND LIQUIDITY

FirstEnergy’s business is capital intensive, requiring significant resources to fund operating expenses, construction and other investment expenditures, scheduled debt maturities and interest payments, dividend payments, and potential contributions to its pension plan.

FE and its distribution and transmission subsidiaries expect their existing sources of liquidity to remain sufficient to meet their respective anticipated obligations. In addition to internal sources to fund liquidity and capital requirements for 2022 and beyond, FE and its distribution and transmission subsidiaries expect to rely on external sources of funds. Short-term cash requirements not met by cash provided from operations are generally satisfied through short-term borrowings. Long-term cash needs may be met through the issuance of long-term debt by FE and certain of its distribution and transmission subsidiaries to, among other things, fund capital expenditures and other capital-like investments, and refinance short-term and maturing long-term debt, subject to market conditions and other factors.

In alignment with FirstEnergy’s strategy to invest in its Regulated Distribution and Regulated Transmission segments as a fully regulated company, FirstEnergy is focused on maintaining balance sheet strength and flexibility. Specifically, at the regulated businesses, regulatory authority has been obtained for various regulated distribution and transmission subsidiaries to issue and/or refinance debt.

Any financing plans by FE or any of its consolidated subsidiaries, including the issuance of equity and debt, and the refinancing of short-term and maturing long-term debt are subject to market conditions and other factors. No assurance can be given that any such issuances, financing or refinancing, as the case may be, will be completed as anticipated or at all. Any delay in the completion of financing plans could require FE or any of its consolidated subsidiaries to utilize short-term borrowing capacity, which could impact available liquidity. In addition, FE and its consolidated subsidiaries expect to continually evaluate any planned financings, which may result in changes from time to time.

On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA with Brookfield and the Brookfield Guarantors, pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. CFIUS completed its review on April 14, 2022 and FERC approved the transaction on April 21, 2022. The transaction is expected to close at the end of May 2022.

On December 13, 2021, FE privately issued to BIP Securities II-B L.P., an affiliate of Blackstone Infrastructure Partners L.P., 25,588,535 shares of FE’s common stock, par value $0.10 per share, at a price of $39.08 per share, representing an investment of $1.0 billion. In addition, FE nominated Sean T. Klimczak, the Blackstone Infrastructure Partners-selected representative, to stand for election to the FE Board at the 2022 annual shareholders’ meeting. On April 21, 2022, FERC approved the Blackstone representative’s ability to participate as a voting member of the FE Board.

On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into six separate senior unsecured five-year syndicated revolving credit facilities. These new credit facilities provide substantial liquidity to support the Regulated Distribution and Regulated Transmission businesses, and each of the operating companies within the businesses. See “Capital Resources and Liquidity" below for additional details.

Together, these transactions enhance FirstEnergy's credit profile, provide funding for the strategic investments discussed above, and address all of FirstEnergy's equity plans, with the exception of annual issuances of up to $100 million under regular dividend reinvestment plans and employee benefit stock investment plans, through at least 2025.

FirstEnergy is continuously evaluating the COVID-19 global pandemic and taking steps to mitigate known risks. FirstEnergy provides a critical and essential service to its customers and the health and safety of its employees and customers is its first priority. FirstEnergy continues to provide flexibility for approximately 7,000 of its 12,400 employees to work from home. Pandemic safety and cleaning protocols were implemented for those workers who have continued to report to a FirstEnergy work location during the pandemic, ensuring FirstEnergy employees can report directly to job sites and work with the same small group of employees every day. FirstEnergy continues to assess its work from home policies to allow for a flexible workplace to continue for its employees after the pandemic.

FirstEnergy continues to effectively manage operations during the pandemic in order to provide critical service to customers. FirstEnergy has experienced supply chain challenges during the COVID-19 pandemic. Lead times have increased across numerous material categories, with some as much as doubling from previous times. Some key suppliers have struggled with labor shortages and raw material availability, which along with increasing inflationary pressure, have increased the costs of certain materials, equipment and contractors. FirstEnergy has taken steps to mitigate these risks and does not currently expect service disruptions or any material impact on its capital spending plan. However, the situation remains fluid and future impacts to FirstEnergy that are presently unknown or unanticipated may occur.

As of March 31, 2022, FirstEnergy’s net deficit in working capital (current assets less current liabilities) was primarily due to accounts payable, current portions of long-term debt, short-term borrowings and accrued interest, taxes, and compensation and

46

benefits. FirstEnergy believes its cash from operations and available liquidity will be sufficient to meet its current working capital needs.

Short-Term Borrowings / Revolving Credit Facilities

On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into the 2021 Credit Facilities, which were six separate senior unsecured five-year syndicated revolving credit facilities with JPMorgan Chase Bank, N.A., Mizuho Bank, Ltd. and PNC Bank, National Association that replace the FE Revolving Facility and the FET Revolving Facility, and provide for aggregate commitments of $4.5 billion. The 2021 Credit Facilities are available until October 18, 2026, as follows:

•FE and FET, $1.0 billion revolving credit facility;

•Ohio Companies, $800 million revolving credit facility;

•Pennsylvania Companies, $950 million revolving credit facility;

•JCP&L, $500 million revolving credit facility;

•MP and PE, $400 million revolving credit facility; and

•Transmission Companies, $850 million credit facility.

Under the 2021 Credit Facilities, an aggregate amount of $4.5 billion is available to be borrowed, repaid and reborrowed, subject to each borrower’s respective sublimit under the respective facilities. These new credit facilities provide substantial liquidity to support the Regulated Distribution and Regulated Transmission businesses, and each of the operating companies within the businesses.

Borrowings under the 2021 Credit Facilities may be used for working capital and other general corporate purposes. Generally, borrowings under each of the credit facilities are available to each borrower separately and mature on the earlier of 364 days from the date of borrowing or the commitment termination date, as the same may be extended. Each of the 2021 Credit Facilities contain financial covenants requiring each borrower, with the exception of FE, to maintain a consolidated debt-to-total-capitalization ratio (as defined under each of the 2021 Credit Facilities) of no more than 65%, and 75% for FET, measured at the end of each fiscal quarter. FE is required under its 2021 Credit Facility to maintain a consolidated interest coverage ratio of not less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters beginning with the quarter ending December 31, 2021.

FirstEnergy’s 2021 Credit Facilities bear interest at fluctuating interest rates, primarily based on LIBOR. LIBOR tends to fluctuate based on general interest rates, rates set by the U.S. Federal Reserve and other central banks, the supply of and demand for credit in the London interbank market and general economic conditions. FirstEnergy has not hedged its interest rate exposure with respect to its floating rate debt. Accordingly, FirstEnergy’s interest expense for any particular period will fluctuate based on LIBOR and other variable interest rates. On July 27, 2017, the FCA (the authority that regulates LIBOR) announced that it intends to stop compelling banks to submit rates for the calculation of LIBOR after 2021. Subsequently, on March 5, 2021, IBA (the entity that calculates and publishes LIBOR) and FCA made public statements regarding the future cessation of LIBOR. IBA permanently ceased publication for 1-week and 2-month LIBOR settings and all settings for non-USD LIBOR on December 31, 2021. According to the FCA, IBA will permanently cease to publish overnight, 1-month, 3-month, 6-month and 12-month LIBOR settings on June 30, 2023. IBA did not identify any successor administrator in its announcement. It is unclear whether new methods of calculating LIBOR will be established such that it continues to exist after such end dates, and there is considerable uncertainty regarding the publication or representativeness of LIBOR beyond such end dates. The U.S. Federal Reserve, in conjunction with the Alternative Reference Rates Committee, is seeking to replace U.S. dollar LIBOR with a newly created index, SOFR, calculated based on repurchase agreements backed by treasury securities. FirstEnergy’s 2021 Credit Facilities provide a mechanism to automatically transition to a SOFR-based benchmark when all United States dollar LIBOR settings are no longer provided or are no longer representative. In addition, FirstEnergy’s 2021 Credit Facilities provide an option for the applicable borrower and lender to jointly elect to transition early to a SOFR-based benchmark, or in certain circumstances, an alternative benchmark replacement. It is not possible to predict the effect of these changes, other reforms or the establishment of alternative reference rates in the United Kingdom, the United States or elsewhere. To the extent these interest rates increase, interest expense will increase. If sources of capital for us are reduced, capital costs could increase materially. Restricted access to capital markets and/or increased borrowing costs could have an adverse effect on FirstEnergy’s results of operations, cash flows, financial condition and liquidity.

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FirstEnergy had $350 million of outstanding short-term borrowings as of March 31, 2022, and no short-term borrowings as of December 31, 2021. FirstEnergy’s available liquidity from external sources as of April 18, 2022, was as follows:

Revolving Credit Facility	Maturity	Commitment		Available Liquidity
		(In millions)
FE and FET	October 2026	$	1,000	$	647
Ohio Companies	October 2026	800		800
Pennsylvania Companies	October 2026	950		950
JCP&L	October 2026	500		499
MP and PE	October 2026	400		400
Transmission Companies	October 2026	850		850
	Subtotal	$	4,500	$	4,146
Cash and cash equivalents		—		383
	Total	$	4,500	$	4,529

The following table summarizes the limitations on short-term indebtedness applicable to each borrower under current regulatory approvals and applicable statutory and/or charter limitations as of March 31, 2022:

Individual Borrower	Regulatory and Other Short-Term Debt Limitations
	(In millions)
FE and FET		N/A
OE, CEI, JCP&L, ME, MP, and ATSI		$	500	(1)
TE and PN		300		(1)
WP		200		(1)
PE		150		(1)
Penn		100		(1)
TrAIL and MAIT		400		(1)
(1) Includes amounts which may be borrowed under the regulated companies’ money pool.

Subject to each borrower’s sublimit, the amounts noted below are available for the issuance of LOCs (subject to borrowings drawn under the 2021 Credit Facilities) expiring up to one year from the date of issuance. The stated amount of outstanding LOCs will count against total commitments available under each of the 2021 Credit Facilities and against the applicable borrower’s borrowing sublimit. As of March 31, 2022, FirstEnergy had $4 million in outstanding LOCs.

Revolving Credit Facility	LOC Availability
(In millions)
FE and FET	$	100
Ohio Companies	150
Pennsylvania Companies	200
JCP&L	100
MP and PE	100
Transmission Companies	200

The 2021 Credit Facilities do not contain provisions that restrict the ability to borrow or accelerate payment of outstanding advances in the event of any change in credit ratings of the borrowers. Pricing is defined in “pricing grids,” whereby the cost of funds borrowed under the 2021 Credit Facilities are related to the credit ratings of the company borrowing the funds. Additionally, borrowings under each of the 2021 Credit Facilities are subject to the usual and customary provisions for acceleration upon the occurrence of events of default, including a cross-default for other indebtedness in excess of $100 million.

As of March 31, 2022, the borrowers were in compliance with the applicable interest coverage and debt-to-total-capitalization ratio covenants in each case as defined under the 2021 Credit Facilities.

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FirstEnergy Money Pools

FirstEnergy’s utility operating subsidiary companies also have the ability to borrow from each other and FE to meet their short-term working capital requirements. Similar but separate arrangements exist among FirstEnergy’s unregulated companies with AE Supply, FE, FET, FEV and certain other unregulated subsidiaries. FESC administers these money pools and tracks surplus funds of FE and the respective regulated and unregulated subsidiaries, as the case may be, as well as proceeds available from bank borrowings. Companies receiving a loan under the money pool agreements must repay the principal amount of the loan, together with accrued interest, within 364 days of borrowing the funds. The rate of interest is the same for each company receiving a loan from their respective pool and is based on the average cost of funds available through the pool. The average interest rate for borrowings through the first quarter of 2022 was 0.37% per annum for the regulated companies’ money pool and 0.52% per annum for the unregulated companies’ money pool.

Long-Term Debt Capacity

FE’s and its subsidiaries’ access to capital markets and costs of financing are influenced by the credit ratings of their securities. The following table displays FE’s and its subsidiaries’ credit ratings as of April 18, 2022:

Corporate Credit Rating

Senior Secured

Senior Unsecured

Outlook/CreditWatch (1)

Issuer

S&P

Moody’s

Fitch

S&P

Moody’s

Fitch

S&P

Moody’s

Fitch

S&P

Moody’s

Fitch

FE

BBB-

Ba1

BB+

—

—

—

BB+

Ba1

BB+

S

P

P

AGC

BB+

Baa2

BBB-

—

—

—

—

—

—

S

S

P

ATSI

BBB

A3

BBB-

—

—

—

BBB

A3

BBB

S

S

P

CEI

BBB

Baa2

BBB-

A-

A3

BBB+

BBB

Baa2

BBB

S

N

P

FET

BBB-

Baa2

BB+

—

—

—

BB+

Baa2

BB+

S

S

P

JCP&L

BBB

A3

BBB-

—

—

—

BBB

A3

BBB

S

S

P

ME

BBB

A3

BBB-

—

—

—

BBB

A3

BBB

S

S

P

MAIT

BBB

A3

BBB-

—

—

—

BBB

A3

BBB

S

S

P

MP

BBB

Baa2

BBB-

A-

A3

BBB+

BBB

Baa2

—

S

S

P

OE

BBB

A3

BBB-

A-

A1

BBB+

BBB

A3

BBB

S

S

P

PN

BBB

Baa1

BBB-

—

—

—

BBB

Baa1

BBB

S

S

P

Penn

BBB

A3

BBB-

A-

A1

BBB+

—

—

—

S

S

P

PE

BBB

Baa2

BBB-

A-

A3

BBB+

—

—

—

S

S

P

TE

BBB

Baa1

BBB-

A-

A2

BBB+

—

—

—

S

N

P

TrAIL

BBB

A3

BBB-

—

—

—

BBB

A3

BBB

S

S

P

WP

BBB

A3

BBB-

A-

A1

BBB+

—

—

—

S

S

P

(1) S = Stable, P = Positive, N = Negative

The applicable undrawn and drawn margin on the 2021 Credit Facilities are subject to ratings based pricing grids. The applicable fee paid on the undrawn commitments under the 2021 Credit Facilities are based on each borrower’s senior unsecured non-credit enhanced debt ratings as determined by S&P and Moody’s. The fee paid on actual borrowings are determined based on each borrower’s senior unsecured non-credit enhanced debt ratings as determined by S&P and Moody’s.

The interest rate payable on approximately $3.0 billion in FE’s senior unsecured notes are subject to adjustments from time to time if the ratings on the notes from any one or more of S&P, Moody’s and Fitch decreases to a rating set forth in the applicable governing documents. Generally a one-notch downgrade by the applicable rating agency may result in a 25 basis points coupon rate increase beginning at BB, Ba1, and BB+ for S&P, Moody’s and Fitch, respectively, to the extent such rating is applicable to the series of outstanding senior unsecured notes, during the next interest period, subject to an aggregate cap of 2% from issuance interest rate.

Debt capacity is subject to the consolidated interest coverage ratio in the 2021 Credit Facilities. As of March 31, 2022, FirstEnergy could incur approximately $790 million of incremental interest expense or incur a $2.0 billion reduction to the consolidated interest coverage earnings numerator, as defined under the covenant, and FE would remain within the limitations of the financial covenant requirements by the 2021 Credit Facilities.

Cash Requirements and Commitments

FirstEnergy has certain obligations and commitments to make future payments under contracts. For an in-depth discussion of FirstEnergy’s cash requirements and commitments, see “Capital Resources and Liquidity - Cash Requirements and Commitments " in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations" within FirstEnergy’s Form 10-K for the year ended December 31, 2021 (filed on February 16, 2022).

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Changes in Cash Position

As of March 31, 2022, FirstEnergy had approximately $283 million of cash and cash equivalents and $27 million of restricted cash compared to approximately $1.5 billion of cash and cash equivalents and $49 million of restricted cash as of December 31, 2021, on the Consolidated Balance Sheets.

Cash Flows From Operating Activities

FirstEnergy's most significant sources of cash are derived from electric service provided by its distribution and transmission operating subsidiaries. The most significant use of cash from operating activities is buying electricity to serve non-shopping customers and paying fuel suppliers, employees, tax authorities, lenders and others for a wide range of materials and services.

In the first three months of 2022, cash provided from operating activities was approximately $355 million compared to $533 million in the same period of 2021. The decrease in cash provided from operating activities is primarily due to rate refunds and rate credits provided to Ohio customers during the first quarter of 2022 under the PUCO-approved Ohio Stipulation, higher operating expenses from lower capitalization of certain vegetation management and corporate support costs, and the absence of accounts receivable working capital improvements in the first quarter of 2021, when collection activity improved since the start of the pandemic. These decreases in cash flow from operating activities are partially offset by cash flow generated from capital investments made since the first quarter of 2021 and improvements in accounts payable working capital from the implementation of FE Forward initiatives.

Cash Flows From Financing Activities

In the first three months of 2022, cash used for financing activities was $964 million compared to $509 million during the same period of 2021. The following table summarizes financing activities for the first three months of 2022 and 2021:

	For the Three Months Ended March 31,
Securities Issued or Redeemed / Repaid	2022		2021
	(In millions)
New issues - Unsecured notes	$	—	$	500
Redemptions / Repayments:
Unsecured notes	(1,000)		—
FMBs	(25)		—
Senior secured notes	(21)		(29)
	$	(1,046)	$	(29)
Make-whole premiums paid on debt redemptions	$	(38)	$	—
Short-term borrowings/(redemptions), net	$	350	$	(750)
Common stock dividend payments	$	(222)	$	(212)

In December 2021, notice of redemption was provided for all remaining $850 million of FE’s 4.25% Notes, Series B, due 2023, which was completed on January 20, 2022, and with a make-whole premium of approximately $38 million.

On January 27, 2022, CEI instructed its indenture trustee to provide notice of redemption for all remaining $150 million of CEI’s 2.77% Senior Notes, Series A, due 2034, for redemption which occurred on March 14, 2022.

Also on January 27, 2022, TE instructed its indenture trustee to provide notice of partial redemption for $25 million of TE’s 2.65% Senior Secured Notes, due 2028, for partial redemption which occurred on February 11, 2022.

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Cash Flows From Investing Activities

Cash used for investing activities in the first three months of 2022 principally represented cash used for property additions. The following table summarizes investing activities for the first three months of 2022 and 2021:

	For the Three Months Ended March 31,				Increase
Cash Used for Investing Activities	2022		2021		(Decrease)
	(In millions)
Property Additions:
Regulated Distribution	$	317	$	321	$	(4)
Regulated Transmission	197		273		(76)
Corporate / Other	6		10		(4)
Proceeds from sale of Yards Creek	—		(155)		155
Asset removal costs	49		47		2
Other	23		3		20
	$	592	$	499	$	93

Cash used for investing activities for the first quarter of 2022 increased $93 million, compared to the same period of 2021, primarily due to the absence of proceeds from the sale of Yards Creek received in the first quarter of 2021, partially offset by lower property additions.

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GUARANTEES AND OTHER ASSURANCES

FirstEnergy has various financial and performance guarantees and indemnifications, which are issued in the normal course of business. These contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications. FirstEnergy enters into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. The maximum potential amount of future payments FirstEnergy and its subsidiaries could be required to make under these guarantees as of March 31, 2022, was approximately $1.1 billion, as summarized below:

Guarantees and Other Assurances	Maximum Exposure
	(In millions)
FE’s Guarantees on Behalf of its Consolidated Subsidiaries
Deferred compensation arrangements	$	520
Vehicle leases	75
Other	7
	602
FE’s Guarantees on Other Assurances
Surety Bonds	330
Deferred compensation arrangements	134
LOCs	4
	468
Total Guarantees and Other Assurances	$	1,070

Collateral and Contingent-Related Features

In the normal course of business, FE and its subsidiaries may enter into physical or financially settled contracts for the sale and purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require FE or its subsidiaries to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon FE’s or its subsidiaries’ credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty.

As of March 31, 2022, $52 million of collateral has been posted by FE or its subsidiaries and is included in Prepaid taxes and other current assets on FirstEnergy’s Consolidated Balance Sheets.

These credit-risk-related contingent features stipulate that if the subsidiary 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. The following table discloses the potential additional credit rating contingent contractual collateral obligations as of March 31, 2022:

Potential Collateral Obligations		Utilities and Transmission Companies		FE		Total
	(In millions)
Contractual Obligations for Additional Collateral
Upon further downgrade		$	43	$	—	$	43
Surety Bonds (collateralized amount)(1)		57		258		315
Total Exposure from Contractual Obligations		$	100	$	258	$	358

(1)Surety bonds are not tied to a credit rating. Surety Bonds’ impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $39 million of surety bond obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.

MARKET RISK INFORMATION

FirstEnergy uses various market risk sensitive instruments, including derivative contracts, primarily to manage the risk of price and interest rate fluctuations. FirstEnergy’s Risk Policy Committee, comprised of members of senior management, provides general oversight for risk management activities throughout FirstEnergy.

Commodity Price Risk

FirstEnergy has limited exposure to financial risks resulting from fluctuating commodity prices, such as prices for electricity, coal and energy transmission. FirstEnergy’s Risk Management and Risk Policy Committees are responsible for promoting the

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effective design and implementation of sound risk management programs and oversees compliance with corporate risk management policies and established risk management practice.

The valuation of derivative contracts is based on observable market information. As of March 31, 2022, FirstEnergy has a net asset of $1 million in non-hedge derivative contracts that are related to FTRs at certain of the Utilities. FTRs are subject to regulatory accounting and do not impact earnings.

Equity Price Risk

As of March 31, 2022, the FirstEnergy pension plan assets were allocated approximately as follows: 35% in equity securities, 25% in fixed income securities, 12% in alternatives, 10% in real estate, 11% in private debt/equity, 5% in derivatives and 2% in cash and short-term securities. Due to the American Rescue Plan Act of 2021, under current assumptions, including an expected annual return on assets of 7.5%, FirstEnergy does not currently expect to have a required contribution to the pension plan. However, a decline in the value of pension plan assets could result in additional funding requirements and FirstEnergy may elect to contribute to the pension plan voluntarily. As of March 31, 2022, FirstEnergy’s OPEB plan assets were allocated approximately as follows: 50% in equity securities, 47% in fixed income securities and 3% in cash and short-term securities. See Note 4, “Pension and Other Post-Employment Benefits,” of the Notes to Consolidated Financial Statements for additional details on FirstEnergy’s pension and OPEB plans.

In the three months ended March 31, 2022, FirstEnergy’s pension and OPEB plan assets have lost approximately 5.8% and 4.8%, respectively, as compared to an annual expected return on plan assets of 7.5%.

Interest Rate Risk

FirstEnergy recognizes net actuarial gains or losses for its pension and OPEB plans in the fourth quarter of each year and whenever a plan is determined to qualify for a remeasurement. A primary factor contributing to these actuarial gains and losses are changes in the discount rates used to value pension and OPEB obligations as of the measurement date and the difference between expected and actual returns on the plans’ assets. FirstEnergy utilizes a spot rate approach in the estimation of the components of benefit cost by applying specific spot rates along the full yield curve to the relevant projected cash flows. As of March 31, 2022, the spot rate was 3.75% and 3.65% for pension and OPEB obligations, respectively, as compared to 3.02% and 2.84% as of December 31, 2021, respectively. At this time, FirstEnergy is unable to determine or project the mark-to-market adjustment that may be recorded as of December 31, 2022.

CREDIT RISK

Credit risk is the risk that FirstEnergy would incur a loss as a result of nonperformance by counterparties of their contractual obligations. FirstEnergy maintains credit policies and procedures with respect to counterparty credit (including requirement that counterparties maintain specified credit ratings) and require other assurances in the form of credit support or collateral in certain circumstance in order to limit counterparty credit risk. In addition, in response to the COVID-19 pandemic, FirstEnergy has increased reviews of counterparties, customers and industries that have been negatively impacted, which could affect meeting contractual obligations with FirstEnergy. FirstEnergy has concentrations of suppliers and customers among electric utilities, financial institutions and energy marketing and trading companies. These concentrations may impact FirstEnergy’s overall exposure to credit risk, positively or negatively, as counterparties may be similarly affected by changes in economic, regulatory or other conditions. In the event an energy supplier of the Ohio Companies, Pennsylvania Companies, JCP&L or PE defaults on its obligation, the affected company would be required to seek replacement power in the market. In general, subject to regulatory review or other processes, it is expected that appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. FirstEnergy’s credit policies to manage credit risk include the use of an established credit approval process, daily credit mitigation provisions, such as margin, prepayment or collateral requirements, and surveys to determine negative impacts to essential vendors as a result of the COVID-19 pandemic. FE and its subsidiaries may request additional credit assurance, in certain circumstances, in the event that the counterparties’ credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit.

OUTLOOK

STATE REGULATION

Each of the Utilities' retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE in Virginia, ATSI in Ohio, and the Transmission Companies in Pennsylvania are subject to certain regulations of the VSCC, PUCO and PPUC, respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and operate the new transmission facility.

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MARYLAND

PE operates under MDPSC approved base rates that were effective as of March 23, 2019. PE also provides SOS pursuant to a combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS. PE expects to file a new base rate case in early 2023, consistent with the MDPSC’s order issued on March 22, 2019.

The EmPOWER Maryland program requires each electric utility to file a plan to reduce electric consumption and demand 0.2% per year, up to the ultimate goal of 2% annual savings, for the duration of the 2021-2023 EmPOWER Maryland program cycles to the extent the MDPSC determines that cost-effective programs and services are available. PE's approved 2021-2023 EmPOWER Maryland plan continues and expands upon prior years' programs for a projected total investment of approximately $148 million over the three-year period. PE recovers program investments with a return through an annually reconciled surcharge, with most costs subject to recovery over a five-year period with a return on the unamortized balance. Maryland law only allows for the utility to recover lost distribution revenue attributable to energy efficiency or demand reduction programs through a base rate case proceeding, and to date, such recovery has not been sought or obtained by PE.

NEW JERSEY

JCP&L operates under NJBPU approved rates that were effective for customers as of November 1, 2021. JCP&L provides BGS for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from customers as a charge separate from base rates.

JCP&L has instituted energy efficiency and peak demand reduction programs in accordance with the New Jersey Clean Energy Act as approved by the NJBPU in April 2021. The NJBPU approved plans include recovery of lost revenues resulting from the programs and a three-year plan including total program costs of $203 million, of which $158 million of investment is recovered over a ten-year amortization period with a return as well as operations and maintenance expenses and financing costs of $45 million recovered on an annual basis.

In December 2017, the NJBPU issued proposed rules to modify its current CTA policy in base rate cases to: (i) calculate savings using a five-year look back from the beginning of the test year; (ii) allocate savings with 75% retained by the company and 25% allocated to customers; and (iii) exclude transmission assets of electric distribution companies in the savings calculation. On January 17, 2019, the NJBPU approved the proposed CTA rules with no changes. On May 17, 2019, the NJ Rate Counsel filed an appeal with the Appellate Division of the Superior Court of New Jersey and on June 7, 2021, the Superior Court issued an order reversing the NJBPU’s CTA rules and remanded the case back to the NJBPU. Specifically, the Court’s ruling requires 100% of the CTA savings to be credited to customers in lieu of the NJBPU’s current policy requiring 25%. On December 6, 2021, the NJBPU issued proposed amended rules modifying its current CTA policy in base rate cases consistent with the Superior Court’s June 7, 2021 order. Comments were filed on March 3, 2022. Once the proposed rules are final, they will be applied on a prospective basis in a future base rate case, however, it is not expected to have a material adverse effect on FirstEnergy’s results or financial condition.

On October 28, 2020, the NJBPU approved a stipulated settlement between JCP&L and various parties, resolving JCP&L’s request for distribution base rate increase. The settlement provided for a $94 million annual base distribution revenues increase for JCP&L based on an ROE of 9.6%, which became effective for customers on November 1, 2021. The settlement additionally provided that JCP&L would be subject to a management audit. The management audit began in May 2021 and is currently ongoing.

On August 27, 2020, JCP&L filed an AMI Program with the NJBPU, which proposed the deployment of approximately 1.2 million advanced meters over a three-year period beginning on January 1, 2023, at a total cost of approximately $418 million, including the pre-deployment phase. The then proposed 3-year deployment was part of the 20-year AMI Program that was projected to cost approximately $732 million and proposed a cost recovery mechanism through a separate AMI tariff rider. On September 14, 2021, JCP&L submitted a supplemental filing, which reflected increases in the AMI Program’s costs. Under the revised AMI Program, during the first six years of the AMI Program from 2022 through 2027, JCP&L estimates costs of $494 million, consisting of capital expenditures of approximately $390 million, incremental operations and maintenance expenses of approximately $73 million and cost of removal of $31 million. On February 8, 2022, JCP&L filed with the NJBPU a stipulation entered into with the NJBPU staff, NJ Rate Counsel and others, that, pending NJBPU approval, would affirm the terms of the revised AMI Program. The Stipulation, which was approved by NJBPU order on February 23, 2022, also provides that the revised AMI Program-related capital costs, the legacy meter stranded costs, and the operations and maintenance expense will be deferred and placed in regulatory assets, with such amounts sought to be recovered in the JCP&L’s subsequent base rate cases.

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On July 2, 2020, the NJBPU issued an order allowing New Jersey utilities to track and create a regulatory asset for future recovery of all prudently incurred incremental costs arising from the COVID-19 pandemic beginning March 9, 2020 and continuing until the New Jersey Governor issues an order stating that the COVID-19 pandemic is no longer in effect. New Jersey utilities can request recovery of such regulatory asset in a stand-alone COVID-19 regulatory asset filing or future base rate case. On October 28, 2020, the NJBPU issued an order expanding the scope of the proceeding to examine all pandemic issues, including recovery of the COVID-19 regulatory assets, by way of a generic proceeding. Through various executive orders issued by the New Jersey Governor, the moratorium period was extended to December 31, 2021. On December 21, 2021, the moratorium on residential disconnections for certain entities providing utility service was extended until March 15, 2022. The moratorium on residential disconnections was not extended for investor-owned electric utilities such as JCP&L, but does require that investor-owned electric public utilities offer qualifying residential customers deferred payment arrangements meeting certain minimum criteria prior to disconnecting service. Additionally, while the moratorium on residential disconnections for certain entities providing electric service was not extended after March 15, 2022, new legislation was enacted on March 25, 2022, prohibiting utilities from disconnecting electric service to customers that have applied for utility bill assistance before June 15, 2022 until such time as the state agency administering the assistance program makes a decision on the application and further requiring that all utilities offer a deferred payment arrangement meeting certain minimum criteria after the state agency’s decision on the application has been made.

Pursuant to an NJBPU order requiring all New Jersey electric distribution companies to file electric vehicle programs, JCP&L filed its program on March 1, 2021. JCP&L’s proposed electric vehicle program consisted of six sub-programs, including a consumer education and outreach initiative that would begin on January 1, 2022, and continue over a four-year period. The total proposed budget for the electric vehicle program is approximately $50 million, including investments of $16 million and operations and maintenance expenses of $34 million. JCP&L is proposing to recover the electric vehicle program costs via a non-bypassable rate clause applicable to all distribution customer rate classes, which became effective on January 1, 2022. On May 26, 2021, a procedural schedule was set to include evidentiary hearings the week of October 18, 2021. On July 16, 2021, the procedural schedule was extended by thirty days as requested by JCP&L to continue settlement discussions. On August 19, 2021, the presiding commissioner issued an order modifying the procedural schedule by extending the procedural schedule by ninety days as requested by JCP&L to continue settlement discussions. On November 12, 2021, JCP&L filed a letter with the presiding commissioner requesting a suspension of the procedural schedule in order to allow the parties to continue settlement discussion. On November 23, 2021, the presiding commissioner entered an order suspending the procedural schedule. JCP&L expects an order from the NJBPU by the end of the second quarter of 2022.

OHIO

The Ohio Companies operate under PUCO approved base distribution rates that became effective in 2009. The Ohio Companies currently operate under ESP IV, effective June 1, 2016 and continuing through May 31, 2024, that continues the supply of power to non-shopping customers at a market-based price set through an auction process. ESP IV also continues the Rider DCR, which supports continued investment related to the distribution system for the benefit of customers, with increased revenue caps of $20 million per year from June 1, 2019 through May 31, 2022; and $15 million per year from June 1, 2022 through May 31, 2024. In addition, ESP IV includes: (1) continuation of a base distribution rate freeze through May 31, 2024; (2) a goal across FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and (3) contributions, totaling $51 million to: (a) fund energy conservation programs, economic development and job retention in the Ohio Companies’ service territories; (b) establish a fuel-fund in each of the Ohio Companies’ service territories to assist low-income customers; and (c) establish a Customer Advisory Council to ensure preservation and growth of the competitive market in Ohio.

On September 8, 2020, the OCC filed motions in the Ohio Companies’ corporate separation audit and DMR audit dockets, requesting the PUCO to open an investigation and management audit, hire an independent auditor, and require FirstEnergy to show it did not improperly use money collected from consumers or violate any utility regulatory laws, rules or orders in its activities regarding HB 6. On December 30, 2020, in response to the OCC's motion, the PUCO reopened the DMR audit docket, and directed PUCO staff to solicit a third-party auditor and conduct a full review of the DMR to ensure funds collected from customers through the DMR were only used for the purposes established in ESP IV. On June 2, 2021, the PUCO selected an auditor and the auditor filed the final audit report on January 14, 2022, which made certain findings and recommendations. The report found that spending of DMR revenues was not required to be tracked, and that DMR revenues, like all rider revenues, are placed into the regulated money pool as a matter of routine, where the funds lose their identity. Therefore, the report could not suggest that DMR funds were used definitively for direct or indirect support for grid modernization. The report also concluded that there was no documented evidence that ties revenues from the DMR to lobbying for the passage of HB 6, but also could not rule out with certainty uses of DMR funds to support the passage of HB 6. The report further recommended that the regulated companies' money pool be audited more frequently and the Ohio Companies adopt formal dividend policies.

On September 15, 2020, the PUCO opened a new proceeding to review the political and charitable spending by the Ohio Companies in support of HB 6 and the subsequent referendum effort, and directing the Ohio Companies to show cause, demonstrating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers. The Ohio Companies initially filed a response stating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers, but on August 6, 2021, filed a supplemental response explaining that, in light of the facts set forth in the DPA and the findings of the Rider DCR audit report further discussed below,

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political or charitable spending in support of HB 6, or the subsequent referendum effort, affected pole attachment rates paid by approximately $15 thousand. On October 26, 2021, the OCC filed a motion requesting the PUCO to order an independent external audit to investigate FE’s political and charitable spending related to HB 6, and to appoint an independent review panel to retain and oversee the auditor. In November and December 2021, parties filed comments and reply comments regarding the Ohio Companies’ original and supplemental responses to the PUCO’s September 15, 2020, show cause directive. On March 9, 2022, the PUCO directed its staff to seek the services of a third-party auditor to determine whether the show cause demonstration submitted by the Ohio Companies is sufficient to ensure that the cost of any political or charitable spending in support of HB 6 or the subsequent referendum effort was not included, directly or indirectly, in any rates or charges paid by ratepayers.

In connection with an ongoing audit of the Ohio Companies’ policies and procedures relating to the code of conduct rules between affiliates, on November 4, 2020, the PUCO initiated an additional corporate separation audit as a result of the FirstEnergy leadership transition announcement made on October 29, 2020, as further discussed below. The additional audit is to ensure compliance by the Ohio Companies and their affiliates with corporate separation laws and the Ohio Companies’ corporate separation plan. The additional audit is for the period from November 2016 through October 2020. The final audit report was filed on September 13, 2021. The audit report makes no findings of major non-compliance with Ohio corporate separation requirements, minor non-compliance with eight requirements, and findings of compliance with 23 requirements. Parties filed comments and reply comments on the audit report, and a PUCO attorney examiner has issued a procedural schedule setting an evidentiary hearing on August 22, 2022.

In the fourth quarter of 2020, motions were filed with the PUCO requesting that the PUCO amend the Ohio Companies’ riders for collecting the OVEC related charges required by HB 6, which the Ohio Companies are further required to remit to other Ohio electric distribution utilities or to the State Treasurer, to provide for refunds in the event such provisions of HB 6 are repealed. The Ohio Companies contested the motions, which are pending before the PUCO.

On November 1, 2021, the Ohio Companies, together with the OCC, PUCO Staff, and several other signatories, entered into an Ohio Stipulation with the intent of resolving the ongoing energy efficiency rider audits, various SEET proceedings, including the Ohio Companies’ 2017 SEET proceeding, and the Ohio Companies’ quadrennial ESP review, each of which was pending before the PUCO. Specifically, the Ohio Stipulation provides that the Ohio Companies’ current ESP IV passes the required statutory test for their prospective SEET review as part of the Quadrennial Review of ESP IV, and except for limited circumstances, the signatory parties have agreed not to challenge the Ohio Companies’ SEET return on equity calculation methodology for their 2021-2024 SEET proceedings. The Ohio Stipulation additionally affirms that: (i) the Ohio Companies’ ESP IV shall continue through its previously authorized term of May 31, 2024; and (ii) the Ohio Companies will file their next base rate case in May 2024, and further, no signatory party will seek to adjust the Ohio Companies’ base distribution rates before that time, except in limited circumstances. The Ohio Companies further agreed to refund $96 million to customers in connection with the 2017-2019 SEET cases, and to provide $210 million in future rate reductions for all customers, including $80 million in 2022, $60 million in 2023, $45 million in 2024, and $25 million in 2025. The PUCO approved the 2017-2019 SEET refunds and 2022 rate reductions December 1, 2021, and refunds began in January 2022. Future rate reductions are recognized as a reduction to regulated distribution segment’s revenue in the Consolidated Statements of Income as they are provided to the Ohio Companies’ customers.

In connection with an ongoing annual audit of the Ohio Companies’ Rider DCR for 2020, and as a result of disclosures in FirstEnergy’s Form 10-K for the year ended December 31, 2020 (filed on February 18, 2021), the PUCO expanded the scope of the audit on March 10, 2021, to include a review of certain transactions that were either improperly classified, misallocated, or lacked supporting documentation, and to determine whether funds collected from customers were used to pay the vendors, and if so, whether or not the funds associated with those payments should be returned to customers through Rider DCR or through an alternative proceeding. On August 3, 2021, the auditor filed its final report on this phase of the audit, and the parties submitted comments and reply comments on this audit report in October 2021. Additionally, on September 29, 2021, the PUCO expanded the scope of the audit in this proceeding to determine if the costs of the naming rights for FirstEnergy Stadium have been recovered from the Ohio Companies’ customers. On November 19, 2021, the auditor filed its final report, in which the auditor concluded that the FirstEnergy Stadium naming rights expenses were not recovered from Ohio customers. On December 15, 2021, the PUCO further expanded the scope of the audit to include an investigation into an apparent nondisclosure of a side agreement in the Ohio Companies’ ESP IV settlement proceedings, but stayed its expansion of the audit until otherwise ordered by the PUCO.

See below for additional details on the government investigations and subsequent litigation surrounding the investigation of HB 6.

PENNSYLVANIA

The Pennsylvania Companies operate under rates approved by the PPUC, effective as of January 27, 2017. On November 18, 2021, the PPUC issued orders to each of the Pennsylvania Companies directing they operate under DSPs for the June 1, 2019 through May 31, 2023 delivery period, which DSPs provide for the competitive procurement of generation supply for customers who do not receive service from an alternative EGS. Under the 2019-2023 DSPs, supply will be provided by wholesale suppliers through a mix of 3, 12 and 24-month energy contracts, as well as two RFPs for 2-year SREC contracts for ME, PN and Penn. On

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December 14, 2021, the Pennsylvania Companies filed proposed DSPs for provision of generation for the June 1, 2023 through May 31, 2027 delivery period, to be sourced through competitive procurements for customers who do not receive service from an alternative EGS. An evidentiary hearing was held on April 13, 2022, and the parties filed a partial settlement with the PPUC resolving most of the issues in the proceeding on April 20, 2022. The remaining issues in the proceeding, which are limited to the treatment of customer-generated energy and renewable energy credit production will be resolved through briefing. Under the 2023-2027 DSPs, supply is proposed to be provided through a mix of 12 and 24-month energy contracts, as well as long-term solar PPAs.

In March 2018, the PPUC approved adjusted customer rates of the Pennsylvania Companies to reflect the net impact of the Tax Act. As a result, the Pennsylvania Companies established riders that, beginning July 1, 2018, refunded to customers tax savings attributable to the Tax Act as compared to the amounts established in their most recent base rate proceedings on a current and going forward basis. The amounts recorded as savings for the total period of January 1 through June 30, 2018, were tracked and were to be addressed for treatment in a future proceeding. On May 17, 2021, the Pennsylvania Companies filed petitions with the PPUC proposing to refund the net savings for the January through June 2018 period to customers beginning January 1, 2022. On November 18, 2021, the PPUC approved the Pennsylvania Companies' proposed refunds, but also revised a previous methodology for calculating the net tax savings, which resulted in additional tax savings attributable to the Tax Act to be refunded to customers and directed the Pennsylvania Companies to file new petitions to propose the timing and methodology to provide these additional refunds to customers. The Pennsylvania Companies recalculated the net impact for 2018 through 2021 under the revised PPUC methodology in comparison to amounts already refunded to customers under the existing riders, which resulted in an additional $61 million in savings, with interest, to be provided to customers. As a result, FirstEnergy recognized a pre-tax charge of $61 million in the fourth quarter of 2021 associated with the additional refund and based on the November 2021 PPUC order and methodology. The Pennsylvania Companies filed petitions to propose the timing and methodology of the refund of these amounts on February 17, 2022. If approved, the Pennsylvania Companies would refund these amounts beginning July 1, 2022, and continuing through the end of the year.

Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, Pennsylvania EDCs implement energy efficiency and peak demand reduction programs. On June 18, 2020, the PPUC entered a Final Implementation Order for a Phase IV EE&C Plan, operating from June 2021 through May 2026. The Final Implementation Order set demand reduction targets, relative to 2007 to 2008 peak demands, at 2.9% MW for ME, 3.3% MW for PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania Companies’ historic 2009 to 2010 reference load at 3.1% MWH for ME, 3.0% MWH for PN, 2.7% MWH for Penn, and 2.4% MWH for WP. The Pennsylvania Companies’ Phase IV plans were approved by PPUC without modification on March 25, 2021.

Pennsylvania EDCs are permitted to seek PPUC approval of an LTIIP for infrastructure improvements and costs related to highway relocation projects, after which a DSIC may be approved to recover LTIIP costs. On January 16, 2020, the PPUC approved the Pennsylvania Companies’ LTIIPs for the five-year period beginning January 1, 2020 and ending December 31, 2024 for a total capital investment of approximately $572 million for certain infrastructure improvement initiatives. On June 25, 2021, the Pennsylvania OCA filed a complaint against Penn’s quarterly DSIC rate, disputing the recoverability of the Companies’ automated distribution management system investment under the DSIC mechanism. On January 26, 2022, the parties filed a joint petition for settlement that resolves all issues in this matter pending PPUC approval.

Following the Pennsylvania Companies’ 2016 base rate proceedings, the PPUC ruled in a separate proceeding related to the DSIC mechanisms that the Pennsylvania Companies were not required to reflect federal and state income tax deductions related to DSIC-eligible property in DSIC rates. The decision was appealed to the Pennsylvania Supreme Court and in July 2021 the court upheld the Pennsylvania Commonwealth Court’s reversal of the PPUC’s decision and remanded the matter back to the PPUC for determination as to how DSIC calculations shall account for ADIT and state taxes. The matter awaits further action by the PPUC. The adverse ruling by the Pennsylvania Supreme Court is not expected to result in a material impact to FirstEnergy.

WEST VIRGINIA

MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate under WVPSC approved rates that became effective in February 2015. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s ENEC rate is updated annually.

On December 30, 2020, MP and PE filed with the WVPSC a determination of the rate impact of the Tax Act with respect to ADIT. The filing proposed an annual revenue reduction of $2.6 million, effective January 1, 2022, with reconciliation and any resulting adjustments incorporated into annual ENEC proceedings. On August 12, 2021, a unanimous settlement was reached with all the parties agreeing to a $7.7 million rate reduction beginning January 1, 2022, with a true-up in the ENEC proceeding each year. On November 30, 2021, the WVPSC approved the settlement on all terms, except for the proposed effective date of the rate reduction, which was held in abeyance until further notice.

On August 27, 2021, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates of $19.6 million beginning January 1, 2022, which represented a 1.5% increase to the rates currently in effect. WVPSC issued an order on December 29, 2021, granting the requested $19.6 million increase in ENEC rates. Among other things, the order requires MP

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and PE to refund to its large industrial customers their respective portion of the $7.7 million rate reduction discussed above and also requires MP and PE to negotiate a PPA for its capacity shortfall and a reasonable reserve margin if certain conditions are met. By order dated March 2, 2022, the WVPSC reopened the case to determine whether rates should be increased to recover growing ENEC under-recoveries. MP and PE proposed a $94 million rate increase to address the growing under-recoveries and a hearing was held on March 24, 2022. Any interim rate increase approved by WVPSC would be expected to begin May 1, 2022.

On December 3, 2021 and on December 27, 2021, the WVPSC approved settlements granting MP and PE a $16 million increase in rates effective January 1, 2022, and permitting the continuation of the vegetation management program and surcharge for another two years. WVPSC additionally ordered MP and PE to perform equipment inspections within a reasonable time after vegetation management occurs on a circuit.

On November 22, 2021, MP and PE filed with the WVPSC their plan to construct 50 MWs of solar generation at five sites in West Virginia. The plan includes a tariff to offer solar power to West Virginia customers and cost recovery for MP and PE from other customers through a surcharge for any solar investment not fully subscribed by their customers. A hearing was held on March 16 and 17, 2022, and an order is expected in the second quarter of 2022. The solar generation project, if approved, is expected to cost approximately $110 million and begin being in-serviced by the end of 2023 with all construction completed at the other sites no later than the end of 2025.

On December 17, 2021, MP and PE filed with the WVPSC for approval of environmental compliance projects at the Ft. Martin and Harrison Power Stations to comply with the EPA’s ELG and operate these plants beyond 2028. The request includes a surcharge to recover the expected $142 million capital investment and $3 million in annual operation and maintenance expense. A hearing has been set for in August 2022, with a ruling from the WVPSC expected in the fall of 2022. If approved, construction would be expected to be completed by the end of 2025. See “Outlook - Environmental Matters - Clean Water Act" below, for additional details on the EPA's ELG.

FERC REGULATORY MATTERS

Under the FPA, FERC regulates rates for interstate wholesale sales, transmission of electric power, accounting and other matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the Utilities, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP, PE, WP and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and conditions. Transmission facilities of JCP&L, MP, PE, WP and the Transmission Companies are subject to functional control by PJM and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.

FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or erect barriers to entry into markets. The Utilities and AE Supply each have been authorized by FERC to sell wholesale power in interstate commerce at market-based rates and have a market-based rate tariff on file with FERC, although in the case of the Utilities major wholesale purchases remain subject to review and regulation by the relevant state commissions.

Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-keeping and reporting requirements on the Utilities, AE Supply, and the Transmission Companies. NERC is the ERO designated by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are located within the RFC region. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards implemented and enforced by RFC.

FirstEnergy believes that it is in material compliance with all currently effective and enforceable reliability standards. Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial condition, results of operations, and cash flows.

FERC Audit

FERC’s Division of Audits and Accounting initiated a nonpublic audit of FESC in February 2019. Among other matters, the audit is evaluating FirstEnergy’s compliance with certain accounting and reporting requirements under various FERC regulations. On February 4, 2022, FERC filed the final audit report for the period of January 1, 2015 through September 30, 2021, which included several findings and recommendations. FirstEnergy has accepted the findings and recommendations of the final audit report. The audit report included a finding and related recommendation that FirstEnergy may have used an inappropriate methodology

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for allocation of certain costs to regulatory capital accounts under certain FERC regulations and reporting. As such, FirstEnergy is currently performing an analysis of these costs and how it impacted certain wholesale transmission customer rates. FirstEnergy is unable to predict or estimate the final outcome of this analysis and audit, however, it could result in refunds, with interest, to certain wholesale transmission customers and/or write-offs of previously capitalized costs if they are determined to be nonrecoverable.

ATSI Transmission Formula Rate

On May 1, 2020, ATSI filed amendments to its formula rate to recover regulatory assets for certain costs that ATSI incurred as a result of its 2011 move from MISO to PJM, certain costs allocated to ATSI by FERC for transmission projects that were constructed by other MISO transmission owners, and certain costs for transmission-related vegetation management programs. A portion of these costs would have been charged to the Ohio Companies. Additionally, ATSI proposed certain income tax-related adjustments and certain tariff changes addressing the revenue credit components of the formula rate template. On June 30, 2020, FERC issued an initial order accepting the tariff amendments subject to refund and setting the matter for hearing and settlement proceedings. ATSI and the parties to the FERC proceeding subsequently were able to reach settlement, and on October 14, 2021, filed the settlement with FERC. As a result of the filed settlement, FirstEnergy recognized a $21 million pre-tax charge during the third quarter of 2021, which reflects the difference between amounts originally recorded as regulatory assets and amounts which will ultimately be recovered as a result of the pending settlement. From a segment perspective, during the third quarter of 2021, the Regulated Transmission segment recorded a pre-tax charge of $48 million and the Regulated Distribution segment recognized a $27 million reduction to a reserve previously recorded in 2010. In addition, the settlement provides for partial recovery of future incurred costs allocated to ATSI by MISO for the above-referenced transmission projects that were constructed by other MISO transmission owners, which is not expected to have a material impact on FirstEnergy or ATSI. The uncontested settlement was approved by FERC on March 24, 2022 without modification.

FERC Actions on Tax Act

On March 15, 2018, FERC initiated proceedings on the question of how to address possible changes to ADIT and bonus depreciation as a result of the Tax Act. Such possible changes could impact FERC-jurisdictional rates, including transmission rates. On November 21, 2019, FERC issued a final rule (Order No. 864). Order No. 864 requires utilities with transmission formula rates to update their formula rate templates to include mechanisms to: (i) deduct any excess ADIT from or add any deficient ADIT to their rate base; (ii) raise or lower their income tax allowances by any amortized excess or deficient ADIT; and (iii) incorporate a new permanent worksheet into their rates that will annually track information related to excess or deficient ADIT. Per FERC directives, ATSI submitted its compliance filing on May 1, 2020. MAIT submitted its compliance filing on June 1, 2020. On November 18, 2021, FERC issued an order that: (i) accepted ATSI proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed ATSI to make a further compliance filing by January 17, 2022; and (iii) set the amount of ATSI’s recorded ADIT balances as of December 31, 2017, for hearing and settlement procedures. ATSI submitted the compliance filing, and is participating in settlement negotiations. On December 3, 2021, FERC issued an order that (i) accepted MAIT’s proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed MAIT to make a further compliance filing by February 1, 2022; and (iii) set the amount of MAIT’s recorded ADIT balances as of December 31, 2017 for hearing and settlement procedures. MAIT submitted the compliance filing, and is participating in settlement negotiations. On May 15, 2020, TrAIL submitted its compliance filing and on June 1, 2020, PATH submitted its required compliance filing. On May 4, 2021, FERC staff requested additional information about PATH’s proposed rate base adjustment mechanism, and PATH submitted the requested information on June 3, 2021. On July 12, 2021, FERC staff requested additional information about TrAIL’s proposed rate base adjustment mechanism. TrAIL filed its response on August 6, 2021. On March 31, 2022, FERC issued an order, ruling that TrAIL’s compliance filing partially complied with the requirements of Order No. 864 and directing TrAIL to submit a further compliance filing on or before May 31, 2022 to address certain additional items that according to FERC further will enhance transparency. The PATH compliance filing remains pending before FERC. MP, WP and PE (as holders of a “stated” transmission rate when Order No. 864 issued) are addressing these requirements in the transmission formula rates amendments that were filed on October 29, 2020, and which have been accepted by FERC effective January 1, 2021, subject to refund, pending further hearing and settlement procedures. MP, WP and PE are engaged in settlement negotiations with other parties to this proceeding.

ATSI ROE – Ohio Consumers Counsel v. ATSI, et al.

On February 24, 2022, the OCC filed a complaint with FERC against ATSI, AEP’s Ohio affiliates and AEPSC, and Duke Energy Ohio, LLC asserting that FERC should reduce the ROE utilized in the utilities’ transmission formula rates by eliminating the 50 basis point adder associated with RTO membership, effective February 24, 2022. The OCC contends that this result is required because Ohio law mandates that transmission owning utilities join an RTO and that the 50 basis point adder is applicable only where RTO membership is voluntary. ATSI disagrees with OCC’s characterization and set forth its reasons for such disagreement in a combined motion to dismiss and answer that was filed with FERC on March 31, 2022. On that same date, AEP and Duke filed separate motions to dismiss and answers to the OCC complaint, and several other parties filed comments. ATSI is currently evaluating whether to file an additional answer to respond to certain of the comments.

Transmission ROE Methodology

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On March 20, 2020, FERC initiated a rulemaking proceeding on the transmission rate incentives provisions of Section 219 of the 2005 Energy Policy Act. FirstEnergy submitted comments through EEI and as part of a consortium of PJM Transmission Owners. In a supplemental rulemaking proceeding that was initiated on April 15, 2021, FERC requested comments on, among other things, whether to require utilities that have been members of an RTO for three years or more and that have been collecting an “RTO membership” ROE incentive adder to file tariff updates that would terminate collection of the incentive adder. Initial comments on the proposed rule were filed on June 25, 2021, and reply comments were filed on July 26, 2021. The rulemaking remains pending before FERC. FirstEnergy is a member of PJM and its transmission subsidiaries could be affected by the supplemental proposed rule. FirstEnergy participated in comments on the supplemental rulemaking that were submitted by a group of PJM transmission owners and by various industry trade groups. If there were to be any changes to FirstEnergy transmission incentive ROE, such changes will be applied on a prospective basis.

Allegheny Power Zone Transmission Formula Rate Filings

On October 29, 2020, MP, PE and WP filed tariff amendments with FERC to implement a forward-looking formula transmission rate, to be effective January 1, 2021. In addition, on October 30, 2020, KATCo filed a proposed new tariff to establish a forward-looking formula rate and requested that the new rate become effective January 1, 2021. In its filing, KATCo explained that while it currently owns no transmission assets, it may build new transmission facilities in the Allegheny zone, and that it may seek required state and federal authorizations to acquire transmission assets from PE and WP by January 1, 2022. These transmission rate filings were accepted for filing by FERC on December 31, 2020, effective January 1, 2021, subject to refund, pending further hearing and settlement procedures and were consolidated into a single proceeding. MP, PE and WP, and KATCo are engaged in settlement negotiations with the other parties to the formula rate proceedings.

ENVIRONMENTAL MATTERS

Various federal, state and local authorities regulate FirstEnergy with regard to air and water quality, hazardous and solid waste disposal, and other environmental matters. While FirstEnergy’s environmental policies and procedures are designed to achieve compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and potential revision by the implementing agencies. FirstEnergy cannot predict the timing or ultimate outcome of any of these reviews or how any future actions taken as a result thereof may materially impact its business, results of operations, cash flows and financial condition.

Clean Air Act

FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP(s) by burning lower-sulfur fuel, utilizing combustion controls and post-combustion controls and/or using emission allowances.

CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and SO2 emission allowances between power plants located in the same state and interstate trading of NOx and SO2 emission allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx and SO2 emissions from power plants in 13 states, including West Virginia. This followed the 2014 U.S. Supreme Court ruling generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on September 7, 2016, reducing summertime NOx emissions from power plants in 22 states in the eastern U.S., including West Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable attainment deadlines.

Also in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone NAAQS. The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126 petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA issued a revised CSAPR Update that addresses, among other things, the remands of the prior CSAPR Update and the New York Section 126 petition. In December 2021, MP purchased NOx emissions allowances to comply with 2021 ozone season requirements. On April 6, 2022, the EPA published proposed rules seeking to impose further significant reductions in EGU NOx emissions in 25 states, including West Virginia. The EPA held a virtual public hearing regarding the proposed rules on April 21, 2022, with comments due June 6, 2022. Depending on the outcome of any appeals and how the EPA and the states ultimately implement the revised CSAPR Update, the future cost of compliance may materially impact FirstEnergy's operations, cash flows and financial condition.

Climate Change

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There are several initiatives to reduce GHG emissions at the state, federal and international level. Certain northeastern states are participating in the RGGI and western states led by California, have implemented programs, primarily cap and trade mechanisms, to control emissions of certain GHGs. Additional policies reducing GHG emissions, such as demand reduction programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.

In September 2016, the U.S. joined in adopting the agreement reached on December 12, 2015, at the United Nations Framework Convention on Climate Change meetings in Paris to reduce GHGs. The Paris Agreement’s non-binding obligations to limit global warming to below two degrees Celsius became effective on November 4, 2016. On June 1, 2017, the Trump Administration announced that the U.S. would cease all participation in the Paris Agreement. On January 20, 2021, President Biden signed an executive order re-adopting the agreement on behalf of the U.S. In November 2020, FirstEnergy published its Climate Story which includes its climate position and strategy, as well as a new comprehensive and ambitious GHG emission goal. FirstEnergy pledged to achieve carbon neutrality by 2050 and set an interim goal for a 30% reduction in GHGs within FirstEnergy’s direct operational control by 2030, based on 2019 levels. Future resource plans to achieve carbon reductions, including any determination of retirement dates of the regulated coal-fired generation, will be developed by working collaboratively with regulators in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory disallowances. If MP is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s financial condition, results of operations, and cash flow. Furthermore, FirstEnergy cannot currently estimate the financial impact of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions, or litigation alleging damages from GHG emissions, could require material capital and other expenditures or result in changes to its operations.

In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air Act,” concluding that concentrations of several key GHGs constitute an "endangerment" and may be regulated as "air pollutants" under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generating plants. Subsequently, the EPA released its final CPP regulations in August 2015 to reduce CO2 emissions from existing fossil fuel-fired EGUs and finalized separate regulations imposing CO2 emission limits for new, modified, and reconstructed fossil fuel-fired EGUs. Numerous states and private parties filed appeals and motions to stay the CPP with the D.C. Circuit in October 2015. On February 9, 2016, the U.S. Supreme Court stayed the rule during the pendency of the challenges to the D.C. Circuit and U.S. Supreme Court. On March 28, 2017, an executive order, entitled “Promoting Energy Independence and Economic Growth,” instructed the EPA to review the CPP and related rules addressing GHG emissions and suspend, revise or rescind the rules if appropriate. On June 19, 2019, the EPA repealed the CPP and replaced it with the ACE rule that established guidelines for states to develop standards of performance to address GHG emissions from existing coal-fired generation. On January 19, 2021, the D.C. Circuit vacated and remanded the ACE rule declaring that the EPA was “arbitrary and capricious” in its rule making and, as such, the ACE rule is no longer in effect and all actions thus far taken by states to implement the federally mandated rule are now null and void. The D.C. Circuit decision was appealed by several states, including West Virginia, as well as other interested parties. On February 28, 2022, the U.S. Supreme Court heard oral arguments on the matter is subject to legal challenge. Depending on the outcomes of the appeal and how any final rules are ultimately implemented, the future cost of compliance may be material.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal CWA and its amendments, apply to FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to FirstEnergy’s operations.

On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category (40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of pollutants in ash transport water. The treatment obligations were to phase-in as permits are renewed on a five-year cycle from 2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water, (with some limited discharge allowances), and extending the deadline for compliance to December 31, 2025 for both. In addition, the EPA allows for less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system, and unit retirement date. The EPA is reconsidering the ELG rule with a publicly announced target of issuing a proposed revised rule in the Fall of 2022 and a final rule by the Spring of 2023. In the interim, the rule issued on August 31, 2020, remains in effect. Depending on the outcome of appeals and how final rules are ultimately implemented, the compliance with these standards, could require additional capital expenditures or changes in operations at Ft. Martin and Harrison power stations from what was filed with the WVPSC in December 2021 that seeks approval of environmental compliance projects to comply with the EPA’s ELG.

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After the completion of a negotiated settlement, a complaint was filed by the EPA and PA DEP on January 10, 2022 in Federal District Court for the Western District of Pennsylvania, alleging, among other things, that WP violated the CWA in connection with past boron exceedances at WP’s Springdale and Mingo landfills. On January 11, 2022, WP entered into a consent decree with the EPA and PA DEP resolving the matters addressed in the complaint, which, among other things, required a civil penalty of $610 thousand. The District Court entered the Consent Decree as final on March 17, 2022 and WP subsequently paid the penalty amount as required therein.

Regulation of Waste Disposal

Federal and state hazardous waste regulations have been promulgated as a result of the RCRA, as amended, and the Toxic Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending the EPA’s evaluation of the need for future regulation.

In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generating plants. On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29, 2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and initiate closure to April 11, 2021. The final rule also allows for an extension of the closure deadline based on meeting proscribed site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to extend the closure date of McElroy's Run CCR impoundment facility until 2024, which request is pending technical review by the EPA. AE Supply continues to operate McElroy’s Run as a disposal facility for FG’s Pleasants Power Station.

FE or its subsidiaries have been named as potentially responsible parties at waste disposal sites, which may require cleanup under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on the Consolidated Balance Sheets as of March 31, 2021, based on estimates of the total costs of cleanup, FirstEnergy’s proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of approximately $110 million have been accrued through March 31, 2022, of which, approximately $70 million are for environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through a non-bypassable SBC. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites, but the loss or range of losses cannot be determined or reasonably estimated at this time.

OTHER LEGAL PROCEEDINGS

United States v. Larry Householder, et al.

On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Also, on July 21, 2020, and in connection with the investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s Office for the S.D. Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020.

On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves this matter. Under the DPA, FE has agreed to the filing of a criminal information charging FE with one count of conspiracy to commit honest services wire fraud. The DPA requires that FirstEnergy, among other obligations: (i) continue to cooperate with the U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, which shall consist of (x) $115 million paid by FE to the United States Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and detect violations of the U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million payment will neither be recovered in rates or charged to FirstEnergy customers nor will FirstEnergy seek any tax deduction related to such payment. The entire amount of the monetary penalty was recognized as expense in the second quarter of 2021, and paid in the third quarter of 2021. Under the terms of the DPA, the criminal information will be dismissed after FirstEnergy fully complies with its obligations under the DPA.

Legal Proceedings Relating to United States v. Larry Householder, et al.

On August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of possible securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers. On April 28, 2021, the SEC issued an additional subpoena to FE. While no contingency has been reflected in its consolidated financial statements,

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FE believes that it is probable that it will incur a loss in connection with the resolution of the SEC investigation. Given the ongoing nature and complexity of the review, inquiries and investigations, FE cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the SEC investigation.

In addition to the subpoenas referenced above under “—United States v. Larry Householder, et. al.” and the SEC investigation, certain FE stockholders and FirstEnergy customers filed several lawsuits against FirstEnergy and certain current and former directors, officers and other employees, and the complaints in each of these suits is related to allegations in the complaint and supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover an unspecified amount of damages (unless otherwise noted). Unless otherwise indicated, no contingency has been reflected in FirstEnergy’s consolidated financial statements with respect to these lawsuits as a loss is neither probable, nor is a loss or range of a loss reasonably estimable.

•In re FirstEnergy Corp. Securities Litigation (Federal District Court, S.D. Ohio); on July 28, 2020 and August 21, 2020, purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those actions have been consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017 and July 21, 2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by issuing misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11, 12(a)(2) and 15 of the Securities Act of 1933 as a result of alleged misrepresentations or omissions in connection with offerings of senior notes by FE in February and June 2020. FE believes that it is probable that it will incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•MFS Series Trust I, et al. v. FirstEnergy Corp., et al. and Brighthouse Funds II – MFS Value Portfolio, et al. v. FirstEnergy Corp., et al. (Federal District Court, S.D. Ohio) on December 17, 2021 and February 21, 2022, purported stockholders of FE filed complaints against FE, certain current and former officers, and certain current and former officers of EH. The complaints allege that the defendants violated Sections 10(b) and 20(a) of the Exchange Act by issuing alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seek the same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will incur losses in connection with the resolution of these lawsuits. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•State of Ohio ex rel. Dave Yost, Ohio Attorney General v. FirstEnergy Corp., et al. and City of Cincinnati and City of Columbus v. FirstEnergy Corp. (Common Pleas Court, Franklin County, OH, all actions have been consolidated); on September 23, 2020 and October 27, 2020, the OAG and the cities of Cincinnati and Columbus, respectively, filed complaints against several parties including FE (the OAG also named FES as a defendant), each alleging civil violations of the Ohio Corrupt Activity Act in connection with the passage of HB 6. On January 13, 2021, the OAG filed a motion for a temporary restraining order and preliminary injunction against FirstEnergy seeking to enjoin FirstEnergy from collecting the Ohio Companies' decoupling rider. On January 31, 2021, FE reached a partial settlement with the OAG and the cities of Cincinnati and Columbus with respect to the temporary restraining order and preliminary injunction request and related issues. In connection with the partial settlement, the Ohio Companies filed an application on February 1, 2021, with the PUCO to set their respective decoupling riders (CSR) to zero. On February 2, 2021, the PUCO approved the application of the Ohio Companies setting the rider to zero and no additional customer bills will include new decoupling rider charges after February 8, 2021. The cases are stayed pending final resolution of the United States v. Larry Householder, et al. criminal proceeding described above, although on August 13, 2021, new defendants were added to the complaint, including two former officers of FirstEnergy. On November 9, 2021, the OAG filed a motion to lift the agreed-upon stay, which FE opposed on November 19, 2021; the motion remains pending. On December 2, 2021, the cities and FE entered a stipulated dismissal with prejudice of the cities’ suit.

•Smith v. FirstEnergy Corp. et al., Buldas v. FirstEnergy Corp. et al., and Hudock and Cameo Countertops, Inc. v. FirstEnergy Corp. et al. (Federal District Court, S.D. Ohio, all actions have been consolidated); on July 27, 2020, July 31, 2020, and August 5, 2020, respectively, purported customers of FE filed putative class action lawsuits against FE and FESC, as well as certain current and former FE officers, alleging civil Racketeer Influenced and Corrupt Organizations Act violations and related state law claims. FE agreed to a settlement to resolve these claims on April 11, 2022. In the fourth quarter of 2021, FirstEnergy recognized a pre-tax reserve of $37.5 million in the aggregate with respect to these lawsuits and the Emmons lawsuit below.

•Emmons v. FirstEnergy Corp. et al. (Common Pleas Court, Cuyahoga County, OH); on August 4, 2020, a purported customer of FirstEnergy filed a putative class action lawsuit against FE, FESC, the Ohio Companies, along with FES, alleging several causes of action, including negligence and/or gross negligence, breach of contract, unjust enrichment, and unfair or deceptive consumer acts or practices. FE agreed to a settlement to resolve these claims on April 11, 2022. In the fourth quarter of 2021, FirstEnergy recognized a pre-tax reserve of $37.5 million in the aggregate with respect to this lawsuit and the lawsuits above consolidated with Smith in the S.D. Ohio alleging, among other things, civil violations of the Racketeer Influenced and Corrupt Organizations Act.

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On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve the following shareholder derivative lawsuits relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder that were filed in the S.D. Ohio, the N.D. Ohio, and the Ohio Court of Common Pleas, Summit County:

•Gendrich v. Anderson, et al. and Sloan v. Anderson, et al. (Common Pleas Court, Summit County, OH, all actions have been consolidated); on July 26, 2020 and July 31, 2020, respectively, purported stockholders of FE filed shareholder derivative action lawsuits against certain FE directors and officers, alleging, among other things, breaches of fiduciary duty.

•Miller v. Anderson, et al. (Federal District Court, N.D. Ohio); Bloom, et al. v. Anderson, et al.; Employees Retirement System of the City of St. Louis v. Jones, et al.; Electrical Workers Pension Fund, Local 103, I.B.E.W. v. Anderson et al.; Massachusetts Laborers Pension Fund v. Anderson et al.; The City of Philadelphia Board of Pensions and Retirement v. Anderson et al.; Atherton v. Dowling et al.; Behar v. Anderson, et al. (Federal District Court, S.D. Ohio, all actions have been consolidated); beginning on August 7, 2020, purported stockholders of FE filed shareholder derivative actions alleging the FE Board and officers breached their fiduciary duties and committed violations of Section 14(a) of the Exchange Act.

On March 11, 2022, the parties executed a stipulation and agreement of settlement, and filed a motion the same day requesting preliminary settlement approval in the S.D. Ohio. The settlement agreement, if approved, will fully resolve the shareholder derivative lawsuits above and stipulates a series of corporate governance enhancements, that has resulted or is expected to result in the following:

•Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D. Pappas and Luis A. Reyes, and Ms. Julia L. Johnson are not standing for re-election at FE’s 2022 annual shareholder meeting;

•A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;

•The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political and lobbying action plans prepared by management;

•An FE Board committee of recently appointed independent directors will oversee the implementation and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;

•FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced disclosure in its annual proxy statement; and

•FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.

The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any court-ordered attorney’s fees awarded to plaintiffs.

In letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that the Division is conducting an investigation of FirstEnergy’s lobbying and governmental affairs activities concerning HB 6, and staff directed FirstEnergy to preserve and maintain all documents and information related to the same as such have been developed as part of an ongoing non-public audit being conducted by FERC's Division of Audits and Accounting. While no contingency has been reflected in the consolidated financial statements, FirstEnergy believes that it is probable that it will incur a loss in connection with the resolution of the FERC investigation. Given the ongoing nature and complexity of the review, inquiries and investigations, FirstEnergy cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the FERC investigation.

The outcome of any of these lawsuits, governmental investigations and audit is uncertain and could have a material adverse effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.

Other Legal Matters

There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to FirstEnergy’s normal business operations pending against FE or its subsidiaries. The loss or range of loss in these matters is not expected to be material to FE or its subsidiaries. The other potentially material items not otherwise discussed above are described under Note 7, “Regulatory Matters.”

FirstEnergy accrues legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such costs. In cases where FirstEnergy determines that it is not probable, but reasonably possible that it has a material obligation, it discloses such obligations and the possible loss or range of loss if such estimate can be made. If it were ultimately determined that FE or its subsidiaries have legal liability or are otherwise made subject to liability based on any of the matters referenced above, it could have a material adverse effect on FE’s or its subsidiaries’ financial condition, results of operations, and cash flows.

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NEW ACCOUNTING PRONOUNCEMENTS

See Note 1, "Organization and Basis of Presentation," for a discussion of new accounting pronouncements.

ITEM 3.     QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See “FirstEnergy Corp. Management’s Discussion and Analysis of Financial Condition and Results of Operations — Market Risk Information” in Item 2 above.

ITEM 4.     CONTROLS AND PROCEDURES

(a) Evaluation of Disclosure Controls and Procedures

The management of FirstEnergy, with the participation of the Chief Executive Officer and Chief Financial Officer, have reviewed and evaluated the effectiveness of its disclosure controls and procedures, as defined under the Exchange Act, in Rules 13a-15(e) and 15d-15(e), as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer of FirstEnergy have concluded that its disclosure controls and procedures were effective as of the end of the period covered by this report.

(b) Changes in Internal Control over Financial Reporting

During the quarter ended March 31, 2022, there were no changes in internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that have materially affected, or are reasonably likely to materially affect, FirstEnergy’s internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1.        LEGAL PROCEEDINGS

Information required for Part II, Item 1 is incorporated by reference to the discussions in Note 7, “Regulatory Matters,” and Note 8, “Commitments, Guarantees and Contingencies,” of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

ITEM 1A.    RISK FACTORS

You should carefully consider the risk factors discussed in "Item 1A. Risk Factors" in FirstEnergy’s Annual Report on Form 10-K for the year ended December 31, 2021, which could materially affect FirstEnergy’s business, financial condition or future results.

ITEM 2.        UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3.        DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4.        MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5.        OTHER INFORMATION

None.

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ITEM 6.        EXHIBITS

Exhibit Number		Description
(A)	10.1	Form of 2022-2024 Cash-Based Performance-Adjusted Restricted Stock Unit Award Agreement
(A)	10.2	Form of 2022-2024 Stock-Based Performance-Adjusted Restricted Stock Unit Award Agreement
(A)	31.1	Certification of chief executive officer, as adopted pursuant to Rule 13a-14(a)
(A)	31.2	Certification of chief financial officer, as adopted pursuant to Rule 13a-14(a)
(A)	32	Certification of chief executive officer and chief financial officer, pursuant to 18 U.S.C. Section 1350
	101	The following materials from the Quarterly Report on Form 10-Q of FirstEnergy Corp. for the period ended March 31, 2022, formatted in iXBRL (Inline Extensible Business Reporting Language): (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income, (iii) Consolidated Balance Sheets, (iv) Consolidated Statements of Cash Flows, (v) related notes to these financial statements and (vi) document and entity information
	104	Cover Page Interactive Data File (the cover page XBRL tags are embedded within the Inline XBRL document contained in Exhibit 101)

(A) Provided herein in electronic format as an exhibit.

Pursuant to paragraph (b)(4)(iii)(A) of Item 601 of Regulation S-K, FirstEnergy has not filed as an exhibit to this Form 10-Q any instrument with respect to long-term debt if the respective total amount of securities authorized thereunder does not exceed 10% of its respective total assets, but hereby agrees to furnish to the SEC on request any such documents.

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SIGNATURES

Pursuant to the 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.

April 21, 2022

FIRSTENERGY CORP.

Registrant

/s/ Jason J. Lisowski

Jason J. Lisowski

Vice President, Controller
and Chief Accounting Officer 

EX-10.1

Exhibit 10.1

(Cash-Based Agreement)

FIRSTENERGY CORP.

2020 Incentive Compensation Plan

2022-2024 Performance-Adjusted Restricted Stock Unit Award Agreement

THIS 2022-2024 PERFORMANCE-ADJUSTED RESTRICTED STOCK UNIT AWARD AGREEMENT (the “Agreement”), effective as of [GRANT DATE], 2022 (the “Grant Date”), is entered into by and between the Company and [PARTICIPANT NAME] (the “Grantee”).

1.Definitions. Unless otherwise specified in this Agreement, capitalized terms shall have the meanings attributed to them under the Plan. For purposes of this Agreement, the following terms shall be defined as follows:

    (a)    “Retirement” shall mean the Grantee’s Separation from Service (except due to death) on or after attaining age fifty-five (55) and after providing at least ten (10) years of service to the Company or any Subsidiary or affiliate and any predecessor thereof; and

    (b)    “Separation from Service” shall mean, with respect to the Grantee, the “separation from service” within the meaning of Code Section 409A of the Grantee with the Company and any Subsidiaries, for any reason, including without limitation quit, discharge, leave of absence (including military leave, sick leave, or other bona fide leave of absence such as temporary employment by the government if the period of such leave exceeds the greater of six months or the period for which the Grantee’s right to reemployment is provided either by statute or by contract) or permanent decrease in service to a level that is no more than twenty percent (20%) of its prior level. For this purpose, whether a “Separation from Service” has occurred is determined based on whether it is reasonably anticipated that no further services will be performed by the Grantee after a certain date or that the level of bona fide services the Grantee will perform after such date (whether as an employee or as an independent contractor) would permanently decrease to no more than twenty percent (20%) of the average level of bona fide services performed (whether as an employee or an independent contractor) over the immediately preceding 36-month period (or the full period of services if the Grantee has been providing services for less than 36 months).

2.Grant of Restricted Stock Units. As of the Grant Date, the Company has granted to the Grantee [NUMBER OF UNITS GRANTED] (the “Target Number”) Restricted Stock Units (the “Restricted Stock Units” or “RSUs”), a percentage of which Target Number will vest and become payable in accordance with the terms and conditions of this Agreement. The Target Number shall be adjusted with respect to Dividend Equivalents as provided in Section 8 below. Each RSU that becomes vested and payable hereunder represents the right of the Grantee to receive the cash value of one Share subject to the terms and conditions of this Agreement. The RSUs are granted in accordance with, and subject to, all the terms, conditions and restrictions of the Plan, which is hereby incorporated by reference in its entirety. The Grantee irrevocably agrees to, and accepts, the terms, conditions and restrictions of the Plan and this Agreement on the Grantee’s own behalf and on behalf of any heirs, successors and assigns.

3.Restrictions on RSUs. Except as otherwise provided herein, the Grantee cannot sell, transfer, assign, hypothecate or otherwise dispose of the RSUs or pledge any RSU as collateral for a loan, other than by will or by the laws of descent and distribution. In no event may any RSU or this Award be transferred for value. In addition, the RSUs, and any payments made with respect to the RSUs, will be subject to such other restrictions as the Committee deems necessary or appropriate, including, without limitation, the Company’s Executive Compensation Recoupment Policy, as may be amended (or succeeded) from time to time, to the extent applicable.

4.Vesting and Settlement of RSUs.

(a)Vesting. Except as otherwise provided in Sections 6 and 7 below, if and to the extent the performance goals set forth on Exhibit A attached to this Agreement (the “Performance Goals”) are achieved during the performance period set forth on Exhibit A (the “Performance Period”), a percentage of the Target Number of RSUs will vest on March 1, 2025 (the “Vesting Date”), as long as the Grantee remains continuously employed by the Company or a Subsidiary until such Vesting Date. The number of RSUs that shall vest will range from 0% to 200% of the Target Number, as determined by the extent to which the Performance Goals are achieved. The Grantee will have no rights to any payment with respect to the RSUs until the RSUs have vested (each RSU that vests pursuant to this Section 4 or Sections 6 and 7 below, a “Vested RSU”). Prior to settlement, each RSU (whether or not a Vested RSU) represents an unfunded and unsecured obligation of the Company.

(b)Settlement. Except as otherwise provided in Sections 6, 7 and 10 below, the Company shall settle each Vested RSU by making a cash payment equal to the Fair Market Value of one Share per Vested RSU to the Grantee as soon as administratively practicable (and no later than 60 days) after the Vesting Date. With respect to any Vested RSU, the Fair Market Value of one Share shall be determined as of the Vesting Date, except as provided in Section 6. Notwithstanding the foregoing or any provision in Sections 6 or 7 to the contrary, if the Grantee elects to defer the settlement of the RSUs pursuant to the Company’s Executive Deferred Compensation Plan (or any other non-qualified deferred compensation plan providing for the ability to defer settlement of the RSUs), then the time, form and medium of payment with respect to any deferred RSUs shall be made pursuant to the terms and conditions of the Executive Deferred Compensation Plan (or similar non-qualified deferred compensation plan).

5.Forfeiture. Except as otherwise provided in Sections 6 and 7, the Grantee will forfeit his or her interest in the RSUs to the extent the Performance Goals are not achieved during the Performance Period or if the Grantee terminates his or her employment with the Company and its Subsidiaries prior to the Vesting Date.

6.Certain Events. Notwithstanding any provision in this Agreement to the contrary and in each case subject to Section 6(g) below:

(a)Death. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee dies, a prorated number of RSUs shall become Vested RSUs. For purposes of this Section 6(a), the number of RSUs that shall become Vested RSUs due to the Grantee’s death shall be equal to (i) the Target Number of RSUs multiplied by (ii) a fraction, where the numerator is the number of full calendar months the Grantee remained employed after the Grant Date and the denominator is 36. The Company shall settle any RSUs that become Vested RSUs under this Section 6(a) by paying the Grantee’s estate a cash amount equal to the Fair Market Value of one Share for each Vested RSU as soon as administratively practicable after the date of the Grantee’s death, but in any event, by March 15th of the year following the year in which the Grantee’s death occurred. For purposes of this Section 6(a), the Fair Market Value shall be determined as of the date of the Grantee’s death.

(b)Disability. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee’s employment is terminated due to the Grantee’s Disability, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested

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RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(b) by paying the Grantee a cash amount equal to the Fair Market Value of one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(c)Termination without Cause. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee’s employment is terminated by the Company and its Subsidiaries without Cause, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(c) by paying the Grantee a cash amount equal to the Fair Market Value of one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(d)Retirement. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee’s employment is terminated due to the Grantee’s Retirement, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(d) by paying the Grantee a cash amount equal to the Fair Market Value of one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(e)Change in Position. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee is transferred to a position with the Company or a Subsidiary that is not an executive position eligible for an award such as this Award, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(e) by paying the Grantee a cash amount equal to the Fair Market Value of one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(f)Prorated Vesting. The Prorated Number of RSUs described in Section 6(b), (c), (d) or (e) above (the “Prorated Number”) shall be determined as follows:

The Prorated Number = X multiplied by (Y/Z), where

X = the number of RSUs that would have become Vested RSUs based on actual performance against the Performance Goals if the Grantee had remained employed (and in an eligible executive position) until the Vesting Date;

Y = the number of full calendar months the Grantee remained employed (and in an eligible executive position) after the Grant Date; and

Z = 36.

(g)Release Requirement. Notwithstanding any provision herein to the contrary, except as otherwise determined by the Company, in order for the Grantee to receive payment pursuant to the settlement of Vested RSUs under Section 6(a), (b), (c), (d) or (e)

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above, the Grantee (or the representative of his or her estate) must execute and deliver to the Company a general release and waiver of claims against the Company, its Subsidiaries and their directors, officers, employees, shareholders and other affiliates in a form that is satisfactory to the Company (the “Release”). The Release must become effective and irrevocable under applicable law no later than 60 days following the date of the Grantee’s death, termination of employment or transfer of position, as applicable.

7.Change in Control. If a Change in Control occurs, the RSUs shall generally become subject to the terms and conditions of Article 16 of the Plan; provided that if the RSUs subject to this Agreement are not replaced with a Replacement Award, then a prorated number of the RSUs (as determined by the formula in the following sentence) shall become Vested RSUs as of the date of the Change in Control and shall be settled no later than 60 days after the Change in Control in the manner set forth in Article 16 of the Plan. For purposes of this Section 7, the prorated number of RSUs that may become Vested RSUs upon a Change in Control shall be equal to the Target Number of RSUs granted hereunder times a fraction, in which the numerator is the number of full months completed from the Grant Date to the date of the consummation of the Change in Control and the denominator is 36.

8.Dividend Equivalents. Until the date on which the RSUs are settled for cash, and pursuant to the terms and conditions of this Agreement, the Grantee will be credited (in the manner described in the following sentences) on the books and records of the Company with an amount per each RSU equal to the amount per share of any cash dividends declared by the Board of Directors of the Company with a record date on or after the Grant Date on the outstanding Shares of the Company (such amount, a “Dividend Equivalent”). Such Dividend Equivalents will be credited in the form of an additional number of RSUs and the Target Number of RSUs shall be adjusted by each additional RSU credited to the Grantee pursuant to the Dividend Equivalents. The additional number of RSUs will be equal to the aggregate amount of Dividend Equivalents credited under this Agreement on the respective dividend payment date divided by the average of the high and low prices per Share on the respective dividend payment date. The RSUs attributable to the Dividend Equivalents will be either settled or forfeited, as appropriate, under the same terms and conditions that apply to the other RSUs under this Award Agreement, including the achievement of the Performance Goals and any action taken by the Committee. For the avoidance of doubt, if the Grantee defers settlement of any portion of the RSUs pursuant to the Executive Deferred Compensation Plan, then, during the deferral period, the Grantee’s stock account under the Executive Deferred Compensation Plan shall continue to be credited with Dividend Equivalents pursuant to this Section 8 until such deferred RSUs are settled for Shares or cash, as applicable, under the terms of the Executive Deferred Compensation Plan.

9.Continuous Employment. So long as the Grantee continues to be an employee of the Company or any of its Subsidiaries, he or she shall not be considered to have experienced a termination of employment because of: (a) any temporary leave of absence approved in writing by the Company or such Subsidiary; or (b) any change of duties or position (including transfer from one Subsidiary to another); provided, however, that, in the case of any change of duties or position that results in the Grantee no longer being an executive of the Company or a Subsidiary, the terms of Section 6(e) shall apply.

10.Withholding. Upon settlement of the RSUs, the Company shall withhold an amount sufficient to satisfy all federal, state, and local taxes to be withheld in connection with the settlement of RSUs under this Agreement.

11.No Shareholder Rights. The Grantee shall have no shareholder rights (or rights as a beneficial owner), including no voting rights, with respect to any RSU or the Share underlying the RSU at any time.

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12.Recoupment. If the Grantee is or has been deemed to be, or becomes, an “insider” for purposes of Section 16 of the Exchange Act, this Agreement will be administered in compliance with Section 10D of the Exchange Act, any applicable rules or regulations promulgated by the Securities and Exchange Commission or any national securities exchange or national securities association on which the Shares may be traded, and subject to the Company’s Executive Compensation Recoupment Policy, as amended (or succeeded) from time to time, or any other Company policy adopted pursuant to such law, rules, or regulations and this Agreement may be amended to further such purpose without the consent of the Grantee.

13.Termination of Agreement. This Agreement will terminate on the earliest of: (a) the date of the Grantee’s termination of employment with the Company, except if such termination of employment is due to death, Disability, Retirement, or a termination by the Company without Cause; (b) the date the RSUs are settled pursuant to the terms of this Agreement; or (c) if no RSUs have become Vested RSUs as of the Vesting Date, the Vesting Date. Any terms or conditions of this Agreement that the Company determines are reasonably necessary to effectuate its purposes shall survive the termination of this Agreement.

14.Miscellaneous Provisions.

(a)Adjustments. In the event of a corporate event or transaction described in Section 4.5 of the Plan, this Award and the RSUs granted hereunder shall be subject to mandatory adjustment as described in Section 4.5 of the Plan.

(b)Successors and Legal Representatives. This Agreement will bind and inure to the benefit of the Company and the Grantee, and their respective successors, assigns and legal representatives.

(c)Integration. This Agreement, together with the Plan, constitutes the entire agreement between the Grantee and the Company with respect to the subject matter hereof. Any waiver of any term, condition or breach thereof will not be a waiver of any other term or condition or of the same term or condition for the future, or of any subsequent breach. To the extent a conflict exists between the terms of this Agreement and the provisions of the Plan, the provisions of the Plan shall govern, except with respect to the Committee’s authority to adjust downward the number of RSUs that vest under this Agreement, as provided under Section 14(h) below.

(d)Notice. Any notice relating to this grant must be in writing, which may include an electronic writing.

(e)No Employment Right Created. Nothing in this Agreement will be construed to confer upon the Grantee the right to continue in the employment or service of the Company or any of its Subsidiaries, or to be employed or serve in any particular position therewith, or affect any right which the Company or any of its Subsidiaries may have to terminate the Grantee’s employment or service with or without cause.

(f)Severability. In the event of the invalidity of any part or provision of this Agreement, such invalidity will not affect the enforceability of any other part or provision of this Agreement.

(g)Section Headings. The section headings of this Agreement are for convenience of reference only and are not intended to define, extend or limit the contents of the sections.

(h)Amendment. The terms and conditions of this Agreement may be modified by the Committee:

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(i)in any case permitted by the terms of the Plan or this Agreement;

(ii)except with respect to an adjustment made pursuant to the last paragraph of this Section 14(h), with the written consent of the Grantee; or

(iii) without the consent of the Grantee if the amendment is either not materially adverse to the interests of the Grantee or is necessary or appropriate in the view of the Committee to conform with, or to take into account, applicable law, including either exemption from or compliance with any applicable tax law.

Notwithstanding any provision in this Agreement or the Plan to the contrary, the Committee shall retain the discretion to adjust the number of RSUs that vest under this Agreement without the Grantee’s consent, notwithstanding the Company’s actual performance against the Performance Goals, either on a formula or discretionary basis or a combination of the two, as the Committee determines in its sole discretion.

(i)Plan Administration. The Plan is administered by the Committee, which has full and exclusive discretionary power to interpret, implement, construe and adopt rules, forms and guidelines for administering the Plan and this Agreement. All actions, interpretations and determinations made by the Committee, the Board of Directors, or any of their delegates as to the provisions of this Agreement and the Plan shall be final, conclusive, and binding on all persons and the Grantee agrees to be bound by such actions, interpretations and determinations.

(j)Governing Law. Except as may otherwise be provided in the Plan, this Agreement will be governed by, construed and enforced in accordance with the internal laws of the State of Ohio, without giving effect to its principles of conflict of laws. By accepting this Award, the Grantee agrees to the exclusive jurisdiction and venue of the courts of the United States District Court for the Northern District of Ohio or the Summit County (Ohio) Court of Common Pleas to adjudicate any and all claims brought with respect to this Agreement.

(k)Internal Revenue Code Section 409A. Notwithstanding anything in the Plan or this Agreement to the contrary, the Award of RSUs granted hereunder is intended to meet any applicable requirements for compliance under, or exemption from, Code Section 409A and this Agreement shall be construed and administered accordingly. However, notwithstanding anything in this Agreement to the contrary, the Company makes no representations or warranties as to the tax effects of payments made to the Grantee (or the Grantee’s estate) pursuant to this Agreement, and any and all tax consequences incident to such shall solely be the responsibility of the Grantee (or the Grantee’s estate).

(l)Data Privacy.

    In order to implement, administer and manage the Grantee’s participation in the Plan, the Company and its affiliates may hold certain personal information about the Grantee, including, but not limited to, the Grantee’s name, home address and telephone number, date of birth, social security number or other identification number, salary, nationality, job title, any Shares or directorships held in the Company or any affiliate, details of all Awards or any other entitlement to Shares awarded, canceled, exercised, vested, unvested or outstanding in the Grantee’s favor, for the exclusive purpose of implementing, administering and managing the Plan (collectively, the “Personal Data”).

    The Grantee hereby explicitly and unambiguously consents to the collection, use and transfer, in electronic or other form, of the Grantee’s Personal Data as described above, as applicable, to the Company and its affiliates for the sole purpose of administering the Plan. The Grantee understands that Personal Data may be transferred to third parties assisting in the

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implementation, administration and management of the Plan, that these recipients may be located in the United States or elsewhere, and that the recipient’s country may have different data privacy laws and protections than the United States or the Grantee’s state of residence. The Grantee understands that he or she may request a list with the names and addresses of any potential recipients of the Personal Data by contacting the Executive Compensation group of Human Resources. The Grantee authorizes the recipients to receive, possess, use, retain and transfer the Personal Data, in electronic or other form, for the purposes of implementing, administering and managing the Grantee’s participation in the Plan, including any requisite transfer of such Personal Data as may be required to a broker or other third party with whom the Grantee may elect to deposit any Shares received upon vesting of the RSUs. The Grantee understands that Personal Data will be held only as long as is necessary to implement, administer and manage the Grantee’s participation in the Plan and to comply with Securities and Exchange Commission and/or NYSE reporting obligations, any other applicable law or regulation and any applicable document retention policies of the Company. The Grantee understands that he or she may, at any time, view Personal Data, request additional information about the storage and processing of Personal Data, require any necessary amendments to Personal Data or refuse or withdraw the consents herein, without cost, by contacting in writing the Executive Compensation group of Human Resources. The Grantee understands that refusal or withdrawal of consent may affect the Grantee’s ability to participate in the Plan or to realize benefits from the RSUs. For more information on the consequences of the Grantee’s refusal to consent or withdrawal of consent, the Grantee understands that he or she may contact the Executive Compensation group of Human Resources.

(m)Signatures and Electronic Delivery. This Agreement may be executed electronically and in counterparts, each of which shall be deemed to be an original, and when taken together shall constitute one binding agreement. The Company may, in its sole discretion, deliver any documents related to current or future participation in the Plan by electronic means. The Grantee hereby consents to receive such documents by electronic delivery and agrees to participate in the Plan through an on-line or electronic system established and maintained by the Company or another third party designated by the Company.

[SIGNATURE ON FOLLOWING PAGE]

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The Grantee acknowledges receipt of this Agreement and accepts and agrees with the terms and conditions stated above.

[Acceptance Date]                    ____[Electronic Signature]______

(Date)(Signature of the Grantee)

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EXHIBIT A

Performance Goals

Performance Period

The Performance Period for this Agreement is January 1, 2022 through December 31, 2024.

Performance Goals1

The Performance Goals, as approved by the Committee, for the Performance Period are based on:

1 Notwithstanding any other provision of this Agreement, in addition to any other rights of the Committee under the Plan (as defined in the Agreement), the Committee may, in any evaluation of the Company’s level of achievement with respect to the Performance Goals, include or exclude any of the following events that occur during the Performance Period: (a) asset write-downs; (b) litigation or claim judgments or settlements; (c) the effect of changes in tax laws, accounting principles or other laws or provisions affecting reported results; (d) any reorganization and restructuring programs; (e) extraordinary nonrecurring items; (f) acquisitions or divestitures and/or (g) foreign exchange gains and losses.

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EX-10.2

Exhibit 10.2

(Stock-Based Agreement)

FIRSTENERGY CORP.

2020 Incentive Compensation Plan

2022-2024 Performance-Adjusted Restricted Stock Unit Award Agreement

THIS 2022-2024 PERFORMANCE-ADJUSTED RESTRICTED STOCK UNIT AWARD AGREEMENT (the “Agreement”), effective as of [GRANT DATE], 2022 (the “Grant Date”), is entered into by and between the Company and [PARTICIPANT NAME] (the “Grantee”).

1.Definitions. Unless otherwise specified in this Agreement, capitalized terms shall have the meanings attributed to them under the Plan. For purposes of this Agreement, the following terms shall be defined as follows:

    (a)    “Retirement” shall mean the Grantee’s Separation from Service (except due to death) on or after attaining age fifty-five (55) and after providing at least ten (10) years of service to the Company or any Subsidiary or affiliate and any predecessor thereof; and

    (b)    “Separation from Service” shall mean, with respect to the Grantee, the “separation from service” within the meaning of Code Section 409A of the Grantee with the Company and any Subsidiaries, for any reason, including without limitation quit, discharge, leave of absence (including military leave, sick leave, or other bona fide leave of absence such as temporary employment by the government if the period of such leave exceeds the greater of six months or the period for which the Grantee’s right to reemployment is provided either by statute or by contract) or permanent decrease in service to a level that is no more than twenty percent (20%) of its prior level. For this purpose, whether a “Separation from Service” has occurred is determined based on whether it is reasonably anticipated that no further services will be performed by the Grantee after a certain date or that the level of bona fide services the Grantee will perform after such date (whether as an employee or as an independent contractor) would permanently decrease to no more than twenty percent (20%) of the average level of bona fide services performed (whether as an employee or an independent contractor) over the immediately preceding 36-month period (or the full period of services if the Grantee has been providing services for less than 36 months).

2.Grant of Restricted Stock Units. As of the Grant Date, the Company has granted to the Grantee [NUMBER OF UNITS GRANTED] (the “Target Number”) Restricted Stock Units (the “Restricted Stock Units” or “RSUs”), a percentage of which Target Number will vest and become payable in accordance with the terms and conditions of this Agreement. The Target Number shall be adjusted with respect to Dividend Equivalents as provided in Section 8 below. Each RSU that becomes vested and payable hereunder represents the right of the Grantee to receive one Share subject to the terms and conditions of this Agreement. The RSUs are granted in accordance with, and subject to, all the terms, conditions and restrictions of the Plan, which is hereby incorporated by reference in its entirety. The Grantee irrevocably agrees to, and accepts, the terms, conditions and restrictions of the Plan and this Agreement on the Grantee’s own behalf and on behalf of any heirs, successors and assigns.

3.Restrictions on RSUs. Except as otherwise provided herein, the Grantee cannot sell, transfer, assign, hypothecate or otherwise dispose of the RSUs or pledge any RSU as collateral for a loan, other than by will or by the laws of descent and distribution. In no event may any RSU or this Award be transferred for value. In addition, the RSUs, and any payments made with respect to the RSUs, will be subject to such other restrictions as the Committee deems necessary or appropriate, including, without limitation, the Company’s Executive Compensation Recoupment Policy, as may be amended (or succeeded) from time to time, to the extent applicable.

4.Vesting and Settlement of RSUs.

(a)Vesting. Except as otherwise provided in Sections 6 and 7 below, if and to the extent the performance goals set forth on Exhibit A attached to this Agreement (the “Performance Goals”) are achieved during the performance period set forth on Exhibit A (the “Performance Period”), a percentage of the Target Number of RSUs will vest on March 1, 2025 (the “Vesting Date”), as long as the Grantee remains continuously employed by the Company or a Subsidiary until such Vesting Date. The number of RSUs that shall vest will range from 0% to 200% of the Target Number, as determined by the extent to which the Performance Goals are achieved. The Grantee will have no rights to the Shares underlying the RSUs until the RSUs have vested and been settled (each RSU that vests pursuant to this Section 4 or Sections 6 and 7 below, a “Vested RSU”). Prior to settlement, each RSU (whether or not a Vested RSU) represents an unfunded and unsecured obligation of the Company.

(b)Settlement. Except as otherwise provided in Sections 6, 7 and 11 below, the Company shall settle each Vested RSU by delivering one Share per Vested RSU to the Grantee as soon as administratively practicable (and no later than 60 days) after the Vesting Date. Notwithstanding the foregoing or any provision in Sections 6 or 7 to the contrary, if the Grantee elects to defer the settlement of the RSUs pursuant to the Company’s Executive Deferred Compensation Plan (or any other non-qualified deferred compensation plan providing for the ability to defer settlement of the RSUs), then the time, form and medium of payment with respect to any deferred RSUs shall be made pursuant to the terms and conditions of the Executive Deferred Compensation Plan (or similar non-qualified deferred compensation plan). Fractional RSUs, if any, will be settled in cash.

5.Forfeiture. Except as otherwise provided in Sections 6 and 7, the Grantee will forfeit his or her interest in the RSUs to the extent the Performance Goals are not achieved during the Performance Period or if the Grantee terminates his or her employment with the Company and its Subsidiaries prior to the Vesting Date.

6.Certain Events. Notwithstanding any provision in this Agreement to the contrary and in each case subject to Section 6(g) below:

(a)Death. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee dies, a prorated number of RSUs shall become Vested RSUs. For purposes of this Section 6(a), the number of RSUs that shall become Vested RSUs due to the Grantee’s death shall be equal to (i) the Target Number of RSUs multiplied by (ii) a fraction, where the numerator is the number of full calendar months the Grantee remained employed after the Grant Date and the denominator is 36. The Company shall settle any RSUs that become Vested RSUs under this Section 6(a) by delivering to the Grantee’s estate one Share for each Vested RSU as soon as administratively practicable after the date of the Grantee’s death, but in any event, by March 15th of the year following the year in which the Grantee’s death occurred.

(b)Disability. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee’s employment is terminated due to the Grantee’s Disability, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(b) by delivering to the Grantee one Share for each Vested RSU as soon as administratively practicable after the Vesting Date,

    2

but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(c)Termination without Cause. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee’s employment is terminated by the Company and its Subsidiaries without Cause, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(c) by delivering to the Grantee one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(d)Retirement. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee’s employment is terminated due to the Grantee’s Retirement, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(d) by delivering to the Grantee one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(e)Change in Position. If, at least one month after the Grant Date but prior to the Vesting Date, the Grantee is transferred to a position with the Company or a Subsidiary that is not an executive position eligible for an awards such as this Award, then, after the end of the Performance Period, a Prorated Number of RSUs shall become Vested RSUs (as determined in Section 6(f) below). The Company shall settle any RSUs that become Vested RSUs under this Section 6(e) by delivering to the Grantee one Share for each Vested RSU as soon as administratively practicable after the Vesting Date, but in any event within the short-term deferral period specified in Treasury Regulation § 1.409A-1(b)(4).

(f)Prorated Vesting. The Prorated Number of RSUs described in Section 6(b), (c), (d) or (e) above (the “Prorated Number”) shall be determined as follows:

The Prorated Number = X multiplied by (Y/Z), where

X = the number of RSUs that would have become Vested RSUs based on actual performance against the Performance Goals if the Grantee had remained employed (and in an eligible executive position) until the Vesting Date;

Y = the number of full calendar months the Grantee remained employed (and in an eligible executive position) after the Grant Date; and

Z = 36.

(g)Release Requirement. Notwithstanding any provision herein to the contrary, except as otherwise determined by the Company, in order for the Grantee to receive Shares pursuant to the settlement of Vested RSUs under Section 6(a), (b), (c), (d) or (e) above, the Grantee (or the representative of his or her estate) must execute and deliver to the Company a general release and waiver of claims against the Company, its Subsidiaries and their directors, officers, employees, shareholders and other affiliates in a form that is satisfactory to the Company (the “Release”). The Release must become effective and irrevocable under applicable law no later than 60 days

    3

following the date of the Grantee’s death, termination of employment or transfer of position, as applicable.

7.Change in Control. If a Change in Control occurs, the RSUs shall generally become subject to the terms and conditions of Article 16 of the Plan; provided that if the RSUs subject to this Agreement are not replaced with a Replacement Award, then a prorated number of the RSUs (as determined by the formula in the following sentence) shall become Vested RSUs as of the date of the Change in Control and shall be settled no later than 60 days after the Change in Control in the manner set forth in Article 16 of the Plan. For purposes of this Section 7, the prorated number of RSUs that may become Vested RSUs upon a Change in Control shall be equal to the Target Number of RSUs granted hereunder times a fraction, in which the numerator is the number of full months completed from the Grant Date to the date of the consummation of the Change in Control and the denominator is 36.

8.Dividend Equivalents. Until the date on which the RSUs are settled for Shares (or cash in the case of RSUs deferred under the Company’s Executive Deferred Compensation Plan), and pursuant to the terms and conditions of this Agreement, the Grantee will be credited (in the manner described in the following sentences) on the books and records of the Company with an amount per each RSU equal to the amount per share of any cash dividends declared by the Board of Directors of the Company with a record date on or after the Grant Date on the outstanding Shares (such amount, a “Dividend Equivalent”). Such Dividend Equivalents will be credited in the form of an additional number of RSUs and the Target Number of RSUs shall be adjusted by each additional RSU credited to the Grantee pursuant to the Dividend Equivalents. The additional number of RSUs will be equal to the aggregate amount of Dividend Equivalents credited under this Agreement on the respective dividend payment date divided by the average of the high and low prices per Share on the respective dividend payment date. The RSUs attributable to the Dividend Equivalents will be either settled or forfeited, as appropriate, under the same terms and conditions that apply to the other RSUs under this Award Agreement, including the achievement of the Performance Goals and any action taken by the Committee. For the avoidance of doubt, if the Grantee defers settlement of any portion of the RSUs pursuant to the Executive Deferred Compensation Plan, then, during the deferral period, the Grantee’s stock account under the Executive Deferred Compensation Plan shall continue to be credited with Dividend Equivalents pursuant to this Section 8 until such deferred RSUs are settled for Shares or cash, as applicable, under the terms of the Executive Deferred Compensation Plan.

9.Continuous Employment. So long as the Grantee continues to be an employee of the Company or any of its Subsidiaries, he or she shall not be considered to have experienced a termination of employment because of: (a) any temporary leave of absence approved in writing by the Company or such Subsidiary; or (b) any change of duties or position (including transfer from one Subsidiary to another); provided, however, that, in the case of any change of duties or position that results in the Grantee no longer being an executive of the Company or a Subsidiary, the terms of Section 6(e) shall apply.

10.Delivery of Shares. Upon settlement of any RSUs under this Agreement, the Company will deliver to the Grantee (or his or her estate) the Shares to which the Grantee is entitled free and clear of any restrictions (except any restrictions under applicable securities laws or otherwise imposed under the Plan or Section 3 hereof).

11.Withholding. Upon settlement of the RSUs, the Company shall withhold a number of Shares (or amount of cash, if applicable) in an amount sufficient to satisfy all federal, state, and local taxes to be withheld in connection with the settlement of RSUs under this Agreement.

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12.No Shareholder Rights. The Grantee shall have no shareholder rights (or rights as a beneficial owner), including no voting rights, with respect to any RSU or the Share underlying the RSU unless and until the Grantee receives the Share upon settlement of the RSU.

13.Recoupment. If the Grantee is or has been deemed to be, or becomes, an “insider” for purposes of Section 16 of the Exchange Act, this Agreement will be administered in compliance with Section 10D of the Exchange Act, any applicable rules or regulations promulgated by the Securities and Exchange Commission or any national securities exchange or national securities association on which the Shares may be traded, and subject to the Company’s Executive Compensation Recoupment Policy, as amended (or succeeded) from time to time, or any other Company policy adopted pursuant to such law, rules, or regulations and this Agreement may be amended to further such purpose without the consent of the Grantee.

14.Termination of Agreement. This Agreement will terminate on the earliest of: (a) the date of the Grantee’s termination of employment with the Company, except if such termination of employment is due to death, Disability, Retirement, or a termination by the Company without Cause; (b) the date the RSUs are settled pursuant to the terms of this Agreement; or (c) if no RSUs have become Vested RSUs as of the Vesting Date, the Vesting Date. Any terms or conditions of this Agreement that the Company determines are reasonably necessary to effectuate its purposes shall survive the termination of this Agreement.

15.Miscellaneous Provisions.

(a)Adjustments. In the event of a corporate event or transaction described in Section 4.5 of the Plan, this Award and the RSUs granted hereunder shall be subject to mandatory adjustment as described in Section 4.5 of the Plan.

(b)Successors and Legal Representatives. This Agreement will bind and inure to the benefit of the Company and the Grantee, and their respective successors, assigns and legal representatives.

(c)Integration. This Agreement, together with the Plan, constitutes the entire agreement between the Grantee and the Company with respect to the subject matter hereof. Any waiver of any term, condition or breach thereof will not be a waiver of any other term or condition or of the same term or condition for the future, or of any subsequent breach. To the extent a conflict exists between the terms of this Agreement and the provisions of the Plan, the provisions of the Plan shall govern, except with respect to the Committee’s authority to adjust downward the number of RSUs that vest under this Agreement, as provided under Section 15(h) below.

(d)Notice. Any notice relating to this grant must be in writing, which may include an electronic writing.

(e)No Employment Right Created. Nothing in this Agreement will be construed to confer upon the Grantee the right to continue in the employment or service of the Company or any of its Subsidiaries, or to be employed or serve in any particular position therewith or affect any right which the Company or any of its Subsidiaries may have to terminate the Grantee’s employment or service with or without cause.

(f)Severability. In the event of the invalidity of any part or provision of this Agreement, such invalidity will not affect the enforceability of any other part or provision of this Agreement.

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(g)Section Headings. The section headings of this Agreement are for convenience of reference only and are not intended to define, extend or limit the contents of the sections.

(h)Amendment. The terms and conditions of this Agreement may be modified by the Committee:

(i)in any case permitted by the terms of the Plan or this Agreement;

(ii)except with respect to an adjustment made pursuant to the last paragraph of this Section 15(h), with the written consent of the Grantee; or

(iii) without the consent of the Grantee if the amendment is either not materially adverse to the interests of the Grantee or is necessary or appropriate in the view of the Committee to conform with, or to take into account, applicable law, including either exemption from or compliance with any applicable tax law.

Notwithstanding any provision in this Agreement or the Plan to the contrary, the Committee shall retain the discretion to adjust the number of RSUs that vest under this Agreement without the Grantee’s consent, notwithstanding the Company’s actual performance against the Performance Goals, either on a formula or discretionary basis or a combination of the two, as the Committee determines in its sole discretion.

(i)Plan Administration. The Plan is administered by the Committee, which has full and exclusive discretionary power to interpret, implement, construe and adopt rules, forms and guidelines for administering the Plan and this Agreement. All actions, interpretations and determinations made by the Committee, the Board of Directors, or any of their delegates as to the provisions of this Agreement and the Plan shall be final, conclusive, and binding on all persons and the Grantee agrees to be bound by such actions, interpretations and determinations.

(j)Governing Law. Except as may otherwise be provided in the Plan, this Agreement will be governed by, construed and enforced in accordance with the internal laws of the State of Ohio, without giving effect to its principles of conflict of laws. By accepting this Award, the Grantee agrees to the exclusive jurisdiction and venue of the courts of the United States District Court for the Northern District of Ohio or the Summit County (Ohio) Court of Common Pleas to adjudicate any and all claims brought with respect to this Agreement.

(k)Internal Revenue Code Section 409A. Notwithstanding anything in the Plan or this Agreement to the contrary, the Award of RSUs granted hereunder is intended to meet any applicable requirements for compliance under, or exemption from, Code Section 409A and this Agreement shall be construed and administered accordingly. However, notwithstanding anything in this Agreement to the contrary, the Company makes no representations or warranties as to the tax effects of payments made to the Grantee (or the Grantee’s estate) pursuant to this Agreement, and any and all tax consequences incident to such shall solely be the responsibility of the Grantee (or the Grantee’s estate).

(l)Data Privacy. In order to implement, administer and manage the Grantee’s participation in the Plan, the Company and its affiliates may hold certain personal information about the Grantee, including, but not limited to, the Grantee’s name, home address and telephone number, date of birth, social security number or other identification number, salary, nationality, job title, any Shares or directorships held in the Company or any affiliate, details of all Awards or any other entitlement to Shares awarded, canceled, exercised, vested, unvested or outstanding in the Grantee’s favor, for the exclusive purpose of implementing, administering and managing the Plan (collectively, the “Personal Data”).

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    The Grantee hereby explicitly and unambiguously consents to the collection, use and transfer, in electronic or other form, of the Grantee’s Personal Data as described above, as applicable, to the Company and its affiliates for the sole purpose of administering the Plan. The Grantee understands that Personal Data may be transferred to third parties assisting in the implementation, administration and management of the Plan, that these recipients may be located in the United States or elsewhere, and that the recipient’s country may have different data privacy laws and protections than the United States or the Grantee’s state of residence. The Grantee understands that he or she may request a list with the names and addresses of any potential recipients of the Personal Data by contacting the Executive Compensation group of Human Resources. The Grantee authorizes the recipients to receive, possess, use, retain and transfer the Personal Data, in electronic or other form, for the purposes of implementing, administering and managing the Grantee’s participation in the Plan, including any requisite transfer of such Personal Data as may be required to a broker or other third party with whom the Grantee may elect to deposit any Shares received upon vesting of the RSUs. The Grantee understands that Personal Data will be held only as long as is necessary to implement, administer and manage the Grantee’s participation in the Plan and to comply with Securities and Exchange Commission and/or NYSE reporting obligations, any other applicable law or regulation and any applicable document retention policies of the Company. The Grantee understands that he or she may, at any time, view Personal Data, request additional information about the storage and processing of Personal Data, require any necessary amendments to Personal Data or refuse or withdraw the consents herein, without cost, by contacting in writing the Executive Compensation group of Human Resources. The Grantee understands that refusal or withdrawal of consent may affect the Grantee’s ability to participate in the Plan or to realize benefits from the RSUs. For more information on the consequences of the Grantee’s refusal to consent or withdrawal of consent, the Grantee understands that he or she may contact the Executive Compensation group of Human Resources.

(m)Signatures and Electronic Delivery. This Agreement may be executed electronically and in counterparts, each of which shall be deemed to be an original, and when taken together shall constitute one binding agreement. The Company may, in its sole discretion, deliver any documents related to current or future participation in the Plan by electronic means. The Grantee hereby consents to receive such documents by electronic delivery and agrees to participate in the Plan through an on-line or electronic system established and maintained by the Company or another third party designated by the Company.

[SIGNATURE ON FOLLOWING PAGE]

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The Grantee acknowledges receipt of this Agreement and accepts and agrees with the terms and conditions stated above.

[Acceptance Date]                    ____[Electronic Signature]______

(Date)(Signature of the Grantee)

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EXHIBIT A

Performance Goals

Performance Period

The Performance Period for this Agreement is January 1, 2022 through December 31, 2024.

Performance Goals1

The Performance Goals, as approved by the Committee, for the Performance Period are based on:

1 Notwithstanding any other provision of this Agreement, in addition to any other rights of the Committee under the Plan (as defined in the Agreement), the Committee may, in any evaluation of the Company’s level of achievement with respect to the Performance Goals, include or exclude any of the following events that occur during the Performance Period: (a) asset write-downs; (b) litigation or claim judgments or settlements; (c) the effect of changes in tax laws, accounting principles or other laws or provisions affecting reported results; (d) any reorganization and restructuring programs; (e) extraordinary nonrecurring items; (f) acquisitions or divestitures and/or (g) foreign exchange gains and losses.

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EX-31.1

EXHIBIT 31.1

Certification

I, Steven E. Strah, certify that:

1.I have reviewed this report on Form 10-Q of FirstEnergy Corp.;

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.

Date: April 21, 2022

/s/ Steven E. Strah

Steven E. Strah

President and
Chief Executive Officer

EX-31.2

EXHIBIT 31.2

Certification

I, K. Jon Taylor, certify that:

1.I have reviewed this report on Form 10-Q of FirstEnergy Corp.;

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.

Date: April 21, 2022

/s/ K. Jon Taylor

K. Jon Taylor

Senior Vice President, Chief Financial Officer and Strategy

EX-32

EXHIBIT 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

In connection with the Report of FirstEnergy Corp. (“Company”) on Form 10-Q for the period ended March 31, 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), each undersigned officer of the Company does hereby certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to the best of his knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Steven E. Strah

Steven E. Strah

President and
Chief Executive Officer

/s/ K. Jon Taylor

K. Jon Taylor

Senior Vice President, Chief Financial Officer and Strategy

Date: April 21, 2022

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Cover Page	3 Months Ended
	Mar. 31, 2022 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
Entity File Number	333-21011
Entity Registrant Name	FIRSTENERGY CORP.
Entity Incorporation, State or Country Code	OH
Entity Address, Address Line One	76 South Main Street
Entity Address, City or Town	Akron
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	44308
City Area Code	(800)
Local Phone Number	736-3402
Entity Tax Identification Number	34-1843785
Title of 12(b) Security	Common Stock, $0.10 par value
Trading Symbol	FE
Security Exchange Name	NYSE
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	570,932,260
Amendment Flag	false
Entity Central Index Key	0001031296
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31

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Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
REVENUES:
Revenues	[1]	$ 2,989	$ 2,726
OPERATING EXPENSES:
Fuel		140	118
Purchased power		875	718
Other operating expenses		820	752
Provision for depreciation		340	323
Amortization (deferral) of regulatory assets, net		(37)	92
General taxes		292	273
Gain on sale of Yards Creek (Note 9)		0	(109)
Total operating expenses		2,430	2,167
OPERATING INCOME		559	559
OTHER INCOME (EXPENSE):
Miscellaneous income, net		106	135
Interest expense		(313)	(285)
Capitalized financing costs		19	13
Total other expense		(188)	(137)
INCOME BEFORE INCOME TAXES		371	422
INCOME TAXES		83	87
NET INCOME		$ 288	$ 335
EARNINGS PER SHARE OF COMMON STOCK (Note 3):
Basic - Earnings Per Share of Common Stock (in dollars per share)		$ 0.51	$ 0.62
Diluted - Earnings Per Share to Common Stock (in dollars per share)		$ 0.50	$ 0.62
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic, in shares		570	543
Diluted, in shares		571	544
Distribution Services and Retail Generation
REVENUES:
Revenues		$ 2,397	$ 2,236
Transmission
REVENUES:
Revenues		451	401
Other
REVENUES:
Revenues		$ 141	$ 89

[1] Includes excise and gross receipts tax collections of $103 million and $95 million during the three months ended March 31, 2022 and 2021, respectively.

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Consolidated Statements of Income (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Income Statement [Abstract]
Excise taxes collected	$ 103	$ 95

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Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
NET INCOME	$ 288	$ 335
OTHER COMPREHENSIVE LOSS:
Pension and OPEB prior service costs	(2)	(3)
Other comprehensive loss	(2)	(3)
Income tax benefits on other comprehensive loss	(1)	(1)
Other comprehensive loss, net of tax	(1)	(2)
COMPREHENSIVE INCOME	$ 287	$ 333

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Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
CURRENT ASSETS:
Cash and cash equivalents	$ 283	$ 1,462
Restricted cash	27	49
Receivables-
Other, net of allowance for uncollectible accounts of $10 in 2022 and 2021	246	246
Materials and supplies, at average cost	273	260
Prepaid taxes and other	295	187
Total current assets	2,250	3,237
PROPERTY, PLANT AND EQUIPMENT:
In service	46,349	46,002
Less — Accumulated provision for depreciation	12,834	12,672
Property, plant and equipment in service net of accumulated provision for depreciation	33,515	33,330
Construction work in progress	1,481	1,414
Total net property, plant and equipment	34,996	34,744
INVESTMENTS AND OTHER NONCURRENT ASSETS:
Goodwill	5,618	5,618
Investments (Note 6)	646	655
Regulatory assets	70	71
Other	1,037	1,107
Total deferred charges and other assets	7,371	7,451
Total assets	44,617	45,432
CURRENT LIABILITIES:
Currently payable long-term debt	1,055	1,606
Short-term borrowings	350	0
Accounts payable	1,090	943
Accrued interest	289	283
Accrued taxes	650	647
Accrued compensation and benefits	276	313
Dividends Payable	223	222
Other	427	402
Total current liabilities	4,360	4,416
Stockholders’ equity-
Common stock	57	57
Other paid-in capital	10,031	10,238
Accumulated other comprehensive loss	(16)	(15)
Accumulated deficit	(1,317)	(1,605)
Total stockholders’ equity	8,755	8,675
Long-term debt and other long-term obligations	21,754	22,248
Total capitalization	30,509	30,923
NONCURRENT LIABILITIES:
Accumulated deferred income taxes	3,544	3,437
Retirement benefits	2,620	2,669
Regulatory liabilities	2,025	2,124
Other	1,559	1,863
Total noncurrent liabilities	9,748	10,093
COMMITMENTS, GUARANTEES AND CONTINGENCIES (Note 8)
Total liabilities and capitalization	44,617	45,432
Customer
Receivables-
Customers	1,258	1,192
Less — Allowance for uncollectible customer receivables	132	159
Customers	$ 1,126	$ 1,033

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Stockholders’ equity-
Common stock, par value (in dollars per share)	$ 0.10	$ 0.10
Common stock, shares authorized (in shares)	700,000,000	700,000,000
Common stock, shares outstanding (in shares)	570,932,260	570,261,104
Other
Receivables-
Allowance for uncollectible accounts	$ 10	$ 10

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Consolidated Statements of Stockholders' Equity - USD ($) $ in Millions	Total	Common Stock	OPIC	AOCI	Accumulated Deficit
Beginning balance, (in shares) at Dec. 31, 2020		543,000,000
Beginning balance at Dec. 31, 2020	$ 7,237	$ 54	$ 10,076	$ (5)	$ (2,888)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	335				335
Other comprehensive loss, net of tax	(2)			(2)
Stock Investment Plan and share-based benefit plans (in shares)		1,000,000
Share-based benefit plans	2		2
Cash dividends declared on common stock	(212)		(212)
Ending balance (in shares) at Mar. 31, 2021		544,000,000
Ending balance at Mar. 31, 2021	$ 7,360	$ 54	9,866	(7)	(2,553)
Beginning balance, (in shares) at Dec. 31, 2021	570,261,104	570,000,000
Beginning balance at Dec. 31, 2021	$ 8,675	$ 57	10,238	(15)	(1,605)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	288				288
Other comprehensive loss, net of tax	(1)			(1)
Stock Investment Plan and share-based benefit plans (in shares)		1,000,000
Share-based benefit plans	20		20
Cash dividends declared on common stock	(223)		(223)
Other	$ (4)		(4)
Ending balance (in shares) at Mar. 31, 2022	570,932,260	571,000,000
Ending balance at Mar. 31, 2022	$ 8,755	$ 57	$ 10,031	$ (16)	$ (1,317)

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Consolidated Statements of Stockholders' Equity (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Stockholders' Equity [Abstract]
Dividends declared (in dollars per share)	$ 0.39	$ 0.39

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 288	$ 335
Adjustments to reconcile net income to net cash from operating activities-
Depreciation and amortization	359	454
Deferred income taxes and investment tax credits, net	77	82
Retirement benefits, net of payments	(96)	(105)
Gain on sale of Yards Creek (Note 9)	0	(109)
Changes in current assets and liabilities-
Receivables	(93)	161
Materials and supplies	(13)	14
Prepaid taxes and other current assets	(105)	(121)
Accounts payable	147	43
Accrued taxes	(133)	(127)
Accrued interest	6	7
Accrued compensation and benefits	(106)	(129)
Other current liabilities	10	(7)
Other	14	35
Net cash provided from operating activities	355	533
New financing-
Long-term debt	0	500
Short-term borrowings, net	350	0
Redemptions and repayments-
Long-term debt	(1,046)	(29)
Short-term borrowings, net	0	(750)
Make-whole premiums paid on debt redemptions	(38)	0
Common stock dividend payments	(222)	(212)
Other	(8)	(18)
Net cash used for financing activities	(964)	(509)
CASH FLOWS FROM INVESTING ACTIVITIES:
Property additions	(520)	(604)
Proceeds from sale of Yards Creek	0	155
Sales of investment securities held in trusts	6	5
Purchases of investment securities held in trusts	(9)	(7)
Asset removal costs	(49)	(47)
Other	(20)	(1)
Net cash used for investing activities	(592)	(499)
Net change in cash, cash equivalents, and restricted cash	(1,201)	(475)
Cash, cash equivalents, and restricted cash at beginning of period	1,511	1,801
Cash, cash equivalents, and restricted cash at end of period	$ 310	$ 1,326

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Organization and Basis of Presentation

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

ORGANIZATION AND BASIS OF PRESENTATION

ORGANIZATION AND BASIS OF PRESENTATION

Unless otherwise indicated, defined terms and abbreviations used herein have the meanings set forth in the accompanying Glossary of Terms.

FE was incorporated under Ohio law in 1996. FE’s principal business is the holding, directly or indirectly, of all of the outstanding equity of its principal subsidiaries: OE, CEI, TE, Penn (a wholly owned subsidiary of OE), JCP&L, ME, PN, FESC, MP, AGC (a wholly owned subsidiary of MP), PE, WP, and FET and its principal subsidiaries (ATSI, MAIT and TrAIL). In addition, FE holds all of the outstanding equity of other direct subsidiaries including: AE Supply, FirstEnergy Properties, Inc., FEV, FirstEnergy License Holding Company, GPUN, Allegheny Ventures, Inc., and Suvon, LLC, doing business as both FirstEnergy Home and FirstEnergy Advisors.

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity. FirstEnergy’s ten utility operating companies comprise one of the nation’s largest investor-owned electric systems, based on serving over six million customers in the Midwest and Mid-Atlantic regions. FirstEnergy’s transmission operations include approximately 24,000 miles of lines and two regional transmission operation centers. AGC and MP control 3,580 MWs of total capacity.

PN, as lessee of the property of its subsidiary, the Waverly Electric Light & Power Company, serves approximately 4,000 customers in the Waverly, New York vicinity. On February 10, 2021, PN entered into an agreement to transfer its customers and the related assets in Waverly, New York to Tri-County Rural Electric Cooperative; the completion of such transfer is subject to several closing conditions including regulatory approval, which are ongoing.

These interim financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and disclosures normally included in financial statements and notes prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. These interim financial statements should be read in conjunction with the financial statements and notes included in the Annual Report on Form 10-K for the year ended December 31, 2021.

FE and its subsidiaries follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The accompanying interim financial statements are unaudited, but reflect all adjustments, consisting of normal recurring adjustments, that, in the opinion of management, are necessary for a fair statement of the financial statements. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of operations for any future period. FE and its subsidiaries have evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued.

FE and its subsidiaries consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. FE and its subsidiaries consolidate a VIE when it is determined that it is the primary beneficiary. Investments in affiliates over which FE and its subsidiaries have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported as an investment in the Consolidated Balance Sheets and the percentage of FE’s ownership share of the entity’s earnings is reported in the Consolidated Statements of Income and Comprehensive Income.

Certain prior year amounts have been reclassified to conform to the current year presentation.

Capitalized Financing Costs

For the three months ended March 31, 2022 and 2021, capitalized financing costs on FirstEnergy’s Consolidated Statements of Income include $13 million and $7 million, respectively, of allowance for equity funds used during construction and $6 million of capitalized interest in both periods.

COVID-19

FirstEnergy is continuously evaluating the COVID-19 global pandemic and taking steps to mitigate known risks. FirstEnergy provides a critical and essential service to its customers and the health and safety of its employees and customers is its first priority. FirstEnergy continues to provide flexibility for approximately 7,000 of its 12,400 employees to work from home. Pandemic safety and cleaning protocols were implemented for those workers who have continued to report to a FirstEnergy work location during the pandemic, ensuring FirstEnergy employees can report directly to job sites and work with the same small group of employees every day. FirstEnergy continues to assess its work from home policies to allow for a flexible workplace to continue for its employees after the pandemic.

FirstEnergy continues to effectively manage operations during the pandemic in order to provide critical service to customers. FirstEnergy has experienced supply chain challenges during the COVID-19 pandemic. Lead times have increased across numerous material categories, with some as much as doubling from previous times. Some key suppliers have struggled with labor shortages and raw material availability, which along with increasing inflationary pressure, have increased the costs of certain materials, equipment and contractors. FirstEnergy has taken steps to mitigate these risks and does not currently expect service disruptions or any material impact on its capital spending plan. However, the situation remains fluid and future impacts to FirstEnergy that are presently unknown or unanticipated may occur.

Customer Receivables

Receivables from customers include distribution services and retail generation sales to residential, commercial and industrial customers of the Utilities. The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for credit losses.

FirstEnergy reviews its allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Utilities are able to utilize to ensure payment. This analysis includes consideration of the outbreak of COVID-19 and the impact on customer receivable balances outstanding and write-offs since the pandemic began. During the first quarter of 2022, various regulatory actions including extensions on moratoriums, certain restrictions on disconnections, and extended installment plan offerings continue to impact the level of past due balances in certain states. However, certain states have resumed normal collections activity and arrears levels have declined towards pre-pandemic levels. As a result of this analysis, FirstEnergy recognized a $25 million decrease to its allowance for uncollectible customer receivables during the first quarter of 2022, of which $15 million was applied to existing deferred regulatory assets. Additionally, as a result of these pandemic-related moratoriums and certain customer installment or extended payment plans offered, the allowance for uncollectible accounts on receivables in 2022 continue to be elevated due to the extension of when certain write-offs would have otherwise occurred.

Receivables from customers also include PJM receivables resulting from transmission and wholesale sales. FirstEnergy’s uncollectible risk on PJM receivables is minimal due to the nature of PJM’s settlement process whereby members of PJM legally agree to share the cost of defaults and as a result there is no allowance for doubtful accounts.

Activity in the allowance for uncollectible accounts on customer receivables for the three months ended March 31, 2022 and for the year ended December 31, 2021 are as follows:

	(In millions)
Balance, January 1, 2021	$	164
Charged to income (1)	54
Charged to other accounts (2)	42
Write-offs	(101)
Balance, December 31, 2021	$	159
Charged to income(3)	(5)
Charged to other accounts (2)	39
Write-offs	(61)
Balance, March 31, 2022	$	132

(1) $12 million of which was deferred for future recovery in the twelve months ended December 31, 2021.

(2) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.

(3) $(11) million of which was deferred for future refund to customers in the three months ended March 31, 2022.

Sale of Minority Interest in FirstEnergy Transmission, LLC

On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA, with Brookfield and Brookfield Guarantors, pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. KATCo, which is currently a subsidiary of FET, will become a wholly owned subsidiary of FE prior to the closing of the transaction and will remain in the Regulated Transmission segment. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. On January 5, 2022, the parties to this transaction submitted an application to FERC requesting approval of the transaction no later than April 30, 2022. On April 14, 2022, CFIUS notified FET and Brookfield that it has determined that there were no unresolved national security issues and its review of the transaction was concluded. On April 21, 2022, FERC approved the matter. The transaction is now expected to close at the end of May 2022.

Pursuant to the terms of the FET P&SA, in connection with the closing, Brookfield, FET and FirstEnergy Corp will enter into the FET LLC Agreement. The FET LLC Agreement, among other things, provides for the governance, exit, capital and distribution, and other arrangements for FET from and following the closing. Under the FET LLC Agreement, Brookfield will be entitled to appoint a number of directors to the FET Board, in approximate proportion to Brookfield’s ownership percentage in FET (rounded to the next whole number). Upon the closing, the FET Board will consist of five directors, one appointed by Brookfield and four appointed by FE. The FET LLC Agreement contains certain investor protections, including, among other things, requiring Brookfield's approval for FET and its subsidiaries to take certain major actions. Under the terms of the FET LLC Agreement, for so long as Brookfield holds a 9.9% interest in FET, Brookfield’s consent is required for FET or any of its subsidiaries to incur indebtedness (other than the refinancing of existing indebtedness on commercially reasonable terms reflecting then-current credit market conditions) that would reasonably be expected to result in FET’s consolidated Debt-to-Capital Ratio (as defined in the FET LLC Agreement) equaling or exceeding (i) prior to the fifth anniversary of the effective date, 65%, and (ii) thereafter, 70%.

New Accounting Pronouncements

Recently Issued Pronouncements - FirstEnergy has assessed new authoritative accounting guidance issued by the FASB that has not yet been adopted and none are currently expected to have a material impact to the financial statements.

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Revenue

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

REVENUE

REVENUE

FirstEnergy accounts for revenues from contracts with customers under ASC 606, “Revenue from Contracts with Customers.” Revenue from leases, financial instruments, other contractual rights or obligations and other revenues that are not from contracts with customers are outside the scope of the standard and accounted for under other existing GAAP.

FirstEnergy has elected to exclude sales taxes and other similar taxes collected on behalf of third parties from revenue as prescribed in the standard. As a result, tax collections and remittances are excluded from recognition in the income statement and instead recorded through the balance sheet. Excise and gross receipts taxes that are assessed on FirstEnergy are not subject to the election and are included in revenue. FirstEnergy has elected the optional invoice practical expedient for most of its revenues and utilizes the optional short-term contract exemption for transmission revenues due to the annual establishment of revenue requirements, which eliminates the need to provide certain revenue disclosures regarding unsatisfied performance obligations.

FirstEnergy’s revenues are primarily derived from electric service provided by the Utilities and Transmission Companies.

The following represents a disaggregation of revenue from contracts with customers for the three months ended March 31, 2022 and 2021:

	For the Three Months Ended March 31, 2022
Revenues by Type of Service	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments (1)		Total
	(In millions)
Distribution services	$	1,348	$	—	$	(28)	$	1,320
Retail generation	1,094		—		(17)		1,077
Wholesale sales	90		—		6		96
Transmission	—		451		—		451
Other	26		—		—		26
Total revenues from contracts with customers	$	2,558	$	451	$	(39)	$	2,970
Other revenue unrelated to contracts with customers	31		2		(14)		19
Total revenues	$	2,589	$	453	$	(53)	$	2,989

(1) Includes eliminations and reconciling adjustments of inter-segment revenues.

	For the Three Months Ended March 31, 2021
Revenues by Type of Service	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments (1)		Total
	(In millions)
Distribution services	$	1,339	$	—	$	(26)	$	1,313
Retail generation	935		—		(12)		923
Wholesale sales	69		—		4		73
Transmission	—		401		—		401
Other	33		—		—		33
Total revenues from contracts with customers	$	2,376	$	401	$	(34)	$	2,743
ARP (2)	(27)		—		—		(27)
Other revenue unrelated to contracts with customers	21		4		(15)		10
Total revenues	$	2,370	$	405	$	(49)	$	2,726

(1) Includes eliminations and reconciling adjustments of inter-segment revenues.

(2) Reflects amount the Ohio Companies refunded to customers that was previously collected under decoupling mechanisms, with interest. See Note 7, “Regulatory Matters,” for further discussion on Ohio decoupling rates.

Other revenue unrelated to contracts with customers includes revenue from late payment charges of $10 million and $9 million for the three months ended March 31, 2022 and 2021, respectively. Other revenue unrelated to contracts with customers also includes revenue from derivatives of $9 million for the three months ended March 31, 2022.

Regulated Distribution

The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies and also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. Each of the Utilities earns revenue from state-regulated rate tariffs under which it provides distribution services to residential, commercial and industrial customers in its service territory. The Utilities are obligated under the regulated construct to deliver power to customers reliably, as it is needed, which creates an implied monthly contract with the end-use customer. See Note 7, “Regulatory Matters,” for additional information on rate recovery mechanisms. Distribution and electric revenues are recognized over time as electricity is distributed and delivered to the customer and the customers consume the electricity immediately as delivery occurs.

Retail generation sales relate to POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey and Maryland, as well as generation sales in West Virginia that are regulated by the WVPSC. Certain of the Utilities have default service obligations to provide power to non-shopping customers who have elected to continue to receive service under regulated retail tariffs. The volume of these sales varies depending on the level of shopping that occurs. Supply plans vary by state and by service territory. Default service for the Ohio Companies, Pennsylvania Companies, JCP&L and PE’s Maryland jurisdiction are provided through a competitive procurement process approved by each state’s respective commission. Retail generation revenues are recognized over time as electricity is delivered and consumed immediately by the customer.

The following table represents a disaggregation of the Regulated Distribution segment revenue from contracts with distribution service and retail generation customers for the three months ended March 31, 2022 and 2021, by class:

	For the Three Months Ended March 31,
Revenues by Customer Class	2022		2021
	(In millions)
Residential	$	1,542	$	1,457
Commercial	597		541
Industrial	283		258
Other	20		18
Total Revenues	$	2,442	$	2,274

Wholesale sales primarily consist of generation and capacity sales into the PJM market from FirstEnergy’s regulated electric generation capacity and NUGs. Certain of the Utilities may also purchase power in the PJM markets to supply power to their customers. Generally, these power sales from generation and purchases to serve load are netted hourly and reported as either revenues or purchased power on the Consolidated Statements of Income based on whether the entity was a net seller or buyer

each hour. Capacity revenues are recognized ratably over the PJM planning year at prices cleared in the annual PJM Reliability Pricing Model Base Residual Auction and Incremental Auctions. Capacity purchases and sales through PJM capacity auctions are reported within revenues on the Consolidated Statements of Income. Certain capacity income (bonuses) and charges (penalties) related to the availability of units that have cleared in the auctions are unknown and not recorded in revenue until, and unless, they occur.

The Utilities’ distribution customers are metered on a cycle basis. An estimate of unbilled revenues is calculated to recognize electric service provided from the last meter reading through the end of the month. This estimate includes many factors, among which are historical customer usage, load profiles, estimated weather impacts, customer shopping activity and prices in effect for each class of customer. In each accounting period, the Utilities accrue the estimated unbilled amount as revenue and reverse the related prior period estimate. Customer payments vary by state but are generally due within 30 days.

ASC 606 excludes industry-specific accounting guidance for recognizing revenue from ARPs as these programs represent contracts between the utility and its regulators, as opposed to customers. Therefore, revenues from these programs are not within the scope of ASC 606 and regulated utilities are permitted to continue to recognize such revenues in accordance with existing practice but are presented separately from revenue arising from contracts with customers. FirstEnergy had ARPs in Ohio and has reflected refunds of decoupling revenue owed to customers as reductions to ARPs in 2021. Please see Note 7, “Regulatory Matters,” for further discussion on decoupling revenues in Ohio.

Regulated Transmission

The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission Companies and certain of FirstEnergy's utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to distribution facilities. The segment's revenues are derived from forward-looking formula rates. See Note 7, “Regulatory Matters,” for additional information.

Forward-looking formula rates recover costs that the regulatory agencies determine are permitted to be recovered and provide a return on transmission capital investment. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual costs. Revenues and cash receipts for the stand-ready obligation of providing transmission service are recognized ratably over time.

The following table represents a disaggregation of revenue from contracts with regulated transmission customers for the three months ended March 31, 2022 and 2021, by transmission owner:

	For the Three Months Ended March 31,
Transmission Owner	2022		2021
	(In millions)
ATSI	217		$	206
TrAIL	63		59
MAIT	79		67
JCP&L	60		36
MP, PE and WP	32		33
Total Revenues	$	451	$	401

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Earnings Per Share Of Common Stock

3 Months Ended

Mar. 31, 2022

Earnings Per Share [Abstract]

EARNINGS PER SHARE OF COMMON STOCK

EARNINGS PER SHARE OF COMMON STOCK

Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised.

Diluted EPS reflects the dilutive effect of potential common shares from share-based awards. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average market price for the period.

The following table reconciles basic and diluted EPS of common stock:

	For the Three Months Ended March 31,
Reconciliation of Basic and Diluted EPS	2022		2021
(In millions, except per share amounts)
Net Income	$	288	$	335
Share count information:
Weighted average number of basic shares outstanding	570		543
Assumed exercise of dilutive stock options and awards	1		1
Weighted average number of diluted shares outstanding	571		544
EPS of Common Stock:
Basic EPS of common stock	$	0.51	$	0.62
Diluted EPS of common stock	$	0.50	$	0.62

For the three months ended March 31, 2022 and March 31, 2021, no shares from stock options and awards were excluded from the calculation of diluted shares outstanding, as their inclusion would have been antidilutive.

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Pension and Other Post-Employment Benefits

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

PENSIONS AND OTHER POST-EMPLOYMENT BENEFITS

PENSION AND OTHER POST-EMPLOYMENT BENEFITS

The components of the consolidated net periodic costs (credits) for pension and OPEB were as follows:

Components of Net Periodic Benefit Costs (Credits)	Pension				OPEB
For the Three Months Ended March 31,	2022		2021		2022		2021
	(In millions)
Service costs	$	46	$	49	$	1	$	1
Interest costs	68		56		3		3
Expected return on plan assets	(164)		(163)		(10)		(10)
Amortization of prior service costs (credits)(1)	1		1		(3)		(4)
Net periodic credits, including amounts capitalized	$	(49)	$	(57)	$	(9)	$	(10)
Net periodic credits, recognized in earnings	$	(69)	$	(78)	$	(9)	$	(10)

(1) The income tax benefits associated with pension and OPEB prior service costs amortized out of AOCI were $1 million as of March 31, 2022 and 2021.

On March 11, 2021, President Biden signed into law the American Rescue Plan Act of 2021, which among other things, extended shortfall amortization periods and modification of the interest rate stabilization rules for single-employer plans thereby impacting funding requirements. As a result, FirstEnergy does not currently expect to have a required contribution to the pension plan based on various assumptions, including annual expected rate of returns for assets of 7.5%. However, FirstEnergy may elect to contribute to the pension plan voluntarily.

Service costs, net of capitalization, are reported within Other operating expenses on FirstEnergy’s Consolidated Statements of Income. Non-service costs, other than the pension and OPEB mark-to-market adjustment, which is separately shown, are reported within Miscellaneous income, net, within Other Income (Expense) on FirstEnergy’s Consolidated Statements of Income.

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Income Taxes

3 Months Ended

Mar. 31, 2022

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

FirstEnergy’s interim effective tax rates reflect the estimated annual effective tax rates for 2022 and 2021. These tax rates are affected by estimated annual permanent items, such as AFUDC equity and other flow-through items, as well as discrete items that may occur in any given period but are not consistent from period to period.

FirstEnergy’s effective tax rate on continuing operations for the three months ended March 31, 2022 and 2021, was 22.4% and 20.6%, respectively. The change in effective tax rate was primarily due to a valuation allowance against certain municipal deferred tax assets.

In February 2022, the IRS completed its examination of FirstEnergy’s 2020 federal income tax return and issued a Full Acceptance Letter with no adjustment to FirstEnergy’s taxable income. There was no material change to FirstEnergy’s reserve for uncertain tax positions for the first three months ended March 31, 2022, and it remains reasonably possible that

approximately $31 million of unrecognized tax benefits may be resolved in the next twelve months as a result of settlements with taxing authorities or the statute of limitations expiring, of which $24 million would ultimately affect FirstEnergy’s effective tax rate.

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Fair Value Measurements

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

RECURRING FAIR VALUE MEASUREMENTS

Authoritative accounting guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to Level 1 measurements and the lowest priority to Level 3 measurements. The three levels of the fair value hierarchy and a description of the valuation techniques are as follows:

Level 1	-	Quoted prices for identical instruments in active market.
Level 2	-	Quoted prices for similar instruments in active market.
	-	Quoted prices for identical or similar instruments in markets that are not active.
	-	Model-derived valuations for which all significant inputs are observable market data.

Models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.

Level 3 - Valuation inputs are unobservable and significant to the fair value measurement.

FirstEnergy produces a long-term power and capacity price forecast annually with periodic updates as market conditions change. When underlying prices are not observable, prices from the long-term price forecast are used to measure fair value.

FTRs are financial instruments that entitle the holder to a stream of revenues (or charges) based on the hourly day-ahead congestion price differences across transmission paths. FTRs are acquired by FirstEnergy in the annual, monthly and long-term PJM auctions and are initially recorded using the auction clearing price less cost. After initial recognition, FTRs’ carrying values are periodically adjusted to fair value using a mark-to-model methodology, which approximates market. The primary inputs into the model, which are generally less observable than objective sources, are the most recent PJM auction clearing prices and the FTRs’ remaining hours. The model calculates the fair value by multiplying the most recent auction clearing price by the remaining FTR hours less the prorated FTR cost. Significant increases or decreases in inputs in isolation may have resulted in a higher or lower fair value measurement.

FirstEnergy primarily applies the market approach for recurring fair value measurements using the best information available. Accordingly, FirstEnergy maximizes the use of observable inputs and minimizes the use of unobservable inputs. There were no changes in valuation methodologies used as of March 31, 2022, from those used as of December 31, 2021. The determination of the fair value measures takes into consideration various factors, including but not limited to, nonperformance risk, counterparty credit risk and the impact of credit enhancements (such as cash deposits, LOCs and priority interests). The impact of these forms of risk was not significant to the fair value measurements.

The following tables set forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy:

	March 31, 2022								December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(In millions)
Derivative assets FTRs(1)	$	—	$	—	$	1	$	1	$	—	$	—	$	9	$	9
Equity securities	2		—		—		2		2		—		—		2
U.S. state debt securities	—		258		—		258		—		273		—		273
Cash, cash equivalents and restricted cash(2)	310		—		—		310		1,511		—		—		1,511
Other(3)	—		45		—		45		—		42		—		42
Total assets	$	312	$	303	$	1	$	616	$	1,513	$	315	$	9	$	1,837
Liabilities
Derivative liabilities FTRs(1)	$	—	$	—	$	—	$	—	$	—	$	—	$	(1)	$	(1)
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	—	$	(1)	$	(1)
Net assets (liabilities)	$	312	$	303	$	1	$	616	$	1,513	$	315	$	8	$	1,836

(1)Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.

(2)Restricted cash of $27 million and $49 million as of March 31, 2022 and December 31, 2021 respectively, primarily relates to cash collected from MP, PE and the Ohio Companies’ customers that is specifically used to service debt of their respective securitization or funding companies.

(3)Primarily consists of short-term investments.

Level 3 Quantitative Information

The following table provides quantitative information for FTRs contracts that are classified as Level 3 in the fair value hierarchy for the period ended March 31, 2022:

	Fair Value, Net (In millions)		Valuation Technique	Significant Input	Range					Weighted Average	Units
FTRs	$	1	Model	RTO auction clearing prices	$	0.20	to	$	4.00	$0.90	Dollars/MWH

INVESTMENTS

All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash equivalents include equity securities, AFS debt securities and other investments. FirstEnergy has no debt securities held for trading purposes.

Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on AFS debt securities are recognized in AOCI. However, the spent nuclear fuel disposal trusts of JCP&L, ME and PN are subject to regulatory accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets.

Spent Nuclear Fuel Disposal Trusts

JCP&L holds debt securities within the spent nuclear fuel disposal trust, which are classified as AFS securities, recognized at fair market value. The trust is intended for funding spent nuclear fuel disposal fees to the DOE associated with the previously owned Oyster Creek and TMI-1 nuclear power plants.

The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held in spent nuclear fuel disposal trusts as of March 31, 2022, and December 31, 2021:

	March 31, 2022(1)								December 31, 2021(2)
	Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value		Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value
	(In millions)
Debt securities	$	279	$	—	$	(21)	$	258	$	280	$	2	$	(9)	$	273

(1) Excludes short-term cash investments of $13 million.

    (2) Excludes short-term cash investments of $11 million.

Proceeds from the sale of investments in AFS debt securities, realized gains and losses on those sales and interest and dividend income for the three months ended March 31, 2022 and 2021, were as follows:

	For the Three Months Ended March 31,
	2022		2021
	(In millions)
Sale proceeds	$	6	$	5
Realized gains	—		—
Realized losses	(1)		—
Interest and dividend income	3		3

Other Investments

Other investments include employee benefit trusts, which are primarily invested in corporate-owned life insurance policies and equity method investments. Other investments were $375 million and $371 million as of March 31, 2022, and December 31, 2021, respectively, and are excluded from the amounts reported above.

LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS

All borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature, FirstEnergy believes that their costs approximate their fair market value. The following table provides the approximate fair value and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance costs, unamortized fair value adjustments, premiums and discounts as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	(In millions)
Carrying value	$	22,900	$	23,946
Fair value	$	23,754	$	27,043

The fair values of long-term debt and other long-term obligations reflect the present value of the cash outflows relating to those securities based on the current call price, the yield to maturity or the yield to call, as deemed appropriate at the end of each respective period. The yields assumed were based on securities with similar characteristics offered by corporations with credit ratings similar to those of FirstEnergy. FirstEnergy classified short-term borrowings, long-term debt and other long-term obligations as Level 2 in the fair value hierarchy as of March 31, 2022, and December 31, 2021.

In December 2021, notice of redemption was provided for all remaining $850 million of FE’s 4.25% Notes, Series B, due 2023, which was completed on January 20, 2022, with a make-whole premium of approximately $38 million.

On January 27, 2022, CEI instructed its indenture trustee to provide notice of redemption for all remaining $150 million of CEI’s 2.77% Senior Notes, Series A, due 2034, for redemption which occurred on March 14, 2022.

Also on January 27, 2022, TE instructed its indenture trustee to provide notice of partial redemption for $25 million of TE’s 2.65% Senior Secured Notes, due 2028, for partial redemption which occurred on February 11, 2022.

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Regulatory Matters

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY MATTERS

STATE REGULATION

Each of the Utilities' retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE in Virginia, ATSI in Ohio, and the Transmission Companies in Pennsylvania are subject to certain regulations of the VSCC, PUCO and PPUC, respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and operate the new transmission facility.

MARYLAND

PE operates under MDPSC approved base rates that were effective as of March 23, 2019. PE also provides SOS pursuant to a combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively

procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS. PE expects to file a new base rate case in early 2023, consistent with the MDPSC’s order issued on March 22, 2019.

The EmPOWER Maryland program requires each electric utility to file a plan to reduce electric consumption and demand 0.2% per year, up to the ultimate goal of 2% annual savings, for the duration of the 2021-2023 EmPOWER Maryland program cycles to the extent the MDPSC determines that cost-effective programs and services are available. PE's approved 2021-2023 EmPOWER Maryland plan continues and expands upon prior years' programs for a projected total investment of approximately $148 million over the three-year period. PE recovers program investments with a return through an annually reconciled surcharge, with most costs subject to recovery over a five-year period with a return on the unamortized balance. Maryland law only allows for the utility to recover lost distribution revenue attributable to energy efficiency or demand reduction programs through a base rate case proceeding, and to date, such recovery has not been sought or obtained by PE.

NEW JERSEY

JCP&L operates under NJBPU approved rates that were effective for customers as of November 1, 2021. JCP&L provides BGS for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from customers as a charge separate from base rates.

JCP&L has instituted energy efficiency and peak demand reduction programs in accordance with the New Jersey Clean Energy Act as approved by the NJBPU in April 2021. The NJBPU approved plans include recovery of lost revenues resulting from the programs and a three-year plan including total program costs of $203 million, of which $158 million of investment is recovered over a ten-year amortization period with a return as well as operations and maintenance expenses and financing costs of $45 million recovered on an annual basis.

In December 2017, the NJBPU issued proposed rules to modify its current CTA policy in base rate cases to: (i) calculate savings using a five-year look back from the beginning of the test year; (ii) allocate savings with 75% retained by the company and 25% allocated to customers; and (iii) exclude transmission assets of electric distribution companies in the savings calculation. On January 17, 2019, the NJBPU approved the proposed CTA rules with no changes. On May 17, 2019, the NJ Rate Counsel filed an appeal with the Appellate Division of the Superior Court of New Jersey and on June 7, 2021, the Superior Court issued an order reversing the NJBPU’s CTA rules and remanded the case back to the NJBPU. Specifically, the Court’s ruling requires 100% of the CTA savings to be credited to customers in lieu of the NJBPU’s current policy requiring 25%. On December 6, 2021, the NJBPU issued proposed amended rules modifying its current CTA policy in base rate cases consistent with the Superior Court’s June 7, 2021 order. Comments were filed on March 3, 2022. Once the proposed rules are final, they will be applied on a prospective basis in a future base rate case, however, it is not expected to have a material adverse effect on FirstEnergy’s results or financial condition.

On October 28, 2020, the NJBPU approved a stipulated settlement between JCP&L and various parties, resolving JCP&L’s request for distribution base rate increase. The settlement provided for a $94 million annual base distribution revenues increase for JCP&L based on an ROE of 9.6%, which became effective for customers on November 1, 2021. The settlement additionally provided that JCP&L would be subject to a management audit. The management audit began in May 2021 and is currently ongoing.

On August 27, 2020, JCP&L filed an AMI Program with the NJBPU, which proposed the deployment of approximately 1.2 million advanced meters over a three-year period beginning on January 1, 2023, at a total cost of approximately $418 million, including the pre-deployment phase. The then proposed 3-year deployment was part of the 20-year AMI Program that was projected to cost approximately $732 million and proposed a cost recovery mechanism through a separate AMI tariff rider. On September 14, 2021, JCP&L submitted a supplemental filing, which reflected increases in the AMI Program’s costs. Under the revised AMI Program, during the first six years of the AMI Program from 2022 through 2027, JCP&L estimates costs of $494 million, consisting of capital expenditures of approximately $390 million, incremental operations and maintenance expenses of approximately $73 million and cost of removal of $31 million. On February 8, 2022, JCP&L filed with the NJBPU a stipulation entered into with the NJBPU staff, NJ Rate Counsel and others, that, pending NJBPU approval, would affirm the terms of the revised AMI Program. The Stipulation, which was approved by NJBPU order on February 23, 2022, also provides that the revised AMI Program-related capital costs, the legacy meter stranded costs, and the operations and maintenance expense will be deferred and placed in regulatory assets, with such amounts sought to be recovered in the JCP&L’s subsequent base rate cases.

On July 2, 2020, the NJBPU issued an order allowing New Jersey utilities to track and create a regulatory asset for future recovery of all prudently incurred incremental costs arising from the COVID-19 pandemic beginning March 9, 2020 and continuing until the New Jersey Governor issues an order stating that the COVID-19 pandemic is no longer in effect. New Jersey utilities can request recovery of such regulatory asset in a stand-alone COVID-19 regulatory asset filing or future base rate case. On October 28, 2020, the NJBPU issued an order expanding the scope of the proceeding to examine all pandemic issues, including recovery of the COVID-19 regulatory assets, by way of a generic proceeding. Through various executive orders issued

by the New Jersey Governor, the moratorium period was extended to December 31, 2021. On December 21, 2021, the moratorium on residential disconnections for certain entities providing utility service was extended until March 15, 2022. The moratorium on residential disconnections was not extended for investor-owned electric utilities such as JCP&L, but does require that investor-owned electric public utilities offer qualifying residential customers deferred payment arrangements meeting certain minimum criteria prior to disconnecting service. Additionally, while the moratorium on residential disconnections for certain entities providing electric service was not extended after March 15, 2022, new legislation was enacted on March 25, 2022, prohibiting utilities from disconnecting electric service to customers that have applied for utility bill assistance before June 15, 2022 until such time as the state agency administering the assistance program makes a decision on the application and further requiring that all utilities offer a deferred payment arrangement meeting certain minimum criteria after the state agency’s decision on the application has been made.

Pursuant to an NJBPU order requiring all New Jersey electric distribution companies to file electric vehicle programs, JCP&L filed its program on March 1, 2021. JCP&L’s proposed electric vehicle program consisted of six sub-programs, including a consumer education and outreach initiative that would begin on January 1, 2022, and continue over a four-year period. The total proposed budget for the electric vehicle program is approximately $50 million, including investments of $16 million and operations and maintenance expenses of $34 million. JCP&L is proposing to recover the electric vehicle program costs via a non-bypassable rate clause applicable to all distribution customer rate classes, which became effective on January 1, 2022. On May 26, 2021, a procedural schedule was set to include evidentiary hearings the week of October 18, 2021. On July 16, 2021, the procedural schedule was extended by thirty days as requested by JCP&L to continue settlement discussions. On August 19, 2021, the presiding commissioner issued an order modifying the procedural schedule by extending the procedural schedule by ninety days as requested by JCP&L to continue settlement discussions. On November 12, 2021, JCP&L filed a letter with the presiding commissioner requesting a suspension of the procedural schedule in order to allow the parties to continue settlement discussion. On November 23, 2021, the presiding commissioner entered an order suspending the procedural schedule. JCP&L expects an order from the NJBPU by the end of the second quarter of 2022.

OHIO

The Ohio Companies operate under PUCO approved base distribution rates that became effective in 2009. The Ohio Companies currently operate under ESP IV, effective June 1, 2016 and continuing through May 31, 2024, that continues the supply of power to non-shopping customers at a market-based price set through an auction process. ESP IV also continues the Rider DCR, which supports continued investment related to the distribution system for the benefit of customers, with increased revenue caps of $20 million per year from June 1, 2019 through May 31, 2022; and $15 million per year from June 1, 2022 through May 31, 2024. In addition, ESP IV includes: (1) continuation of a base distribution rate freeze through May 31, 2024; (2) a goal across FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and (3) contributions, totaling $51 million to: (a) fund energy conservation programs, economic development and job retention in the Ohio Companies’ service territories; (b) establish a fuel-fund in each of the Ohio Companies’ service territories to assist low-income customers; and (c) establish a Customer Advisory Council to ensure preservation and growth of the competitive market in Ohio.

On September 8, 2020, the OCC filed motions in the Ohio Companies’ corporate separation audit and DMR audit dockets, requesting the PUCO to open an investigation and management audit, hire an independent auditor, and require FirstEnergy to show it did not improperly use money collected from consumers or violate any utility regulatory laws, rules or orders in its activities regarding HB 6. On December 30, 2020, in response to the OCC's motion, the PUCO reopened the DMR audit docket, and directed PUCO staff to solicit a third-party auditor and conduct a full review of the DMR to ensure funds collected from customers through the DMR were only used for the purposes established in ESP IV. On June 2, 2021, the PUCO selected an auditor and the auditor filed the final audit report on January 14, 2022, which made certain findings and recommendations. The report found that spending of DMR revenues was not required to be tracked, and that DMR revenues, like all rider revenues, are placed into the regulated money pool as a matter of routine, where the funds lose their identity. Therefore, the report could not suggest that DMR funds were used definitively for direct or indirect support for grid modernization. The report also concluded that there was no documented evidence that ties revenues from the DMR to lobbying for the passage of HB 6, but also could not rule out with certainty uses of DMR funds to support the passage of HB 6. The report further recommended that the regulated companies' money pool be audited more frequently and the Ohio Companies adopt formal dividend policies.

On September 15, 2020, the PUCO opened a new proceeding to review the political and charitable spending by the Ohio Companies in support of HB 6 and the subsequent referendum effort, and directing the Ohio Companies to show cause, demonstrating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers. The Ohio Companies initially filed a response stating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers, but on August 6, 2021, filed a supplemental response explaining that, in light of the facts set forth in the DPA and the findings of the Rider DCR audit report further discussed below, political or charitable spending in support of HB 6, or the subsequent referendum effort, affected pole attachment rates paid by approximately $15 thousand. On October 26, 2021, the OCC filed a motion requesting the PUCO to order an independent external audit to investigate FE’s political and charitable spending related to HB 6, and to appoint an independent review panel to retain and oversee the auditor. In November and December 2021, parties filed comments and reply comments regarding the Ohio Companies’ original and supplemental responses to the PUCO’s September 15, 2020, show cause directive. On March 9, 2022, the PUCO directed its staff to seek the services of a third-party auditor to determine whether the show cause

demonstration submitted by the Ohio Companies is sufficient to ensure that the cost of any political or charitable spending in support of HB 6 or the subsequent referendum effort was not included, directly or indirectly, in any rates or charges paid by ratepayers.

In connection with an ongoing audit of the Ohio Companies’ policies and procedures relating to the code of conduct rules between affiliates, on November 4, 2020, the PUCO initiated an additional corporate separation audit as a result of the FirstEnergy leadership transition announcement made on October 29, 2020, as further discussed below. The additional audit is to ensure compliance by the Ohio Companies and their affiliates with corporate separation laws and the Ohio Companies’ corporate separation plan. The additional audit is for the period from November 2016 through October 2020. The final audit report was filed on September 13, 2021. The audit report makes no findings of major non-compliance with Ohio corporate separation requirements, minor non-compliance with eight requirements, and findings of compliance with 23 requirements. Parties filed comments and reply comments on the audit report, and a PUCO attorney examiner has issued a procedural schedule setting an evidentiary hearing on August 22, 2022.

In the fourth quarter of 2020, motions were filed with the PUCO requesting that the PUCO amend the Ohio Companies’ riders for collecting the OVEC related charges required by HB 6, which the Ohio Companies are further required to remit to other Ohio electric distribution utilities or to the State Treasurer, to provide for refunds in the event such provisions of HB 6 are repealed. The Ohio Companies contested the motions, which are pending before the PUCO.

On November 1, 2021, the Ohio Companies, together with the OCC, PUCO Staff, and several other signatories, entered into an Ohio Stipulation with the intent of resolving the ongoing energy efficiency rider audits, various SEET proceedings, including the Ohio Companies’ 2017 SEET proceeding, and the Ohio Companies’ quadrennial ESP review, each of which was pending before the PUCO. Specifically, the Ohio Stipulation provides that the Ohio Companies’ current ESP IV passes the required statutory test for their prospective SEET review as part of the Quadrennial Review of ESP IV, and except for limited circumstances, the signatory parties have agreed not to challenge the Ohio Companies’ SEET return on equity calculation methodology for their 2021-2024 SEET proceedings. The Ohio Stipulation additionally affirms that: (i) the Ohio Companies’ ESP IV shall continue through its previously authorized term of May 31, 2024; and (ii) the Ohio Companies will file their next base rate case in May 2024, and further, no signatory party will seek to adjust the Ohio Companies’ base distribution rates before that time, except in limited circumstances. The Ohio Companies further agreed to refund $96 million to customers in connection with the 2017-2019 SEET cases, and to provide $210 million in future rate reductions for all customers, including $80 million in 2022, $60 million in 2023, $45 million in 2024, and $25 million in 2025. The PUCO approved the 2017-2019 SEET refunds and 2022 rate reductions December 1, 2021, and refunds began in January 2022. Future rate reductions are recognized as a reduction to regulated distribution segment’s revenue in the Consolidated Statements of Income as they are provided to the Ohio Companies’ customers.

In connection with an ongoing annual audit of the Ohio Companies’ Rider DCR for 2020, and as a result of disclosures in FirstEnergy’s Form 10-K for the year ended December 31, 2020 (filed on February 18, 2021), the PUCO expanded the scope of the audit on March 10, 2021, to include a review of certain transactions that were either improperly classified, misallocated, or lacked supporting documentation, and to determine whether funds collected from customers were used to pay the vendors, and if so, whether or not the funds associated with those payments should be returned to customers through Rider DCR or through an alternative proceeding. On August 3, 2021, the auditor filed its final report on this phase of the audit, and the parties submitted comments and reply comments on this audit report in October 2021. Additionally, on September 29, 2021, the PUCO expanded the scope of the audit in this proceeding to determine if the costs of the naming rights for FirstEnergy Stadium have been recovered from the Ohio Companies’ customers. On November 19, 2021, the auditor filed its final report, in which the auditor concluded that the FirstEnergy Stadium naming rights expenses were not recovered from Ohio customers. On December 15, 2021, the PUCO further expanded the scope of the audit to include an investigation into an apparent nondisclosure of a side agreement in the Ohio Companies’ ESP IV settlement proceedings, but stayed its expansion of the audit until otherwise ordered by the PUCO.

See Note 8, "Commitments, Guarantees and Contingencies" below for additional details on the government investigations and subsequent litigation surrounding the investigation of HB 6.

PENNSYLVANIA

The Pennsylvania Companies operate under rates approved by the PPUC, effective as of January 27, 2017. On November 18, 2021, the PPUC issued orders to each of the Pennsylvania Companies directing they operate under DSPs for the June 1, 2019 through May 31, 2023 delivery period, which DSPs provide for the competitive procurement of generation supply for customers who do not receive service from an alternative EGS. Under the 2019-2023 DSPs, supply will be provided by wholesale suppliers through a mix of 3, 12 and 24-month energy contracts, as well as two RFPs for 2-year SREC contracts for ME, PN and Penn. On December 14, 2021, the Pennsylvania Companies filed proposed DSPs for provision of generation for the June 1, 2023 through May 31, 2027 delivery period, to be sourced through competitive procurements for customers who do not receive service from an alternative EGS. An evidentiary hearing was held on April 13, 2022, and the parties filed a partial settlement with the PPUC resolving most of the issues in the proceeding on April 20, 2022. The remaining issues in the proceeding, which are limited to the treatment of customer-generated energy and renewable energy credit production will be resolved through briefing. Under the

2023-2027 DSPs, supply is proposed to be provided through a mix of 12 and 24-month energy contracts, as well as long-term solar PPAs.

In March 2018, the PPUC approved adjusted customer rates of the Pennsylvania Companies to reflect the net impact of the Tax Act. As a result, the Pennsylvania Companies established riders that, beginning July 1, 2018, refunded to customers tax savings attributable to the Tax Act as compared to the amounts established in their most recent base rate proceedings on a current and going forward basis. The amounts recorded as savings for the total period of January 1 through June 30, 2018, were tracked and were to be addressed for treatment in a future proceeding. On May 17, 2021, the Pennsylvania Companies filed petitions with the PPUC proposing to refund the net savings for the January through June 2018 period to customers beginning January 1, 2022. On November 18, 2021, the PPUC approved the Pennsylvania Companies' proposed refunds, but also revised a previous methodology for calculating the net tax savings, which resulted in additional tax savings attributable to the Tax Act to be refunded to customers and directed the Pennsylvania Companies to file new petitions to propose the timing and methodology to provide these additional refunds to customers. The Pennsylvania Companies recalculated the net impact for 2018 through 2021 under the revised PPUC methodology in comparison to amounts already refunded to customers under the existing riders, which resulted in an additional $61 million in savings, with interest, to be provided to customers. As a result, FirstEnergy recognized a pre-tax charge of $61 million in the fourth quarter of 2021 associated with the additional refund and based on the November 2021 PPUC order and methodology. The Pennsylvania Companies filed petitions to propose the timing and methodology of the refund of these amounts on February 17, 2022. If approved, the Pennsylvania Companies would refund these amounts beginning July 1, 2022, and continuing through the end of the year.

Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, Pennsylvania EDCs implement energy efficiency and peak demand reduction programs. On June 18, 2020, the PPUC entered a Final Implementation Order for a Phase IV EE&C Plan, operating from June 2021 through May 2026. The Final Implementation Order set demand reduction targets, relative to 2007 to 2008 peak demands, at 2.9% MW for ME, 3.3% MW for PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania Companies’ historic 2009 to 2010 reference load at 3.1% MWH for ME, 3.0% MWH for PN, 2.7% MWH for Penn, and 2.4% MWH for WP. The Pennsylvania Companies’ Phase IV plans were approved by PPUC without modification on March 25, 2021.

Pennsylvania EDCs are permitted to seek PPUC approval of an LTIIP for infrastructure improvements and costs related to highway relocation projects, after which a DSIC may be approved to recover LTIIP costs. On January 16, 2020, the PPUC approved the Pennsylvania Companies’ LTIIPs for the five-year period beginning January 1, 2020 and ending December 31, 2024 for a total capital investment of approximately $572 million for certain infrastructure improvement initiatives. On June 25, 2021, the Pennsylvania OCA filed a complaint against Penn’s quarterly DSIC rate, disputing the recoverability of the Companies’ automated distribution management system investment under the DSIC mechanism. On January 26, 2022, the parties filed a joint petition for settlement that resolves all issues in this matter pending PPUC approval.

Following the Pennsylvania Companies’ 2016 base rate proceedings, the PPUC ruled in a separate proceeding related to the DSIC mechanisms that the Pennsylvania Companies were not required to reflect federal and state income tax deductions related to DSIC-eligible property in DSIC rates. The decision was appealed to the Pennsylvania Supreme Court and in July 2021 the court upheld the Pennsylvania Commonwealth Court’s reversal of the PPUC’s decision and remanded the matter back to the PPUC for determination as to how DSIC calculations shall account for ADIT and state taxes. The matter awaits further action by the PPUC. The adverse ruling by the Pennsylvania Supreme Court is not expected to result in a material impact to FirstEnergy.

WEST VIRGINIA

MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate under WVPSC approved rates that became effective in February 2015. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s ENEC rate is updated annually.

On December 30, 2020, MP and PE filed with the WVPSC a determination of the rate impact of the Tax Act with respect to ADIT. The filing proposed an annual revenue reduction of $2.6 million, effective January 1, 2022, with reconciliation and any resulting adjustments incorporated into annual ENEC proceedings. On August 12, 2021, a unanimous settlement was reached with all the parties agreeing to a $7.7 million rate reduction beginning January 1, 2022, with a true-up in the ENEC proceeding each year. On November 30, 2021, the WVPSC approved the settlement on all terms, except for the proposed effective date of the rate reduction, which was held in abeyance until further notice.

On August 27, 2021, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates of $19.6 million beginning January 1, 2022, which represented a 1.5% increase to the rates currently in effect. WVPSC issued an order on December 29, 2021, granting the requested $19.6 million increase in ENEC rates. Among other things, the order requires MP and PE to refund to its large industrial customers their respective portion of the $7.7 million rate reduction discussed above and also requires MP and PE to negotiate a PPA for its capacity shortfall and a reasonable reserve margin if certain conditions are met. By order dated March 2, 2022, the WVPSC reopened the case to determine whether rates should be increased to recover growing ENEC under-recoveries. MP and PE proposed a $94 million rate increase to address the growing under-recoveries and a hearing was held on March 24, 2022. Any interim rate increase approved by WVPSC would be expected to begin May 1, 2022.

On December 3, 2021 and on December 27, 2021, the WVPSC approved settlements granting MP and PE a $16 million increase in rates effective January 1, 2022, and permitting the continuation of the vegetation management program and surcharge for another two years. WVPSC additionally ordered MP and PE to perform equipment inspections within a reasonable time after vegetation management occurs on a circuit.

On November 22, 2021, MP and PE filed with the WVPSC their plan to construct 50 MWs of solar generation at five sites in West Virginia. The plan includes a tariff to offer solar power to West Virginia customers and cost recovery for MP and PE from other customers through a surcharge for any solar investment not fully subscribed by their customers. A hearing was held on March 16 and 17, 2022, and an order is expected in the second quarter of 2022. The solar generation project, if approved, is expected to cost approximately $110 million and begin being in-serviced by the end of 2023 with all construction completed at the other sites no later than the end of 2025.

On December 17, 2021, MP and PE filed with the WVPSC for approval of environmental compliance projects at the Ft. Martin and Harrison Power Stations to comply with the EPA’s ELG and operate these plants beyond 2028. The request includes a surcharge to recover the expected $142 million capital investment and $3 million in annual operation and maintenance expense. A hearing has been set for in August 2022, with a ruling from the WVPSC expected in the fall of 2022. If approved, construction would be expected to be completed by the end of 2025. See Note 8, “Commitments, Guarantees and Contingencies - Environmental Matters - Clean Water Act" below, for additional details on the EPA's ELG.

FERC REGULATORY MATTERS

Under the FPA, FERC regulates rates for interstate wholesale sales, transmission of electric power, accounting and other matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the Utilities, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP, PE, WP and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and conditions. Transmission facilities of JCP&L, MP, PE, WP and the Transmission Companies are subject to functional control by PJM and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.

FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or erect barriers to entry into markets. The Utilities and AE Supply each have been authorized by FERC to sell wholesale power in interstate commerce at market-based rates and have a market-based rate tariff on file with FERC, although in the case of the Utilities major wholesale purchases remain subject to review and regulation by the relevant state commissions.

Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-keeping and reporting requirements on the Utilities, AE Supply, and the Transmission Companies. NERC is the ERO designated by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are located within the RFC region. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards implemented and enforced by RFC.

FirstEnergy believes that it is in material compliance with all currently effective and enforceable reliability standards. Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial condition, results of operations, and cash flows.

FERC Audit

FERC’s Division of Audits and Accounting initiated a nonpublic audit of FESC in February 2019. Among other matters, the audit is evaluating FirstEnergy’s compliance with certain accounting and reporting requirements under various FERC regulations. On February 4, 2022, FERC filed the final audit report for the period of January 1, 2015 through September 30, 2021, which included several findings and recommendations. FirstEnergy has accepted the findings and recommendations of the final audit report. The audit report included a finding and related recommendation that FirstEnergy may have used an inappropriate methodology for allocation of certain costs to regulatory capital accounts under certain FERC regulations and reporting. As such, FirstEnergy is currently performing an analysis of these costs and how it impacted certain wholesale transmission customer rates. FirstEnergy is unable to predict or estimate the final outcome of this analysis and audit, however, it could result in refunds, with interest, to certain wholesale transmission customers and/or write-offs of previously capitalized costs if they are determined to be nonrecoverable.

ATSI Transmission Formula Rate

On May 1, 2020, ATSI filed amendments to its formula rate to recover regulatory assets for certain costs that ATSI incurred as a result of its 2011 move from MISO to PJM, certain costs allocated to ATSI by FERC for transmission projects that were constructed by other MISO transmission owners, and certain costs for transmission-related vegetation management programs. A portion of these costs would have been charged to the Ohio Companies. Additionally, ATSI proposed certain income tax-related adjustments and certain tariff changes addressing the revenue credit components of the formula rate template. On June 30, 2020, FERC issued an initial order accepting the tariff amendments subject to refund and setting the matter for hearing and settlement proceedings. ATSI and the parties to the FERC proceeding subsequently were able to reach settlement, and on October 14, 2021, filed the settlement with FERC. As a result of the filed settlement, FirstEnergy recognized a $21 million pre-tax charge during the third quarter of 2021, which reflects the difference between amounts originally recorded as regulatory assets and amounts which will ultimately be recovered as a result of the pending settlement. From a segment perspective, during the third quarter of 2021, the Regulated Transmission segment recorded a pre-tax charge of $48 million and the Regulated Distribution segment recognized a $27 million reduction to a reserve previously recorded in 2010. In addition, the settlement provides for partial recovery of future incurred costs allocated to ATSI by MISO for the above-referenced transmission projects that were constructed by other MISO transmission owners, which is not expected to have a material impact on FirstEnergy or ATSI. The uncontested settlement was approved by FERC on March 24, 2022 without modification.

FERC Actions on Tax Act

On March 15, 2018, FERC initiated proceedings on the question of how to address possible changes to ADIT and bonus depreciation as a result of the Tax Act. Such possible changes could impact FERC-jurisdictional rates, including transmission rates. On November 21, 2019, FERC issued a final rule (Order No. 864). Order No. 864 requires utilities with transmission formula rates to update their formula rate templates to include mechanisms to: (i) deduct any excess ADIT from or add any deficient ADIT to their rate base; (ii) raise or lower their income tax allowances by any amortized excess or deficient ADIT; and (iii) incorporate a new permanent worksheet into their rates that will annually track information related to excess or deficient ADIT. Per FERC directives, ATSI submitted its compliance filing on May 1, 2020. MAIT submitted its compliance filing on June 1, 2020. On November 18, 2021, FERC issued an order that: (i) accepted ATSI proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed ATSI to make a further compliance filing by January 17, 2022; and (iii) set the amount of ATSI’s recorded ADIT balances as of December 31, 2017, for hearing and settlement procedures. ATSI submitted the compliance filing, and is participating in settlement negotiations. On December 3, 2021, FERC issued an order that (i) accepted MAIT’s proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed MAIT to make a further compliance filing by February 1, 2022; and (iii) set the amount of MAIT’s recorded ADIT balances as of December 31, 2017 for hearing and settlement procedures. MAIT submitted the compliance filing, and is participating in settlement negotiations. On May 15, 2020, TrAIL submitted its compliance filing and on June 1, 2020, PATH submitted its required compliance filing. On May 4, 2021, FERC staff requested additional information about PATH’s proposed rate base adjustment mechanism, and PATH submitted the requested information on June 3, 2021. On July 12, 2021, FERC staff requested additional information about TrAIL’s proposed rate base adjustment mechanism. TrAIL filed its response on August 6, 2021. On March 31, 2022, FERC issued an order, ruling that TrAIL’s compliance filing partially complied with the requirements of Order No. 864 and directing TrAIL to submit a further compliance filing on or before May 31, 2022 to address certain additional items that according to FERC further will enhance transparency. The PATH compliance filing remains pending before FERC. MP, WP and PE (as holders of a “stated” transmission rate when Order No. 864 issued) are addressing these requirements in the transmission formula rates amendments that were filed on October 29, 2020, and which have been accepted by FERC effective January 1, 2021, subject to refund, pending further hearing and settlement procedures. MP, WP and PE are engaged in settlement negotiations with other parties to this proceeding.

ATSI ROE – Ohio Consumers Counsel v. ATSI, et al.

On February 24, 2022, the OCC filed a complaint with FERC against ATSI, AEP’s Ohio affiliates and AEPSC, and Duke Energy Ohio, LLC asserting that FERC should reduce the ROE utilized in the utilities’ transmission formula rates by eliminating the 50 basis point adder associated with RTO membership, effective February 24, 2022. The OCC contends that this result is required

because Ohio law mandates that transmission owning utilities join an RTO and that the 50 basis point adder is applicable only where RTO membership is voluntary. ATSI disagrees with OCC’s characterization and set forth its reasons for such disagreement in a combined motion to dismiss and answer that was filed with FERC on March 31, 2022. On that same date, AEP and Duke filed separate motions to dismiss and answers to the OCC complaint, and several other parties filed comments. ATSI is currently evaluating whether to file an additional answer to respond to certain of the comments.

Transmission ROE Methodology

On March 20, 2020, FERC initiated a rulemaking proceeding on the transmission rate incentives provisions of Section 219 of the 2005 Energy Policy Act. FirstEnergy submitted comments through EEI and as part of a consortium of PJM Transmission Owners. In a supplemental rulemaking proceeding that was initiated on April 15, 2021, FERC requested comments on, among other things, whether to require utilities that have been members of an RTO for three years or more and that have been collecting an “RTO membership” ROE incentive adder to file tariff updates that would terminate collection of the incentive adder. Initial comments on the proposed rule were filed on June 25, 2021, and reply comments were filed on July 26, 2021. The rulemaking remains pending before FERC. FirstEnergy is a member of PJM and its transmission subsidiaries could be affected by the supplemental proposed rule. FirstEnergy participated in comments on the supplemental rulemaking that were submitted by a group of PJM transmission owners and by various industry trade groups. If there were to be any changes to FirstEnergy transmission incentive ROE, such changes will be applied on a prospective basis.

Allegheny Power Zone Transmission Formula Rate Filings

On October 29, 2020, MP, PE and WP filed tariff amendments with FERC to implement a forward-looking formula transmission rate, to be effective January 1, 2021. In addition, on October 30, 2020, KATCo filed a proposed new tariff to establish a forward-looking formula rate and requested that the new rate become effective January 1, 2021. In its filing, KATCo explained that while it currently owns no transmission assets, it may build new transmission facilities in the Allegheny zone, and that it may seek required state and federal authorizations to acquire transmission assets from PE and WP by January 1, 2022. These transmission rate filings were accepted for filing by FERC on December 31, 2020, effective January 1, 2021, subject to refund, pending further hearing and settlement procedures and were consolidated into a single proceeding. MP, PE and WP, and KATCo are engaged in settlement negotiations with the other parties to the formula rate proceedings.

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Commitments, Guarantees and Contingencies

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS, GUARANTEES AND CONTINGENCIES

COMMITMENTS, GUARANTEES AND CONTINGENCIES

GUARANTEES AND OTHER ASSURANCES

FirstEnergy has various financial and performance guarantees and indemnifications, which are issued in the normal course of business. These contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications. FirstEnergy enters into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party.

As of March 31, 2022, outstanding guarantees and other assurances aggregated approximately $1.1 billion, consisting of parental guarantees on behalf of its consolidated subsidiaries ($602 million) and other assurances ($468 million).

COLLATERAL AND CONTINGENT-RELATED FEATURES

In the normal course of business, FE and its subsidiaries may enter into physical or financially settled contracts for the sale and purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require FE or its subsidiaries to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon FE’s or its subsidiaries’ credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty.

As of March 31, 2022, $52 million of collateral has been posted by FE or its subsidiaries and is included in Prepaid taxes and other current assets on FirstEnergy’s Consolidated Balance Sheets.

These credit-risk-related contingent features stipulate that if the subsidiary 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. The following table discloses the potential additional credit rating contingent contractual collateral obligations as of March 31, 2022:

Potential Collateral Obligations		Utilities and Transmission Companies		FE		Total
	(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade		$	43	$	—	$	43
Surety Bonds (Collateralized Amount) (1)		57		258		315
Total Exposure from Contractual Obligations		$	100	$	258	$	358

(1)Surety Bonds are not tied to a credit rating. Surety Bonds’ impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with the respect to $39 million of surety bond obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.

ENVIRONMENTAL MATTERS

Various federal, state and local authorities regulate FirstEnergy with regard to air and water quality, hazardous and solid waste disposal, and other environmental matters. While FirstEnergy’s environmental policies and procedures are designed to achieve compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and potential revision by the implementing agencies. FirstEnergy cannot predict the timing or ultimate outcome of any of these reviews or how any future actions taken as a result thereof may materially impact its business, results of operations, cash flows and financial condition.

Clean Air Act

FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP(s) by burning lower-sulfur fuel, utilizing combustion controls and post-combustion controls and/or using emission allowances.

CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and SO2 emission allowances between power plants located in the same state and interstate trading of NOx and SO2 emission allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx and SO2 emissions from power plants in 13 states, including West Virginia. This followed the 2014 U.S. Supreme Court ruling generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on September 7, 2016, reducing summertime NOx emissions from power plants in 22 states in the eastern U.S., including West Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable attainment deadlines.

Also in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone NAAQS. The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126 petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA issued a revised CSAPR Update that addresses, among other things, the remands of the prior CSAPR Update and the New York Section 126 petition. In December 2021, MP purchased NOx emissions allowances to comply with 2021 ozone season requirements. On April 6, 2022, the EPA published proposed rules seeking to impose further significant reductions in EGU NOx emissions in 25 states, including West Virginia. The EPA held a virtual public hearing regarding the proposed rules on April 21, 2022, with comments due June 6, 2022. Depending on the outcome of any appeals and how the EPA and the states ultimately implement the revised CSAPR Update, the future cost of compliance may materially impact FirstEnergy's operations, cash flows and financial condition.

Climate Change

There are several initiatives to reduce GHG emissions at the state, federal and international level. Certain northeastern states are participating in the RGGI and western states led by California, have implemented programs, primarily cap and trade mechanisms, to control emissions of certain GHGs. Additional policies reducing GHG emissions, such as demand reduction programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.

In September 2016, the U.S. joined in adopting the agreement reached on December 12, 2015, at the United Nations Framework Convention on Climate Change meetings in Paris to reduce GHGs. The Paris Agreement’s non-binding obligations to limit global

warming to below two degrees Celsius became effective on November 4, 2016. On June 1, 2017, the Trump Administration announced that the U.S. would cease all participation in the Paris Agreement. On January 20, 2021, President Biden signed an executive order re-adopting the agreement on behalf of the U.S. In November 2020, FirstEnergy published its Climate Story which includes its climate position and strategy, as well as a new comprehensive and ambitious GHG emission goal. FirstEnergy pledged to achieve carbon neutrality by 2050 and set an interim goal for a 30% reduction in GHGs within FirstEnergy’s direct operational control by 2030, based on 2019 levels. Future resource plans to achieve carbon reductions, including any determination of retirement dates of the regulated coal-fired generation, will be developed by working collaboratively with regulators in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory disallowances. If MP is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s financial condition, results of operations, and cash flow. Furthermore, FirstEnergy cannot currently estimate the financial impact of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions, or litigation alleging damages from GHG emissions, could require material capital and other expenditures or result in changes to its operations.

In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air Act,” concluding that concentrations of several key GHGs constitute an "endangerment" and may be regulated as "air pollutants" under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generating plants. Subsequently, the EPA released its final CPP regulations in August 2015 to reduce CO2 emissions from existing fossil fuel-fired EGUs and finalized separate regulations imposing CO2 emission limits for new, modified, and reconstructed fossil fuel-fired EGUs. Numerous states and private parties filed appeals and motions to stay the CPP with the D.C. Circuit in October 2015. On February 9, 2016, the U.S. Supreme Court stayed the rule during the pendency of the challenges to the D.C. Circuit and U.S. Supreme Court. On March 28, 2017, an executive order, entitled “Promoting Energy Independence and Economic Growth,” instructed the EPA to review the CPP and related rules addressing GHG emissions and suspend, revise or rescind the rules if appropriate. On June 19, 2019, the EPA repealed the CPP and replaced it with the ACE rule that established guidelines for states to develop standards of performance to address GHG emissions from existing coal-fired generation. On January 19, 2021, the D.C. Circuit vacated and remanded the ACE rule declaring that the EPA was “arbitrary and capricious” in its rule making and, as such, the ACE rule is no longer in effect and all actions thus far taken by states to implement the federally mandated rule are now null and void. The D.C. Circuit decision was appealed by several states, including West Virginia, as well as other interested parties. On February 28, 2022, the U.S. Supreme Court heard oral arguments on the matter is subject to legal challenge. Depending on the outcomes of the appeal and how any final rules are ultimately implemented, the future cost of compliance may be material.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal CWA and its amendments, apply to FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to FirstEnergy’s operations.

On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category (40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of pollutants in ash transport water. The treatment obligations were to phase-in as permits are renewed on a five-year cycle from 2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water, (with some limited discharge allowances), and extending the deadline for compliance to December 31, 2025 for both. In addition, the EPA allows for less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system, and unit retirement date. The EPA is reconsidering the ELG rule with a publicly announced target of issuing a proposed revised rule in the Fall of 2022 and a final rule by the Spring of 2023. In the interim, the rule issued on August 31, 2020, remains in effect. Depending on the outcome of appeals and how final rules are ultimately implemented, the compliance with these standards, could require additional capital expenditures or changes in operations at Ft. Martin and Harrison power stations from what was filed with the WVPSC in December 2021 that seeks approval of environmental compliance projects to comply with the EPA’s ELG.

After the completion of a negotiated settlement, a complaint was filed by the EPA and PA DEP on January 10, 2022 in Federal District Court for the Western District of Pennsylvania, alleging, among other things, that WP violated the CWA in connection with past boron exceedances at WP’s Springdale and Mingo landfills. On January 11, 2022, WP entered into a consent decree with the EPA and PA DEP resolving the matters addressed in the complaint, which, among other things, required a civil penalty of $610 thousand. The District Court entered the Consent Decree as final on March 17, 2022 and WP subsequently paid the penalty amount as required therein.

Regulation of Waste Disposal

Federal and state hazardous waste regulations have been promulgated as a result of the RCRA, as amended, and the Toxic Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending the EPA’s evaluation of the need for future regulation.

In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generating plants. On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29, 2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and initiate closure to April 11, 2021. The final rule also allows for an extension of the closure deadline based on meeting proscribed site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to extend the closure date of McElroy's Run CCR impoundment facility until 2024, which request is pending technical review by the EPA. AE Supply continues to operate McElroy’s Run as a disposal facility for FG’s Pleasants Power Station.

FE or its subsidiaries have been named as potentially responsible parties at waste disposal sites, which may require cleanup under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on the Consolidated Balance Sheets as of March 31, 2021, based on estimates of the total costs of cleanup, FirstEnergy’s proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of approximately $110 million have been accrued through March 31, 2022, of which, approximately $70 million are for environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through a non-bypassable SBC. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites, but the loss or range of losses cannot be determined or reasonably estimated at this time.

OTHER LEGAL PROCEEDINGS

United States v. Larry Householder, et al.

On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Also, on July 21, 2020, and in connection with the investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s Office for the S.D. Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020.

On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves this matter. Under the DPA, FE has agreed to the filing of a criminal information charging FE with one count of conspiracy to commit honest services wire fraud. The DPA requires that FirstEnergy, among other obligations: (i) continue to cooperate with the U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, which shall consist of (x) $115 million paid by FE to the United States Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and detect violations of the U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million payment will neither be recovered in rates or charged to FirstEnergy customers nor will FirstEnergy seek any tax deduction related to such payment. The entire amount of the monetary penalty was recognized as expense in the second quarter of 2021, and paid in the third quarter of 2021. Under the terms of the DPA, the criminal information will be dismissed after FirstEnergy fully complies with its obligations under the DPA.

Legal Proceedings Relating to United States v. Larry Householder, et al.

On August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of possible securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers. On April 28, 2021, the SEC issued an additional subpoena to FE. While no contingency has been reflected in its consolidated financial statements, FE believes that it is probable that it will incur a loss in connection with the resolution of the SEC investigation. Given the ongoing nature and complexity of the review, inquiries and investigations, FE cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the SEC investigation.

In addition to the subpoenas referenced above under “—United States v. Larry Householder, et. al.” and the SEC investigation, certain FE stockholders and FirstEnergy customers filed several lawsuits against FirstEnergy and certain current and former directors, officers and other employees, and the complaints in each of these suits is related to allegations in the complaint and supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover an unspecified amount of damages (unless otherwise noted). Unless otherwise indicated, no contingency has been reflected in FirstEnergy’s consolidated financial statements with respect to these lawsuits as a loss is neither probable, nor is a loss or range of a loss reasonably estimable.

•In re FirstEnergy Corp. Securities Litigation (Federal District Court, S.D. Ohio); on July 28, 2020 and August 21, 2020, purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those actions have been consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017 and July 21, 2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by issuing misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11, 12(a)(2) and 15 of the Securities Act of 1933 as a result of alleged misrepresentations or omissions in connection with offerings of senior notes by FE in February and June 2020. FE believes that it is probable that it will incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•MFS Series Trust I, et al. v. FirstEnergy Corp., et al. and Brighthouse Funds II – MFS Value Portfolio, et al. v. FirstEnergy Corp., et al. (Federal District Court, S.D. Ohio) on December 17, 2021 and February 21, 2022, purported stockholders of FE filed complaints against FE, certain current and former officers, and certain current and former officers of EH. The complaints allege that the defendants violated Sections 10(b) and 20(a) of the Exchange Act by issuing alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seek the same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will incur losses in connection with the resolution of these lawsuits. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•State of Ohio ex rel. Dave Yost, Ohio Attorney General v. FirstEnergy Corp., et al. and City of Cincinnati and City of Columbus v. FirstEnergy Corp. (Common Pleas Court, Franklin County, OH, all actions have been consolidated); on September 23, 2020 and October 27, 2020, the OAG and the cities of Cincinnati and Columbus, respectively, filed complaints against several parties including FE (the OAG also named FES as a defendant), each alleging civil violations of the Ohio Corrupt Activity Act in connection with the passage of HB 6. On January 13, 2021, the OAG filed a motion for a temporary restraining order and preliminary injunction against FirstEnergy seeking to enjoin FirstEnergy from collecting the Ohio Companies' decoupling rider. On January 31, 2021, FE reached a partial settlement with the OAG and the cities of Cincinnati and Columbus with respect to the temporary restraining order and preliminary injunction request and related issues. In connection with the partial settlement, the Ohio Companies filed an application on February 1, 2021, with the PUCO to set their respective decoupling riders (CSR) to zero. On February 2, 2021, the PUCO approved the application of the Ohio Companies setting the rider to zero and no additional customer bills will include new decoupling rider charges after February 8, 2021. The cases are stayed pending final resolution of the United States v. Larry Householder, et al. criminal proceeding described above, although on August 13, 2021, new defendants were added to the complaint, including two former officers of FirstEnergy. On November 9, 2021, the OAG filed a motion to lift the agreed-upon stay, which FE opposed on November 19, 2021; the motion remains pending. On December 2, 2021, the cities and FE entered a stipulated dismissal with prejudice of the cities’ suit.

•Smith v. FirstEnergy Corp. et al., Buldas v. FirstEnergy Corp. et al., and Hudock and Cameo Countertops, Inc. v. FirstEnergy Corp. et al. (Federal District Court, S.D. Ohio, all actions have been consolidated); on July 27, 2020, July 31, 2020, and August 5, 2020, respectively, purported customers of FE filed putative class action lawsuits against FE and FESC, as well as certain current and former FE officers, alleging civil Racketeer Influenced and Corrupt Organizations Act violations and related state law claims. FE agreed to a settlement to resolve these claims on April 11, 2022. In the fourth quarter of 2021, FirstEnergy recognized a pre-tax reserve of $37.5 million in the aggregate with respect to these lawsuits and the Emmons lawsuit below.

•Emmons v. FirstEnergy Corp. et al. (Common Pleas Court, Cuyahoga County, OH); on August 4, 2020, a purported customer of FirstEnergy filed a putative class action lawsuit against FE, FESC, the Ohio Companies, along with FES, alleging several causes of action, including negligence and/or gross negligence, breach of contract, unjust enrichment, and unfair or deceptive consumer acts or practices. FE agreed to a settlement to resolve these claims on April 11, 2022. In the fourth quarter of 2021, FirstEnergy recognized a pre-tax reserve of $37.5 million in the aggregate with respect to this lawsuit and the lawsuits above consolidated with Smith in the S.D. Ohio alleging, among other things, civil violations of the Racketeer Influenced and Corrupt Organizations Act.

On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve the following shareholder derivative lawsuits relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder that were filed in the S.D. Ohio, the N.D. Ohio, and the Ohio Court of Common Pleas, Summit County:

•Gendrich v. Anderson, et al. and Sloan v. Anderson, et al. (Common Pleas Court, Summit County, OH, all actions have been consolidated); on July 26, 2020 and July 31, 2020, respectively, purported stockholders of FE filed shareholder derivative action lawsuits against certain FE directors and officers, alleging, among other things, breaches of fiduciary duty.

•Miller v. Anderson, et al. (Federal District Court, N.D. Ohio); Bloom, et al. v. Anderson, et al.; Employees Retirement System of the City of St. Louis v. Jones, et al.; Electrical Workers Pension Fund, Local 103, I.B.E.W. v. Anderson et al.; Massachusetts Laborers Pension Fund v. Anderson et al.; The City of Philadelphia Board of Pensions and Retirement v. Anderson et al.; Atherton v. Dowling et al.; Behar v. Anderson, et al. (Federal District Court, S.D. Ohio, all actions

have been consolidated); beginning on August 7, 2020, purported stockholders of FE filed shareholder derivative actions alleging the FE Board and officers breached their fiduciary duties and committed violations of Section 14(a) of the Exchange Act.

On March 11, 2022, the parties executed a stipulation and agreement of settlement, and filed a motion the same day requesting preliminary settlement approval in the S.D. Ohio. The settlement agreement, if approved, will fully resolve the shareholder derivative lawsuits above and stipulates a series of corporate governance enhancements, that has resulted or is expected to result in the following:

•Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D. Pappas and Luis A. Reyes, and Ms. Julia L. Johnson are not standing for re-election at FE’s 2022 annual shareholder meeting;

•A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;

•The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political and lobbying action plans prepared by management;

•An FE Board committee of recently appointed independent directors will oversee the implementation and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;

•FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced disclosure in its annual proxy statement; and

•FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.

The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any court-ordered attorney’s fees awarded to plaintiffs.

In letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that the Division is conducting an investigation of FirstEnergy’s lobbying and governmental affairs activities concerning HB 6, and staff directed FirstEnergy to preserve and maintain all documents and information related to the same as such have been developed as part of an ongoing non-public audit being conducted by FERC's Division of Audits and Accounting. While no contingency has been reflected in the consolidated financial statements, FirstEnergy believes that it is probable that it will incur a loss in connection with the resolution of the FERC investigation. Given the ongoing nature and complexity of the review, inquiries and investigations, FirstEnergy cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the FERC investigation.

The outcome of any of these lawsuits, governmental investigations and audit is uncertain and could have a material adverse effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.

Other Legal Matters

There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to FirstEnergy’s normal business operations pending against FE or its subsidiaries. The loss or range of loss in these matters is not expected to be material to FE or its subsidiaries. The other potentially material items not otherwise discussed above are described under Note 7, “Regulatory Matters.”

FirstEnergy accrues legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such costs. In cases where FirstEnergy determines that it is not probable, but reasonably possible that it has a material obligation, it discloses such obligations and the possible loss or range of loss if such estimate can be made. If it were ultimately determined that FE or its subsidiaries have legal liability or are otherwise made subject to liability based on any of the matters referenced above, it could have a material adverse effect on FE’s or its subsidiaries’ financial condition, results of operations, and cash flows.

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Segment Information

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

SEGMENT INFORMATION

SEGMENT INFORMATION

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable segments, Regulated Distribution and Regulated Transmission.

The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies, serving approximately six million customers within 65,000 square miles of Ohio, Pennsylvania, West Virginia, Maryland, New Jersey and New York, and purchases power for its POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey and Maryland. This segment also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. The segment’s results reflect the costs of securing and delivering electric generation from transmission facilities to customers, including the deferral and amortization of certain related costs.

On April 6, 2020, JCP&L signed an asset purchase agreement with Yards Creek Energy, LLC, a subsidiary of LS Power to sell its 50% interest in the Yards Creek pumped-storage hydro generation facility. With the receipt of all required regulatory approvals,

the transaction was consummated on March 5, 2021 and resulted in a $109 million gain within the regulated distribution segment in the first quarter of 2021. The gain from the transaction was applied against and reduced JCP&L’s existing regulatory asset for previously deferred storm costs and, as a result, was offset by expense in the “Amortization (deferral) of regulatory assets, net”, line on the Consolidated Statements of Income, resulting in no earnings impact to FirstEnergy or JCP&L.

The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission Companies and certain of FirstEnergy’s utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to distribution facilities. The segment’s revenues are primarily derived from forward-looking formula rates. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual rate base and costs. The segment’s results also reflect the net transmission expenses related to the delivery of electricity on FirstEnergy’s transmission facilities. On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA, with Brookfield and Brookfield Guarantors pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. CFIUS completed its review on April 14, 2022 and FERC approved the transaction on April 21, 2022. The transaction is expected to close at the end of May 2022. KATCo, which is currently a subsidiary of FET, will become a wholly owned subsidiary of FE prior to the closing of the transaction and will remain in the Regulated Transmission segment.

Corporate/Other reflects corporate support and other costs not charged or attributable to the Utilities or Transmission Companies, including FE’s retained Pension and OPEB assets and liabilities of the FES Debtors, interest expense on FE’s holding company debt and other investments or businesses that do not constitute an operating segment. Reconciling adjustments for the elimination of inter-segment transactions are shown separately in the following table of Segment Financial Information. As of March 31, 2022, 67 MWs of electric generating capacity, representing AE Supply’s OVEC capacity entitlement, is included in Corporate/Other. As of March 31, 2022, Corporate/Other had approximately $7.4 billion of FE holding company debt.

Financial information for each of FirstEnergy’s business segments and reconciliations to consolidated amounts is presented in the tables below. FirstEnergy evaluates segment performance based on Net income (loss).

Segment Financial Information

For the Three Months Ended	Regulated Distribution		Regulated Transmission		Corporate/ Other		Reconciling Adjustments		FirstEnergy Consolidated
	(In millions)
March 31, 2022
External revenues	$	2,532	$	451	$	6	$	—	$	2,989
Internal revenues	57		2		—		(59)		—
Total revenues	$	2,589	$	453	$	6	$	(59)	$	2,989
Depreciation	235		86		2		17		340
Amortization (deferral) of regulatory assets, net	(38)		1		—		—		(37)
Miscellaneous income (expense), net	85		6		17		(2)		106
Interest expense	129		59		127		(2)		313
Income taxes (benefits)	69		41		(27)		—		83
Net income (loss)	265		125		(102)		—		288
Property additions	$	317	$	197	$	6	$	—	$	520
March 31, 2021
External revenues	$	2,321	$	401	$	4	$	—	$	2,726
Internal revenues	49		4		—		(53)		—
Total revenues	$	2,370	$	405	$	4	$	(53)	$	2,726
Depreciation	226		81		1		15		323
Amortization of regulatory assets, net	87		5		—		—		92
Miscellaneous income (expense), net	107		11		22		(5)		135
Interest expense	128		61		101		(5)		285
Income taxes (benefits)	82		33		(28)		—		87
Net income (loss)	313		109		(87)		—		335
Property additions	$	321	$	273	$	10	$	—	$	604
As of March 31, 2022
Total assets	$	30,883	$	13,070	$	664	$	—	$	44,617
Total goodwill	$	5,004	$	614	$	—	$	—	$	5,618
As of December 31, 2021
Total assets	$	30,812	$	13,237	$	1,383	$	—	$	45,432
Total goodwill	$	5,004	$	614	$	—	$	—	$	5,618

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Organization and Basis of Presentation (Policies)

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Accounting

These interim financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and disclosures normally included in financial statements and notes prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. These interim financial statements should be read in conjunction with the financial statements and notes included in the Annual Report on Form 10-K for the year ended December 31, 2021.

FE and its subsidiaries follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The accompanying interim financial statements are unaudited, but reflect all adjustments, consisting of normal recurring adjustments, that, in the opinion of management, are necessary for a fair statement of the financial statements. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of operations for any future period. FE and its subsidiaries have evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued.

Consolidation

FE and its subsidiaries consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. FE and its subsidiaries consolidate a VIE when it is determined that it is the primary beneficiary. Investments in affiliates over which FE and its subsidiaries have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported as an investment in the Consolidated Balance Sheets and the percentage of FE’s ownership share of the entity’s earnings is reported in the Consolidated Statements of Income and Comprehensive Income.

Customer Receivables

Customer Receivables

Receivables from customers include distribution services and retail generation sales to residential, commercial and industrial customers of the Utilities. The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for credit losses.

FirstEnergy reviews its allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Utilities are able to utilize to ensure payment. This analysis includes consideration of the outbreak of COVID-19 and the impact on customer receivable balances outstanding and write-offs since the pandemic began. During the first quarter of 2022, various regulatory actions including extensions on moratoriums, certain restrictions on disconnections, and extended installment plan offerings continue to impact the level of past due balances in certain states. However, certain states have resumed normal collections activity and arrears levels have declined towards pre-pandemic levels. As a result of this analysis, FirstEnergy recognized a $25 million decrease to its allowance for uncollectible customer receivables during the first quarter of 2022, of which $15 million was applied to existing deferred regulatory assets. Additionally, as a result of these pandemic-related moratoriums and certain customer installment or extended payment plans offered, the allowance for uncollectible accounts on receivables in 2022 continue to be elevated due to the extension of when certain write-offs would have otherwise occurred.

Receivables from customers also include PJM receivables resulting from transmission and wholesale sales. FirstEnergy’s uncollectible risk on PJM receivables is minimal due to the nature of PJM’s settlement process whereby members of PJM legally agree to share the cost of defaults and as a result there is no allowance for doubtful accounts

New Accounting Pronouncements

New Accounting Pronouncements

Recently Issued Pronouncements - FirstEnergy has assessed new authoritative accounting guidance issued by the FASB that has not yet been adopted and none are currently expected to have a material impact to the financial statements.

Revenue

FirstEnergy accounts for revenues from contracts with customers under ASC 606, “Revenue from Contracts with Customers.” Revenue from leases, financial instruments, other contractual rights or obligations and other revenues that are not from contracts with customers are outside the scope of the standard and accounted for under other existing GAAP.

FirstEnergy has elected to exclude sales taxes and other similar taxes collected on behalf of third parties from revenue as prescribed in the standard. As a result, tax collections and remittances are excluded from recognition in the income statement and instead recorded through the balance sheet. Excise and gross receipts taxes that are assessed on FirstEnergy are not subject to the election and are included in revenue. FirstEnergy has elected the optional invoice practical expedient for most of its revenues and utilizes the optional short-term contract exemption for transmission revenues due to the annual establishment of revenue requirements, which eliminates the need to provide certain revenue disclosures regarding unsatisfied performance obligations.

FirstEnergy’s revenues are primarily derived from electric service provided by the Utilities and Transmission Companies.

Earnings Per Share

Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised.

Diluted EPS reflects the dilutive effect of potential common shares from share-based awards. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average market price for the period.

Investments

INVESTMENTS

All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash equivalents include equity securities, AFS debt securities and other investments. FirstEnergy has no debt securities held for trading purposes.

Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on AFS debt securities are recognized in AOCI. However, the spent nuclear fuel disposal trusts of JCP&L, ME and PN are subject to regulatory accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets.

Long-Term Debt and Other Long-Term Obligations

LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONSAll borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature, FirstEnergy believes that their costs approximate their fair market value.

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Organization and Basis of Presentation (Tables)

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Activity in the allowance for uncollectible accounts on customer receivables

Activity in the allowance for uncollectible accounts on customer receivables for the three months ended March 31, 2022 and for the year ended December 31, 2021 are as follows:

	(In millions)
Balance, January 1, 2021	$	164
Charged to income (1)	54
Charged to other accounts (2)	42
Write-offs	(101)
Balance, December 31, 2021	$	159
Charged to income(3)	(5)
Charged to other accounts (2)	39
Write-offs	(61)
Balance, March 31, 2022	$	132

(1) $12 million of which was deferred for future recovery in the twelve months ended December 31, 2021.

(2) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.

(3) $(11) million of which was deferred for future refund to customers in the three months ended March 31, 2022.

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Revenue (Tables)

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following represents a disaggregation of revenue from contracts with customers for the three months ended March 31, 2022 and 2021:

	For the Three Months Ended March 31, 2022
Revenues by Type of Service	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments (1)		Total
	(In millions)
Distribution services	$	1,348	$	—	$	(28)	$	1,320
Retail generation	1,094		—		(17)		1,077
Wholesale sales	90		—		6		96
Transmission	—		451		—		451
Other	26		—		—		26
Total revenues from contracts with customers	$	2,558	$	451	$	(39)	$	2,970
Other revenue unrelated to contracts with customers	31		2		(14)		19
Total revenues	$	2,589	$	453	$	(53)	$	2,989

(1) Includes eliminations and reconciling adjustments of inter-segment revenues.

	For the Three Months Ended March 31, 2021
Revenues by Type of Service	Regulated Distribution		Regulated Transmission		Corporate/Other and Reconciling Adjustments (1)		Total
	(In millions)
Distribution services	$	1,339	$	—	$	(26)	$	1,313
Retail generation	935		—		(12)		923
Wholesale sales	69		—		4		73
Transmission	—		401		—		401
Other	33		—		—		33
Total revenues from contracts with customers	$	2,376	$	401	$	(34)	$	2,743
ARP (2)	(27)		—		—		(27)
Other revenue unrelated to contracts with customers	21		4		(15)		10
Total revenues	$	2,370	$	405	$	(49)	$	2,726

(1) Includes eliminations and reconciling adjustments of inter-segment revenues.

(2) Reflects amount the Ohio Companies refunded to customers that was previously collected under decoupling mechanisms, with interest. See Note 7, “Regulatory Matters,” for further discussion on Ohio decoupling rates.

The following table represents a disaggregation of the Regulated Distribution segment revenue from contracts with distribution service and retail generation customers for the three months ended March 31, 2022 and 2021, by class:

	For the Three Months Ended March 31,
Revenues by Customer Class	2022		2021
	(In millions)
Residential	$	1,542	$	1,457
Commercial	597		541
Industrial	283		258
Other	20		18
Total Revenues	$	2,442	$	2,274

The following table represents a disaggregation of revenue from contracts with regulated transmission customers for the three months ended March 31, 2022 and 2021, by transmission owner:

	For the Three Months Ended March 31,
Transmission Owner	2022		2021
	(In millions)
ATSI	217		$	206
TrAIL	63		59
MAIT	79		67
JCP&L	60		36
MP, PE and WP	32		33
Total Revenues	$	451	$	401

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Earnings Per Share Of Common Stock (Tables)

3 Months Ended

Mar. 31, 2022

Earnings Per Share [Abstract]

Reconciliation of Basic and Diluted Earnings Per Share

The following table reconciles basic and diluted EPS of common stock:

	For the Three Months Ended March 31,
Reconciliation of Basic and Diluted EPS	2022		2021
(In millions, except per share amounts)
Net Income	$	288	$	335
Share count information:
Weighted average number of basic shares outstanding	570		543
Assumed exercise of dilutive stock options and awards	1		1
Weighted average number of diluted shares outstanding	571		544
EPS of Common Stock:
Basic EPS of common stock	$	0.51	$	0.62
Diluted EPS of common stock	$	0.50	$	0.62

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Pension and Other Post-Employment Benefits (Tables)

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Costs

The components of the consolidated net periodic costs (credits) for pension and OPEB were as follows:

Components of Net Periodic Benefit Costs (Credits)	Pension				OPEB
For the Three Months Ended March 31,	2022		2021		2022		2021
	(In millions)
Service costs	$	46	$	49	$	1	$	1
Interest costs	68		56		3		3
Expected return on plan assets	(164)		(163)		(10)		(10)
Amortization of prior service costs (credits)(1)	1		1		(3)		(4)
Net periodic credits, including amounts capitalized	$	(49)	$	(57)	$	(9)	$	(10)
Net periodic credits, recognized in earnings	$	(69)	$	(78)	$	(9)	$	(10)

(1) The income tax benefits associated with pension and OPEB prior service costs amortized out of AOCI were $1 million as of March 31, 2022 and 2021.

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Assets and Liabilities Measured on Recurring Basis

The following tables set forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy:

	March 31, 2022								December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(In millions)
Derivative assets FTRs(1)	$	—	$	—	$	1	$	1	$	—	$	—	$	9	$	9
Equity securities	2		—		—		2		2		—		—		2
U.S. state debt securities	—		258		—		258		—		273		—		273
Cash, cash equivalents and restricted cash(2)	310		—		—		310		1,511		—		—		1,511
Other(3)	—		45		—		45		—		42		—		42
Total assets	$	312	$	303	$	1	$	616	$	1,513	$	315	$	9	$	1,837
Liabilities
Derivative liabilities FTRs(1)	$	—	$	—	$	—	$	—	$	—	$	—	$	(1)	$	(1)
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	—	$	(1)	$	(1)
Net assets (liabilities)	$	312	$	303	$	1	$	616	$	1,513	$	315	$	8	$	1,836

(1)Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.

(2)Restricted cash of $27 million and $49 million as of March 31, 2022 and December 31, 2021 respectively, primarily relates to cash collected from MP, PE and the Ohio Companies’ customers that is specifically used to service debt of their respective securitization or funding companies.

(3)Primarily consists of short-term investments.

Quantitative Information for Level 3 Valuation

The following table provides quantitative information for FTRs contracts that are classified as Level 3 in the fair value hierarchy for the period ended March 31, 2022:

	Fair Value, Net (In millions)		Valuation Technique	Significant Input	Range					Weighted Average	Units
FTRs	$	1	Model	RTO auction clearing prices	$	0.20	to	$	4.00	$0.90	Dollars/MWH

Amortized Cost Basis, Unrealized Gains and Losses and Fair Values of Investments in Available-for-sale Securities

The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held in spent nuclear fuel disposal trusts as of March 31, 2022, and December 31, 2021:

	March 31, 2022(1)								December 31, 2021(2)
	Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value		Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value
	(In millions)
Debt securities	$	279	$	—	$	(21)	$	258	$	280	$	2	$	(9)	$	273

(1) Excludes short-term cash investments of $13 million.

    (2) Excludes short-term cash investments of $11 million.

Proceeds from the Sale of Investments in Available-for-sale Securities, Realized Gains and Losses on Those Sales, and Interest and Dividend Income

Proceeds from the sale of investments in AFS debt securities, realized gains and losses on those sales and interest and dividend income for the three months ended March 31, 2022 and 2021, were as follows:

	For the Three Months Ended March 31,
	2022		2021
	(In millions)
Sale proceeds	$	6	$	5
Realized gains	—		—
Realized losses	(1)		—
Interest and dividend income	3		3

Fair Value and Related Carrying Amounts of Long-term Debt and Other Long-term Obligations

The following table provides the approximate fair value and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance costs, unamortized fair value adjustments, premiums and discounts as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	(In millions)
Carrying value	$	22,900	$	23,946
Fair value	$	23,754	$	27,043

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Commitments, Guarantees and Contingencies (Tables)

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

Schedule of Guarantor Obligations

These credit-risk-related contingent features stipulate that if the subsidiary 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. The following table discloses the potential additional credit rating contingent contractual collateral obligations as of March 31, 2022:

Potential Collateral Obligations		Utilities and Transmission Companies		FE		Total
	(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade		$	43	$	—	$	43
Surety Bonds (Collateralized Amount) (1)		57		258		315
Total Exposure from Contractual Obligations		$	100	$	258	$	358

(1)Surety Bonds are not tied to a credit rating. Surety Bonds’ impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with the respect to $39 million of surety bond obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Segment Financial Information

Financial information for each of FirstEnergy’s business segments and reconciliations to consolidated amounts is presented in the tables below. FirstEnergy evaluates segment performance based on Net income (loss).

Segment Financial Information

For the Three Months Ended	Regulated Distribution		Regulated Transmission		Corporate/ Other		Reconciling Adjustments		FirstEnergy Consolidated
	(In millions)
March 31, 2022
External revenues	$	2,532	$	451	$	6	$	—	$	2,989
Internal revenues	57		2		—		(59)		—
Total revenues	$	2,589	$	453	$	6	$	(59)	$	2,989
Depreciation	235		86		2		17		340
Amortization (deferral) of regulatory assets, net	(38)		1		—		—		(37)
Miscellaneous income (expense), net	85		6		17		(2)		106
Interest expense	129		59		127		(2)		313
Income taxes (benefits)	69		41		(27)		—		83
Net income (loss)	265		125		(102)		—		288
Property additions	$	317	$	197	$	6	$	—	$	520
March 31, 2021
External revenues	$	2,321	$	401	$	4	$	—	$	2,726
Internal revenues	49		4		—		(53)		—
Total revenues	$	2,370	$	405	$	4	$	(53)	$	2,726
Depreciation	226		81		1		15		323
Amortization of regulatory assets, net	87		5		—		—		92
Miscellaneous income (expense), net	107		11		22		(5)		135
Interest expense	128		61		101		(5)		285
Income taxes (benefits)	82		33		(28)		—		87
Net income (loss)	313		109		(87)		—		335
Property additions	$	321	$	273	$	10	$	—	$	604
As of March 31, 2022
Total assets	$	30,883	$	13,070	$	664	$	—	$	44,617
Total goodwill	$	5,004	$	614	$	—	$	—	$	5,618
As of December 31, 2021
Total assets	$	30,812	$	13,237	$	1,383	$	—	$	45,432
Total goodwill	$	5,004	$	614	$	—	$	—	$	5,618

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Organization and Basis of Presentation - Narrative (Details) mi in Thousands, customer in Thousands, $ in Millions		3 Months Ended
	Apr. 14, 2022 USD ($)	Mar. 31, 2022 USD ($) customer company transmissionCenter mi MW	Mar. 31, 2021 USD ($)	Apr. 30, 2022 director
Property, Plant and Equipment [Line Items]
Length of transmission lines | mi		24
Number of regional transmission centers | transmissionCenter		2
Capitalized cost of equity		$ 13	$ 7
Capitalized interest		6	$ 6
Incremental decrease to uncollectible expense due to Covid-19		25
Deferred Regulatory Assets
Property, Plant and Equipment [Line Items]
Incremental decrease to uncollectible expense due to Covid-19		$ 15
PN | Waverly, New York
Property, Plant and Equipment [Line Items]
Number of customers served by utility operating companies | customer		4
FET | Forecast
Property, Plant and Equipment [Line Items]
Number of directors | director				5
Minimum ownership interest				9.90%
Year one through five required debt to equity percentage				65.00%
Required debt to equity ratio thereafter				70.00%
FET | North American Transmission Company II LLC | Forecast
Property, Plant and Equipment [Line Items]
Sale of ownership interest by parent	19.90%
Sale price of ownership interest by parent	$ 2,375
Number of directors | director				1
FET | FirstEnergy | Forecast
Property, Plant and Equipment [Line Items]
Number of directors | director				4
Regulated Distribution
Property, Plant and Equipment [Line Items]
Number of existing utility operating companies | company		10
Number of customers served by utility operating companies | customer		6,000
Plant capacity (in MW's) | MW		3,580

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Organization and Basis of Presentation - Activity in Uncollectable Accounts (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 159	$ 164
Charged to income	(5)	54
Charged to other accounts	39	42
Write-offs	(61)	(101)
Ending balance	132	159
Deferred for recovery	$ (11)	$ (12)

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Revenue (Details) $ in Millions		3 Months Ended
		Mar. 31, 2022 USD ($) company MW	Mar. 31, 2021 USD ($)
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		$ 2,970	$ 2,743
Total revenues	[1]	2,989	2,726
Other Non-Customer Revenue
Disaggregation of Revenue [Line Items]
Late payment charges		10	9
Distribution services
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,320	1,313
Retail generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,077	923
Wholesale sales
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		96	73
Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		451	401
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		26	33
ARP
Disaggregation of Revenue [Line Items]
Total revenues			(27)
Other non-customer revenue
Disaggregation of Revenue [Line Items]
Total revenues		19	10
Derivative revenue | Other Non-Customer Revenue
Disaggregation of Revenue [Line Items]
Total revenues		9
Regulated Distribution
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		$ 2,442	2,274
Number of existing utility operating companies | company		10
Megawatts of net demonstrated capacity of competitive segment | MW		3,580
Utility customer payment period		30 days
Regulated Distribution | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		$ 1,542	1,457
Regulated Distribution | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		597	541
Regulated Distribution | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		283	258
Regulated Distribution | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		20	18
Regulated Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		451	401
Regulated Transmission | ATSI
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		217	206
Regulated Transmission | TrAIL
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		63	59
Regulated Transmission | MAIT
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		79	67
Regulated Transmission | JCP&L
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		60	36
Regulated Transmission | MP, PE and WP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		32	33
Operating Segments | Regulated Distribution
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,558	2,376
Total revenues		2,589	2,370
Operating Segments | Regulated Distribution | Distribution services
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,348	1,339
Operating Segments | Regulated Distribution | Retail generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,094	935
Operating Segments | Regulated Distribution | Wholesale sales
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		90	69
Operating Segments | Regulated Distribution | Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Operating Segments | Regulated Distribution | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		26	33
Operating Segments | Regulated Distribution | ARP
Disaggregation of Revenue [Line Items]
Total revenues			(27)
Operating Segments | Regulated Distribution | Other non-customer revenue
Disaggregation of Revenue [Line Items]
Total revenues		31	21
Operating Segments | Regulated Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		451	401
Total revenues		453	405
Operating Segments | Regulated Transmission | Distribution services
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Operating Segments | Regulated Transmission | Retail generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Operating Segments | Regulated Transmission | Wholesale sales
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Operating Segments | Regulated Transmission | Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		451	401
Operating Segments | Regulated Transmission | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Operating Segments | Regulated Transmission | ARP
Disaggregation of Revenue [Line Items]
Total revenues			0
Operating Segments | Regulated Transmission | Other non-customer revenue
Disaggregation of Revenue [Line Items]
Total revenues		2	4
Corporate/Other and Reconciling Adjustments
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(39)	(34)
Total revenues		(53)	(49)
Corporate/Other and Reconciling Adjustments | Distribution services
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(28)	(26)
Corporate/Other and Reconciling Adjustments | Retail generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(17)	(12)
Corporate/Other and Reconciling Adjustments | Wholesale sales
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		6	4
Corporate/Other and Reconciling Adjustments | Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Corporate/Other and Reconciling Adjustments | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0
Corporate/Other and Reconciling Adjustments | ARP
Disaggregation of Revenue [Line Items]
Total revenues			0
Corporate/Other and Reconciling Adjustments | Other non-customer revenue
Disaggregation of Revenue [Line Items]
Total revenues		$ (14)	$ (15)

[1] Includes excise and gross receipts tax collections of $103 million and $95 million during the three months ended March 31, 2022 and 2021, respectively.

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Earnings Per Share Of Common Stock (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
EPS of Common Stock
Net Income	$ 288	$ 335
Share count information:
Weighted average number of basic shares outstanding (in shares)	570,000	543,000
Assumed exercise of dilutive stock options and awards (in shares)	1,000	1,000
Weighted average number of diluted shares outstanding	571,000	544,000
EPS of Common Stock:
Basic - EPS of Common Stock (in dollars per share)	$ 0.51	$ 0.62
Diluted - EPS to Common Stock (in dollars per share)	$ 0.50	$ 0.62
Stock Options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the calculation of diluted shares outstanding, in shares	0	0

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Pension and Other Post-Employment Benefits (Details) - USD ($) $ in Millions		3 Months Ended
	Mar. 11, 2021	Mar. 31, 2022	Mar. 31, 2021
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and OPEB prior service costs amortized out of AOCI		$ 1	$ 1
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service costs		46	49
Interest costs		68	56
Expected return on plan assets		(164)	(163)
Amortization of prior service costs (credits)		1	1
Net periodic credits, including amounts capitalized		(49)	(57)
Net periodic credits, recognized in earnings		(69)	(78)
Estimated return	7.50%
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service costs		1	1
Interest costs		3	3
Expected return on plan assets		(10)	(10)
Amortization of prior service costs (credits)		(3)	(4)
Net periodic credits, including amounts capitalized		(9)	(10)
Net periodic credits, recognized in earnings		$ (9)	$ (10)

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Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Income Tax Disclosure [Abstract]
Effective tax rate (percent)	22.40%	20.60%
Unrecognized tax benefits period decrease	$ 31
Unrecognized tax benefits that would impact effective tax rate	$ 24

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Fair Value Measurements - Recurring Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Liabilities
Restricted cash	$ 27	$ 49
Recurring
Assets
Fair value, assets	616	1,837
Liabilities
Fair value, liabilities	0	(1)
Net assets (liabilities)	616	1,836
Recurring | FTRs | Derivative Liabilities
Liabilities
Fair value, liabilities	0	(1)
Recurring | FTRs | Derivative Assets
Assets
Fair value, assets	1	9
Recurring | Equity securities
Assets
Fair value, assets	2	2
Recurring | U.S. state debt securities
Assets
Fair value, assets	258	273
Recurring | Cash, cash equivalents and restricted cash
Assets
Fair value, assets	310	1,511
Recurring | Other
Assets
Fair value, assets	45	42
Recurring | Level 1
Assets
Fair value, assets	312	1,513
Liabilities
Fair value, liabilities	0	0
Net assets (liabilities)	312	1,513
Recurring | Level 1 | FTRs | Derivative Liabilities
Liabilities
Fair value, liabilities	0	0
Recurring | Level 1 | FTRs | Derivative Assets
Assets
Fair value, assets	0	0
Recurring | Level 1 | Equity securities
Assets
Fair value, assets	2	2
Recurring | Level 1 | U.S. state debt securities
Assets
Fair value, assets	0	0
Recurring | Level 1 | Cash, cash equivalents and restricted cash
Assets
Fair value, assets	310	1,511
Recurring | Level 1 | Other
Assets
Fair value, assets	0	0
Recurring | Level 2
Assets
Fair value, assets	303	315
Liabilities
Fair value, liabilities	0	0
Net assets (liabilities)	303	315
Recurring | Level 2 | FTRs | Derivative Liabilities
Liabilities
Fair value, liabilities	0	0
Recurring | Level 2 | FTRs | Derivative Assets
Assets
Fair value, assets	0	0
Recurring | Level 2 | Equity securities
Assets
Fair value, assets	0	0
Recurring | Level 2 | U.S. state debt securities
Assets
Fair value, assets	258	273
Recurring | Level 2 | Cash, cash equivalents and restricted cash
Assets
Fair value, assets	0	0
Recurring | Level 2 | Other
Assets
Fair value, assets	45	42
Recurring | Level 3
Assets
Fair value, assets	1	9
Liabilities
Fair value, liabilities	0	(1)
Net assets (liabilities)	1	8
Recurring | Level 3 | FTRs | Derivative Liabilities
Liabilities
Fair value, liabilities	0	(1)
Recurring | Level 3 | FTRs | Derivative Assets
Assets
Fair value, assets	1	9
Recurring | Level 3 | Equity securities
Assets
Fair value, assets	0	0
Recurring | Level 3 | U.S. state debt securities
Assets
Fair value, assets	0	0
Recurring | Level 3 | Cash, cash equivalents and restricted cash
Assets
Fair value, assets	0	0
Recurring | Level 3 | Other
Assets
Fair value, assets	$ 0	$ 0

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Fair Value Measurements - Level 3 Quantitative Information (Details) - Model - Level 3 - FTRs $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($) $ / MWh
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value | $	$ 1
Minimum
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, RTO Auction Clearing Prices (in $/MWH)	0.20
Maximum
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, RTO Auction Clearing Prices (in $/MWH)	4.00
Weighted Average
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, RTO Auction Clearing Prices (in $/MWH)	0.90

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Fair Value Measurements - Investments Held in Trusts (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Short-term cash investments	$ 13	$ 11
Debt securities
Debt Securities, Available-for-sale [Line Items]
Cost Basis	279	280
Unrealized Gains	0	2
Unrealized Losses	(21)	(9)
Fair Value	$ 258	$ 273

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Fair Value Measurements - Proceeds from the Sale of Investments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Proceeds from the sale of investments in available-for-sale securities, realized gains and losses on those sales, and interest and dividend income
Sale proceeds	$ 6	$ 5
Realized gains	0	0
Realized losses	(1)	0
Interest and dividend income	$ 3	$ 3

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Fair Value Measurements - Carrying Amounts of Long-term Debt (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Carrying Value
Fair value and related carrying amounts of long-term debt and other long-term obligations
Long-term debt and other long-term obligations	$ 22,900	$ 23,946
Fair Value
Fair value and related carrying amounts of long-term debt and other long-term obligations
Long-term debt and other long-term obligations	$ 23,754	$ 27,043

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Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	Jan. 27, 2022	Mar. 31, 2022	Dec. 31, 2021
Fair Value of Financial Instruments [Line Items]
Investments not required to be disclosed		$ 375	$ 371
4.25% Series B Senior Notes Due 2023 | Senior Notes
Fair Value of Financial Instruments [Line Items]
Face amount of debt			$ 850
Stated interest rate			4.25%
Debt Instrument, Unamortized Premium			$ 38
2.77% Series A Senior Notes Due 2034 | Senior Notes | The Cleveland Electric Illuminating Company
Fair Value of Financial Instruments [Line Items]
Face amount of debt	$ 150
Stated interest rate	2.77%
2.65%, 150 Million Notes Maturing 2028 | Senior Notes | TE
Fair Value of Financial Instruments [Line Items]
Stated interest rate	2.65%
Early repayment of debt	$ 25

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Regulatory Matters - Maryland and New Jersey (Details) meter in Millions, $ in Millions							3 Months Ended
	Nov. 01, 2021	Sep. 14, 2021 USD ($)	Apr. 23, 2021 USD ($)	Mar. 01, 2021 USD ($) program	Oct. 28, 2020 USD ($)	Aug. 27, 2020 USD ($) meter	Mar. 31, 2022 USD ($)
PE | Maryland
Regulatory Matters [Line Items]
Incremental energy savings goal per year (percent)							0.20%
Incremental energy savings goal thereafter (percent)							2.00%
Amortization period							5 years
Amount of requested rate increase (decrease)							$ 148
Recovery period for expenditures for cost recovery program							3 years
JCP&L | Advanced Metering Infrastructure | New Jersey | Regulated Distribution
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)						$ 732
JCP&L | Advanced Metering Infrastructure Supplemental Filing | New Jersey | Regulated Distribution
Regulatory Matters [Line Items]
First period of the program		6 years
Costs associated with program		$ 494
Amount of capital expenditures		390
Amount of maintenance expense		73
Cost of removal		$ 31
JCP&L | NJBPU | New Jersey
Regulatory Matters [Line Items]
Requested increase to ROE	9.60%
Amount of revenue increase					$ 94
JCP&L | NJBPU | Advanced Metering Infrastructure | New Jersey | Regulated Distribution
Regulatory Matters [Line Items]
Meter deployment period						3 years
Number of meters to be deployed | meter						1.2
Expected cost of the program						$ 418
Time period of the program						20 years
JCP&L | NJBPU | Energy Efficiency and Peak Demand Reduction | New Jersey | Regulated Distribution
Regulatory Matters [Line Items]
Amortization period			10 years
JCP&L | NJBPU | Electrical Vehicle Program | New Jersey | Regulated Distribution
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)				$ 50
Number of programs | program				6
Electric vehicle program period				4 years
Amount of requested return on capital				$ 16
Requested amount for operations and maintenance expense				$ 34
JCP&L | NJBPU | Energy Efficiency and Peak Demand Reduction Stipulation Settlement | New Jersey | Regulated Distribution
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)			$ 203
Approved period of rate plan			3 years
Approved investment recovery			$ 158
Approved amount of operation and maintenance recovery			$ 45

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Regulatory Matters - Ohio (Details) - OHIO - PUCO $ in Thousands			3 Months Ended
	Nov. 01, 2021 USD ($)	Jun. 01, 2016 USD ($)	Mar. 31, 2022 USD ($)	Sep. 13, 2021 requirement	Aug. 06, 2021 USD ($)
Regulatory Matters [Line Items]
Proposed goal to reduce CO2 pollution (percent)		90.00%
Energy Conservation, Economic Development and Job Retention
Regulatory Matters [Line Items]
Contribution amount		$ 51,000
Delivery Capital Recovery Rider
Regulatory Matters [Line Items]
Annual revenue cap for rider for years three through six		20,000
Annual revenue cap for rider for years six through eight		$ 15,000
Rider DCR Audit Report | The Ohio Companies
Regulatory Matters [Line Items]
Refund to customer of pole attachment sates					$ 15
Number of requirements with minor non-compliance | requirement				8
Number of requirements | requirement				23
SEET 2017-2019 Cases | The Ohio Companies
Regulatory Matters [Line Items]
Rate refunds	$ 96,000
Ohio Stipulation
Regulatory Matters [Line Items]
Rate refunds	210,000
Rate refunds in 2022	80,000
Rate refunds in 2023	60,000
Rate refunds in 2024	45,000
Rate refunds in 2025	$ 25,000
Ohio Stipulation | Regulated Distribution
Regulatory Matters [Line Items]
Pre-tax charges			$ 96,000

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Regulatory Matters - Pennsylvania and West Virginia (Details) $ in Millions											3 Months Ended
	Mar. 17, 2022 USD ($)	Mar. 02, 2022 USD ($)	Dec. 29, 2021 USD ($)	Dec. 27, 2021 USD ($)	Dec. 17, 2021 USD ($)	Nov. 22, 2021 MW	Nov. 18, 2021 USD ($)	Aug. 27, 2021 USD ($)	Dec. 30, 2020 USD ($)	Jan. 16, 2020 USD ($)	Mar. 31, 2022 USD ($) proposal	Sep. 30, 2021 USD ($)	Jun. 18, 2020
FERC | Transmission Related Vegetation Management Programs | Other Nonoperating Income (Expense) | FirstEnergy
Regulatory Matters [Line Items]
Pre-tax impairment of regulatory asset												$ 21.0
ATSI | FERC | Transmission Related Vegetation Management Programs | Regulated Transmission
Regulatory Matters [Line Items]
Pre-tax impairment of regulatory asset												48.0
ATSI | FERC | Transmission Related Vegetation Management Programs | Regulated Distribution
Regulatory Matters [Line Items]
Pre-tax impairment of regulatory asset												$ 27.0
Pennsylvania | DSP June 2019- May 2023
Regulatory Matters [Line Items]
Number of RFP's | proposal											2
RFP term											2 years
Pennsylvania | Three month period | DSP June 2019- May 2023
Regulatory Matters [Line Items]
Term of energy contract											3 months
Pennsylvania | Twelve month period | DSP June 2019- May 2023
Regulatory Matters [Line Items]
Term of energy contract											12 months
Pennsylvania | Twenty-four month period | DSP June 2019- May 2023
Regulatory Matters [Line Items]
Term of energy contract											24 months
Pennsylvania | PPUC
Regulatory Matters [Line Items]
Amended amount of rate increase							$ 61.0
Pennsylvania | PPUC | Regulated Distribution
Regulatory Matters [Line Items]
Pre-tax charges											$ 61.0
Pennsylvania | Pennsylvania Companies | PPUC | New LTIIPs
Regulatory Matters [Line Items]
Recovery period										5 years
Amount of requested rate increase (decrease)										$ 572.0
Pennsylvania | ME | PPUC | EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets													2.90%
Energy consumption reduction targets													3.10%
Pennsylvania | PN | PPUC | EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets													3.30%
Energy consumption reduction targets													3.00%
Pennsylvania | Penn | PPUC | EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets													2.00%
Energy consumption reduction targets													2.70%
Pennsylvania | WP | PPUC | EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets													2.50%
Energy consumption reduction targets													2.40%
West Virginia | MP and PE | WVPSC
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)		$ 94.0
West Virginia | MP and PE | WVPSC | Ft. Martin and Harrison Power Stations
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)					$ 142.0
Requested annual rate increase					$ 3.0
West Virginia | MP and PE | WVPSC | Solar Generation Project
Regulatory Matters [Line Items]
Plant capacity (in MW's) | MW						50
Expected cost of the program	$ 110.0
West Virginia | MP and PE | WVPSC | ENEC
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)								$ 19.6	$ (2.6)
Approved amount of annual increase									$ (7.7)
Amount of requested rate increase (decrease) (percent)								1.50%
Supplemental requested decrease								$ (7.7)
Expected cost of the program			$ 2.9
West Virginia | MP and PE | WVPSC | Integrated Resource Plan
Regulatory Matters [Line Items]
Approved amount of annual increase			$ 19.6
West Virginia | MP and PE | WVPSC | VMS
Regulatory Matters [Line Items]
Approved amount of annual increase				$ 16.0
Surcharge period				2 years

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Commitments, Guarantees and Contingencies - Potential Collateral Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Guarantor Obligations [Line Items]
Guarantor obligations	$ 358
Percent of face amount of debt	100.00%
Curing period	30 days
Upon Further Downgrade
Guarantor Obligations [Line Items]
Guarantor obligations	$ 43
Surety Bond (Collateralized Amount)
Guarantor Obligations [Line Items]
Guarantor obligations	$ 315
Percent of face amount of debt	60.00%
Capped portion of surety bond obligations	$ 39
Utilities and Transmission Companies
Guarantor Obligations [Line Items]
Guarantor obligations	100
Utilities and Transmission Companies | Upon Further Downgrade
Guarantor Obligations [Line Items]
Guarantor obligations	43
Utilities and Transmission Companies | Surety Bond (Collateralized Amount)
Guarantor Obligations [Line Items]
Guarantor obligations	57
FirstEnergy
Guarantor Obligations [Line Items]
Guarantor obligations	258
FirstEnergy | Upon Further Downgrade
Guarantor Obligations [Line Items]
Guarantor obligations	0
FirstEnergy | Surety Bond (Collateralized Amount)
Guarantor Obligations [Line Items]
Guarantor obligations	$ 258

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Commitments, Guarantees and Contingencies - Narrative (Details) $ in Thousands	Feb. 09, 2022 USD ($)	Jul. 21, 2021 USD ($)	Feb. 20, 2018 USD ($)	Mar. 31, 2022 USD ($)	Mar. 11, 2022 director	Dec. 31, 2021 USD ($)
Guarantor Obligations [Line Items]
Outstanding guarantees and other assurances aggregated				$ 1,100,000
Company posted collateral related to net liability positions				$ 52,000
Goal to reduce in GHG emissions				30.00%
United States v. Householder, et al.
Guarantor Obligations [Line Items]
Number of board members not seeking re-election | director					6
Number of board members on special committee | director					3
Smith v FirstEnergy Corp et al., Buldas v FirstEnergy Corp. et al., and Hudock and Cameo Countertops, Inc. v. FirstEnergy Corp. et al.
Guarantor Obligations [Line Items]
Loss contingency accrual						$ 37,500
Emmons v. FirstEnergy Corp. et al.
Guarantor Obligations [Line Items]
Loss contingency accrual						$ 37,500
Shareholder Derivative Lawsuit
Guarantor Obligations [Line Items]
Amount awarded from other party	$ 180,000
Regulation of Waste Disposal
Guarantor Obligations [Line Items]
Accrual for environmental loss contingencies				$ 110,000
Environmental liabilities former gas facilities				70,000
FE
Guarantor Obligations [Line Items]
Outstanding guarantees and other assurances aggregated				602,000
Other Assurances
Guarantor Obligations [Line Items]
Outstanding guarantees and other assurances aggregated				$ 468,000
EPA | Clean Water Act
Guarantor Obligations [Line Items]
Amount awarded to other party			$ 610
U.S. Attorney's Office | United States v. Householder, et al.
Guarantor Obligations [Line Items]
Term of payments		60 days
Term of DPA		3 years
Loss in period		$ 230,000
United States Treasury | United States v. Householder, et al.
Guarantor Obligations [Line Items]
Amount awarded to other party		115,000
Ohio Development Service | United States v. Householder, et al.
Guarantor Obligations [Line Items]
Amount awarded to other party		$ 115,000

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Segment Information - Narrative (Details) mi² in Thousands, customer in Millions, $ in Millions				3 Months Ended
	Apr. 14, 2022 USD ($)	Mar. 05, 2021 USD ($)	Apr. 06, 2020	Mar. 31, 2022 USD ($) mi² customer company MW	Mar. 31, 2021 USD ($)
Segment Reporting Information [Line Items]
Gain on sale of Yards Creek (Note 9)				$ 0	$ 109
FET | North American Transmission Company II LLC | Forecast
Segment Reporting Information [Line Items]
Sale of ownership interest by parent	19.90%
Sale price of ownership interest by parent	$ 2,375
JCP&L | Yard's Creek Energy | NEW JERSEY | NJBPU
Segment Reporting Information [Line Items]
Ownership interest sold			50.00%
Regulated Distribution
Segment Reporting Information [Line Items]
Number of existing utility operating companies | company				10
Number of customers served by utility operating companies | customer				6
Number of square miles in service area | mi²				65
Megawatts of net demonstrated capacity of competitive segment | MW				3,580
Regulated Distribution | JCP&L | Yard's Creek Energy | NEW JERSEY
Segment Reporting Information [Line Items]
Gain on sale of Yards Creek (Note 9)		$ 109
Other/Corporate | OVEC
Segment Reporting Information [Line Items]
Megawatts of net demonstrated capacity of competitive segment | MW				67
FirstEnergy | Other/Corporate
Segment Reporting Information [Line Items]
Long-term debt and other long-term obligations				$ 7,400

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Segment Information - Financial Data (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Segment Financial Information
Revenues	[1]	$ 2,989	$ 2,726
Depreciation		340	323
Amortization (deferral) of regulatory assets, net		(37)	92
Miscellaneous income (expense), net		106	135
Interest expense		313	285
Income taxes (benefits)		83	87
Income (loss) from continuing operations		288	335
Property additions		520	604
Total assets		44,617		$ 45,432
Goodwill		5,618		5,618
External Customers
Segment Financial Information
Revenues		2,989	2,726
Internal Customers
Segment Financial Information
Revenues		0	0
Operating Segments | Regulated Distribution
Segment Financial Information
Revenues		2,589	2,370
Depreciation		235	226
Amortization (deferral) of regulatory assets, net		(38)	87
Miscellaneous income (expense), net		85	107
Interest expense		129	128
Income taxes (benefits)		69	82
Income (loss) from continuing operations		265	313
Property additions		317	321
Total assets		30,883		30,812
Goodwill		5,004		5,004
Operating Segments | Regulated Distribution | External Customers
Segment Financial Information
Revenues		2,532	2,321
Operating Segments | Regulated Distribution | Internal Customers
Segment Financial Information
Revenues		57	49
Operating Segments | Regulated Transmission
Segment Financial Information
Revenues		453	405
Depreciation		86	81
Amortization (deferral) of regulatory assets, net		1	5
Miscellaneous income (expense), net		6	11
Interest expense		59	61
Income taxes (benefits)		41	33
Income (loss) from continuing operations		125	109
Property additions		197	273
Total assets		13,070		13,237
Goodwill		614		614
Operating Segments | Regulated Transmission | External Customers
Segment Financial Information
Revenues		451	401
Operating Segments | Regulated Transmission | Internal Customers
Segment Financial Information
Revenues		2	4
Corporate/Other
Segment Financial Information
Revenues		6	4
Depreciation		2	1
Amortization (deferral) of regulatory assets, net		0	0
Miscellaneous income (expense), net		17	22
Interest expense		127	101
Income taxes (benefits)		(27)	(28)
Income (loss) from continuing operations		(102)	(87)
Property additions		6	10
Total assets		664		1,383
Goodwill		0		0
Corporate/Other | External Customers
Segment Financial Information
Revenues		6	4
Corporate/Other | Internal Customers
Segment Financial Information
Revenues		0	0
Reconciling Adjustments
Segment Financial Information
Revenues		(59)	(53)
Depreciation		17	15
Amortization (deferral) of regulatory assets, net		0	0
Miscellaneous income (expense), net		(2)	(5)
Interest expense		(2)	(5)
Income taxes (benefits)		0	0
Income (loss) from continuing operations		0	0
Property additions		0	0
Total assets		0		0
Goodwill		0		$ 0
Reconciling Adjustments | External Customers
Segment Financial Information
Revenues		0	0
Reconciling Adjustments | Internal Customers
Segment Financial Information
Revenues		$ (59)	$ (53)

[1] Includes excise and gross receipts tax collections of $103 million and $95 million during the three months ended March 31, 2022 and 2021, respectively.