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Cover and table of contents

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 June 30, 2023

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

For the transition period from ___________________ to ___________________

FE Logo.jpg


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 standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the 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 June 30, 2023
Common Stock, $0.10 par value						573,362,380

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 dismissal of the derivative shareholder lawsuits.
Changes in national and regional economic conditions, including recession, inflationary pressure, supply chain disruptions, higher energy costs, and workforce impacts, affecting us and/or our customers and those vendors with which we do business.
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 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.
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, executing on our rate filing strategy, controlling costs, GHG reduction goals, improving our credit metrics, growing earnings, strengthening our balance sheet, and satisfying the conditions necessary to close the FET Minority Equity Interest Sale.
Changing market conditions affecting the measurement of certain liabilities and the value of assets held in our pension trusts may negatively impact our forecasted growth rate, results of operations, and may also cause us to make contributions to our pension sooner or in amounts that are larger than currently anticipated.
Mitigating exposure for remedial activities associated with retired and formerly owned electric generation assets.
Changes to environmental laws and regulations, including, but not limited to, those related to climate change.
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.
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.
Future actions 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.
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.
Human capital management challenges, including among other things, attracting and retaining appropriately trained and qualified employees and labor disruptions by our unionized workforce.
Changes to significant accounting policies.
Any changes in tax laws or regulations, including, but not limited to, the IRA of 2022, 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.

Forward-looking and other statements in this Quarterly Report on Form 10-Q regarding our Climate Strategy, including our GHG emission reduction goals, are not an indication that these statements are necessarily material to investors or required to be disclosed in our filings with the SEC. In addition, historical, current and forward-looking statements regarding climate matters,

including GHG emissions, may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve and assumptions that are subject to change in the future.

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 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			34

Item 3. Quantitative and Qualitative Disclosures About Market Risk			78

Item 4. Controls and Procedures			78

Part II. Other Information

Item 1. Legal Proceedings			78

Item 1A. Risk Factors			78

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			78

Item 3. Defaults Upon Senior Securities			78

Item 4. Mine Safety Disclosures			78

Item 5. Other Information			78

Item 6. Exhibits			79

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
FE PA			FirstEnergy Pennsylvania Electric Company
FESC			FirstEnergy Service Company, which provides legal, financial, and other corporate support services
FET			FirstEnergy Transmission, LLC, the parent company of ATSI, MAIT and TrAIL, and has a joint venture in PATH
FEV			FirstEnergy Ventures Corp., which invests in certain unregulated enterprises and business ventures
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
JCP&L			Jersey Central Power & Light Company, a New Jersey electric utility operating subsidiary
KATCo			Keystone Appalachian Transmission Company, a former subsidiary of FET which, in May 2022, became a subsidiary of FE
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
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 FET 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


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
2023 Amendments			Collectively, the six separate amendments to the 2021 Credit Facilities entered into by FE, FET, the Utilities and the Transmission Companies, on April 27, 2023
2026 Convertible Notes			FE’s 4.00% convertible senior notes, due 2026
2031 Notes			FE’s 7.375% Notes, Series C, due 2031
ACE			Affordable Clean Energy
AEP			American Electric Power Company, Inc.
AEPSC			American Electric Power Service Corporation
AFS			Available-for-sale
AFSI			Adjusted Financial Statement Income
AFUDC			Allowance for Funds Used During Construction
AMI			Advance Metering Infrastructure
AMT			Alternative Minimum Tax
AOCI			Accumulated Other Comprehensive Income (Loss)
ASC			Accounting Standards Codification
ASU			Accounting Standards Update
A&R FET LLC Agreement			Fourth Amended and Restated Limited Liability Company Operating Agreement of FET
BGS			Basic Generation Service
Brookfield			North American Transmission Company II L.P., a controlled investment vehicle entity of Brookfield Infrastructure Partners
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
CAA			Clean Air Act
CCR			Coal Combustion Residual
CERCLA			Comprehensive Environmental Response, Compensation, and Liability Act of 1980
CFIUS			Committee on Foreign Investments in the United States
CFR			Code of Federal Regulations
CO2			Carbon Dioxide
COVID-19			Coronavirus disease
CPP			EPA's Clean Power Plan
CSAPR			Cross-State Air Pollution Rule
CTA			Consolidated Tax Adjustment
D.C. Circuit			United States Court of Appeals for the District of Columbia Circuit
DCR			Delivery Capital Recovery
DMR			Distribution Modernization Rider
DPA			Deferred Prosecution Agreement entered into on July 21, 2021 between FE and the U.S. Attorney’s Office for the S.D. Ohio
DSIC			Distribution System Improvement Charge
DSP			Default Service Plan
EDC			Electric Distribution Company
EESG			Employee, Environmental, Social, and Corporate Governance
EGS			Electric Generation Supplier
EGU			Electric Generation Unit
EH			Energy Harbor Corp.
ELG			Effluent Limitation Guideline
EmPOWER Maryland			EmPOWER Maryland Energy Efficiency Act
ENEC			Expanded Net Energy Cost
EPA			United States Environmental Protection Agency

iii


EPS			Earnings Per Share
ESP IV			Electric Security Plan IV
ESP V			Electric Security Plan V
Exchange Act			Securities and Exchange Act of 1934, as amended
Facebook®			Facebook is a registered trademark of Facebook, Inc.
FASB			Financial Accounting Standards Board
FE Board			FE Board of Directors
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
FERC			Federal Energy Regulatory Committee
FET Board			The Board of Directors of FET
FET LLC Agreement			Third Amended and Restated Limited Liability Company Operating Agreement of FET
FET Minority Equity Interest Sale			Sale of an additional 30% membership interest of FET, such that Brookfield will own 49.9% of FET
FET P&SA I			Purchase and Sale Agreement entered into on November 6, 2021, by and between FE, FET, Brookfield and the Brookfield Guarantors
FET P&SA II			Purchase and Sale Agreement entered into on February 2, 2023, by and between FE, FET, Brookfield, and the Brookfield Guarantors
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
FIP			Federal Implementation Plan(s) under the CAA
Fitch			Fitch Ratings Service
FMB			First Mortgage Bond
FTR			Financial Transmission Right
GAAP			Accounting Principles Generally Accepted in the United States of America
GHG			Greenhouse Gas
HB 6			House Bill 6, as passed by Ohio's 133rd General Assembly
IRA of 2022			Inflation Reduction Act of 2022
IRS			Internal Revenue Service
kWh			Kilowatt-Hour
LIBOR			London Inter-Bank Offered Rate
LOC			Letter of Credit
LTIIP			Long-Term Infrastructure Improvement Plan
MDPSC			Maryland Public Service Commission
MGP			Manufactured Gas Plants
Moody’s			Moody’s Investors Service, Inc.
MW			Megawatt
MWH			Megawatt-hour
NCI			Noncontrolling Interest
N.D. Ohio			Federal District Court, Northern District of Ohio
NERC			North American Electric Reliability Corporation
NJBPU			New Jersey Board of Public Utilities
NOL			Net Operating Loss
NOx			Nitrogen Oxide
NYPSC			New York State Public Service Commission
OAG			Ohio Attorney General
OCC			Ohio Consumers' Counsel
ODSA			Ohio Development Service Agency
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
OOCIC			Ohio Organized Crime Investigations Commission, which is composed of members of the Ohio law enforcement community and is chaired by the OAG
OPEB			Other Post-Employment Benefits


OPIC			Other Paid-in Capital
OVEC			Ohio Valley Electric Corporation
PA Consolidation			Consolidation of the Pennsylvania Companies
PEER			FirstEnergy’s Program for Enhanced Employee Retirement
PJM			PJM Interconnection, LLC
PJM Tariff			PJM Open Access Transmission Tariff
PPA			Purchase Power Agreement
PPUC			Pennsylvania Public Utility Commission
PUCO			Public Utilities Commission of Ohio
Regulation FD			Regulation Fair Disclosure promulgated by the SEC
RFC			ReliabilityFirst Corporation
RFP			Request for Proposal
ROE			Return on Equity
RTO			Regional Transmission Organization
S.D. Ohio			Federal District Court, Southern District of Ohio
SEC			United States Securities and Exchange Commission
SEET			Significantly Excessive Earnings Test
SIP			State Implementation Plan(s) under the CAA
SLC			Special Litigation Committee of the FE Board
SO2			Sulfur Dioxide
SOFR			Secured Overnight Financing Rate
SOS			Standard Offer Service
S&P			Standard & Poor’s Ratings Service
SREC			Solar Renewable Energy Credit
Tax Act			Tax Cuts and Jobs Act adopted December 22, 2017
TMI-1			Three Mile Island Unit 1
Twitter®			Twitter is a registered trademark of Twitter, Inc.
VAR			Volt-Amps Reactive, the measuring unit for reactive power
VSCC			Virginia State Corporation Commission
WVPSC			Public Service Commission of West Virginia

PART I. FINANCIAL INFORMATION

ITEM I. Financial Statements

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
(In millions, except per share amounts)	2023		2022		2023		2022

REVENUES:
Distribution services and retail generation	$	2,375	$	2,170	$	5,055	$	4,567
Transmission	518		440		978		891
Other	113		208		204		349
Total revenues (1)	3,006		2,818		6,237		5,807

OPERATING EXPENSES:
Fuel	140		190		273		330
Purchased power	894		802		2,018		1,677
Other operating expenses	885		896		1,731		1,716

Provision for depreciation	361		348		722		688

Deferral of regulatory assets, net	(33)		(129)		(113)		(166)
General taxes	278		264		574		556



Total operating expenses	2,525		2,371		5,205		4,801

OPERATING INCOME	481		447		1,032		1,006

OTHER INCOME (EXPENSE):
Debt redemption costs (Note 6)	(36)		(118)		(36)		(156)
Equity method investment earnings (Note 1)	35		65		91		77
Miscellaneous income, net	43		95		78		189

Pension and OPEB mark-to-market adjustment (Note 4)	59		—		59		—
Interest expense	(276)		(265)		(539)		(540)
Capitalized financing costs	22		17		43		36
Total other expense	(153)		(206)		(304)		(394)

INCOME BEFORE INCOME TAXES	328		241		728		612

INCOME TAXES	74		49		164		132





NET INCOME	$	254	$	192	$	564	$	480

Income attributable to noncontrolling interest	19		5		37		5

EARNINGS ATTRIBUTABLE TO FIRSTENERGY CORP.	$	235	$	187	$	527	$	475





EARNINGS PER SHARE ATTRIBUTABLE TO FIRSTENERGY CORP. (Note 3):


Basic	$	0.41	$	0.33	$	0.92	$	0.83



Diluted	$	0.41	$	0.33	$	0.92	$	0.83

WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic	573		571		573		571
Diluted	574		572		574		572

(1) Includes excise and gross receipts tax collections of $92 million and $91 million during the three months ended June 30, 2023 and 2022, respectively, and $201 million and $194 million during the six months ended June 30, 2023 and 2022, respectively.

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

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
(In millions)	2023		2022		2023		2022

NET INCOME	$	254	$	192	$	564	$	480

OTHER COMPREHENSIVE INCOME (LOSS):
Pension and OPEB prior service costs	(1)		(2)		(3)		(4)
Amortized losses on derivative hedges	2		8		2		8


Other comprehensive income (loss)	1		6		(1)		4
Income taxes on other comprehensive income (loss)	1		2		—		1
Other comprehensive income (loss), net of tax	—		4		(1)		3

COMPREHENSIVE INCOME	$	254	$	196	$	563	$	483

Comprehensive income attributable to noncontrolling interest	19		5		37		5

COMPREHENSIVE INCOME ATTRIBUTABLE TO FIRSTENERGY CORP.	$	235	$	191	$	526	$	478

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

FIRSTENERGY CORP.

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions, except share amounts)	June 30, 2023		December 31, 2022
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	171	$	160
Restricted cash	43		46
Receivables-
Customers	1,271		1,455
Less — Allowance for uncollectible customer receivables	85		137
	1,186		1,318

Other, net of allowance for uncollectible accounts of $15 in 2023 and $11 in 2022	275		253
Materials and supplies, at average cost	449		421




Prepaid taxes and other	361		217

	2,485		2,415
PROPERTY, PLANT AND EQUIPMENT:
In service	48,963		47,850
Less — Accumulated provision for depreciation	13,671		13,258
	35,292		34,592
Construction work in progress	1,857		1,693
	37,149		36,285



INVESTMENTS AND OTHER NONCURRENT ASSETS:
Goodwill	5,618		5,618
Investments (Note 6)	638		622
Regulatory assets	311		33
Other	864		1,135

	7,431		7,408
TOTAL ASSETS	$	47,065	$	46,108

LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently payable long-term debt	$	1,002	$	351
Short-term borrowings	350		100
Accounts payable	1,200		1,503

Accrued interest	283		254
Accrued taxes	604		668
Accrued compensation and benefits	257		272

Customer deposits	223		223
Dividends payable	—		223
Other	230		364

	4,149		3,958
NONCURRENT LIABILITIES:
Long-term debt and other long-term obligations	22,656		21,203
Accumulated deferred income taxes	4,392		4,202
Retirement benefits	1,516		2,335
Regulatory liabilities	1,519		1,847



Other	1,862		1,920

	31,945		31,507
TOTAL LIABILITIES	36,094		35,465

EQUITY:
Common stockholders’ equity-
Common stock, $0.10 par value, authorized 700,000,000 shares - 573,362,380 and 572,130,932 shares outstanding as of June 30, 2023 and December 31, 2022, respectively.	57		57

Other paid-in capital	11,140		11,322
Accumulated other comprehensive loss	(15)		(14)
Accumulated deficit	(672)		(1,199)
Total common stockholders’ equity	10,510		10,166
Noncontrolling interest	461		477

TOTAL EQUITY	10,971		10,643

COMMITMENTS, GUARANTEES AND CONTINGENCIES (Note 8)

TOTAL LIABILITIES AND EQUITY	$	47,065	$	46,108

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

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)


	Six Months Ended June 30, 2023
	Common Stock			OPIC		AOCI		Accumulated Deficit		Total Common Stockholders’ Equity		NCI		Total Equity
(In millions)	Shares	Amount
Balance, January 1, 2023	572	$	57	$	11,322	$	(14)	$	(1,199)	$	10,166	$	477	$	10,643
Net income	—	—		—		—		292		292		18		310
Other comprehensive loss, net of tax	—	—		—		(1)		—		(1)		—		(1)
Stock Investment Plan and share-based benefit plans	1	—		19		—		—		19		—		19
Cash dividends declared on common stock ($0.39 per share in March)	—	—		(223)		—		—		(223)		—		(223)
Distribution to FET minority interest	—	—		—		—		—		—		(17)		(17)
Balance, March 31, 2023	573	57		11,118		(15)		(907)		10,253		478		10,731
Net income	—	—		—		—		235		235		19		254

Stock Investment Plan and share-based benefit plans	—	—		22		—		—		22		—		22
Distribution to FET minority interest	—	—		—		—		—		—		(36)		(36)
Balance, June 30, 2023	573	$	57	$	11,140	$	(15)	$	(672)	$	10,510	$	461	$	10,971


	Six Months Ended June 30, 2022
	Common Stock			OPIC		AOCI			Accumulated Deficit		Total Common Stockholders’ Equity		NCI		Total Equity
(In millions)	Shares	Amount
Balance, January 1, 2022	570	$	57	$	10,238	$	(15)	0	$	(1,605)	$	8,675	$	—	$	8,675
Net income	—	—		—		—			288		288		—		288
Other comprehensive loss, net of tax	—	—		—		(1)			—		(1)		—		(1)
Stock Investment Plan and share-based benefit plans	1	—		20		—			—		20		—		20
Cash dividends declared on common stock ($0.39 per share in March)	—	—		(223)		—			—		(223)		—		(223)
Other	—	—		(4)		—			—		(4)		—		(4)
Balance, March 31, 2022	571	57		10,031		(16)			(1,317)		8,755		—		8,755
Net income	—	—		—		—			187		187		5		192
Other comprehensive income, net of tax	—	—		—		4			—		4		—		4
Stock Investment Plan and share-based benefit plans	—	—		25		—			—		25		—		25
FET minority interest sale, net of transaction costs	—	—		1,887		—			—		1,887		451		2,338
Balance, June 30, 2022	571	$	57	$	11,943	$	(12)		$	(1,130)	$	10,858	$	456	$	11,314

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

FIRSTENERGY CORP.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Six Months Ended June 30,
(In millions)	2023		2022
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	564	$	480
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments	657		695


Deferred income taxes and investment tax credits, net	133		123

Retirement benefits, net of payments	(51)		(188)
Pension trust contribution	(750)		—
Pension and OPEB mark-to-market adjustment	(59)		—


Transmission revenue collections, net	(65)		23



Changes in current assets and liabilities-
Receivables	110		(109)
Materials and supplies	(28)		(44)
Prepaid taxes and other current assets	(128)		(121)
Accounts payable	(303)		239
Accrued taxes	(64)		(16)
Accrued interest	29		(28)
Accrued compensation and benefits	(65)		(85)
Other current liabilities	(14)		(5)
Collateral, net	(190)		262
Other	11		57
Net cash provided from (used for) operating activities	(213)		1,283



CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments	(1,418)		(1,186)

Sales of investment securities held in trusts	18		16
Purchases of investment securities held in trusts	(24)		(22)

Asset removal costs	(117)		(97)
Other	(6)		8
Net cash used for investing activities	(1,547)		(1,281)

CASH FLOWS FROM FINANCING ACTIVITIES:
New financing-
Long-term debt	2,600		—
Short-term borrowings, net	250		—


Redemptions and repayments-
Long-term debt	(515)		(2,745)


Proceeds from FET minority interest sale, net of transaction costs	—		2,348
Distributions to FET minority interest	(53)		—


Common stock dividend payments	(447)		(445)
Other	(67)		(139)
Net cash provided from (used for) financing activities	1,768		(981)

Net change in cash, cash equivalents, and restricted cash	8		(979)
Cash, cash equivalents, and restricted cash at beginning of period	206		1,511
Cash, cash equivalents, and restricted cash at end of period	$	214	$	532

SUPPLEMENTAL CASH FLOW INFORMATION:
Significant non-cash transactions:
Accrued capital investments	$	143	$	106

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

FIRSTENERGY CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)


Note Number		Page Number

1	Organization and Basis of Presentation	7

2	Revenue	10

3	Earnings Per Share	11

4	Pension and Other Post-Employment Benefits	12

5	Income Taxes	14

6	Fair Value Measurements	15

7	Regulatory Matters	18

8	Commitments, Guarantees and Contingencies	25

9	Segment Information	31

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 and WP. Additionally, FET is a majority-owned subsidiary of FE, and is the parent company of ATSI, MAIT, PATH and TrAIL. In addition, FE holds all of the outstanding equity of other direct subsidiaries including FEV, which currently holds a 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in the Signal Peak mining and coal transportation operations.

On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA I, 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 would own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction closed on May 31, 2022. The difference between the cash consideration received, net of transaction costs of approximately $37 million, and the carrying value of the NCI of $451 million was recorded as an increase to OPIC. FirstEnergy presents the third-party investors’ ownership portion of FirstEnergy's net income, net assets and comprehensive income as NCI. NCI is included as a component of equity on the Consolidated Balance Sheets.

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.

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, 2022.

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 variable interest entity 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, including presenting long-term debt and other long-term obligations within “Noncurrent Liabilities” on the Consolidated Balance Sheets as compared to “Total Capitalization”.

Economic Conditions

Economic conditions following the global pandemic have increased lead times across numerous material categories, with some as much as doubling from pre-pandemic lead times. Some key suppliers have struggled with labor shortages and raw material availability, which along with increasing inflationary pressure, have increased costs and decreased the availability 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 a prolonged continuation or further increase in supply chain disruptions could have an adverse effect on FirstEnergy’s results of operations, cash flow and financial condition.

Sale of Equity Interest in FirstEnergy Transmission, LLC

On February 2, 2023, FE, along with FET, entered into the FET P&SA II with Brookfield and the Brookfield Guarantors, pursuant to which FE agreed to sell to Brookfield at the closing, and Brookfield agreed to purchase from FE, an incremental 30% equity interest in FET for a purchase price of $3.5 billion. The purchase price will be payable in part by the issuance of a promissory note expected to be in the principal amount of $1.75 billion. The remaining $1.75 billion of the purchase price will be payable in cash at the closing. As a result of the consummation of the transaction, Brookfield’s interest in FET will increase from 19.9% to 49.9%, while FE will retain the remaining 50.1% ownership interests of FET. The transaction is subject to customary closing conditions, including approval from the FERC and certain state utility commissions, and completion of review by the CFIUS. In addition, pursuant to the FET P&SA II, FirstEnergy has agreed to make the necessary filings with the applicable regulatory authorities for the PA Consolidation. The FET Minority Equity Interest Sale is expected to close by early 2024. Upon closing, FET will continue to be consolidated in FirstEnergy’s GAAP financial statements.

Pursuant to the terms of the FET P&SA II, in connection with the closing, Brookfield, FET and FE will enter into the A&R FET LLC Agreement, which will amend and restate in its entirety the current limited liability company agreement of FET. The A&R 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 A&R FET LLC Agreement, at the closing, the FET Board will consist of five directors, two appointed by Brookfield and three appointed by FE. Each of Brookfield’s and FE’s respective appointment rights are subject to such party maintaining certain minimum ownership percentages. The A&R 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 A&R FET LLC Agreement, for so long as Brookfield holds at least a 30.0% interest in FET, Brookfield’s consent is required for FET or any of its subsidiaries to, among other things, undertake certain acquisitions or dispositions in excess of certain dollar thresholds, establish or amend the annual budget, incur cost overruns on certain capital expenditures projects during any fiscal year in excess of a certain percentage overage of the budgeted amounts or incur cost overruns on the aggregate capital expenditure budget of FET’s subsidiaries during any fiscal year in excess of a certain percentage overage of the aggregated budgeted amount, make material decisions relating to litigation where either the potential liability exposure is in excess of a certain threshold dollar amount or such proceeding would reasonably be expected to have an adverse effect on Brookfield or FET, make certain material regulatory filings, incur or refinance indebtedness by FET or its subsidiaries, which, in the case of its subsidiaries, would reasonably be expected to cause such subsidiary to deviate from its targeted capital structure, enter into joint ventures, appoint or replace any member of its transmission leadership team, amend the accounting policies of FET or its subsidiaries (but only if FE is no longer the majority owner of FET), take any action that would reasonably be expected to cause a default or breach of any material contract of FET or any of its subsidiaries, create certain material liens (excluding certain permitted liens), or cause any reorganization of FET or any of its subsidiaries. The A&R FET LLC Agreement also includes provisions relating to the resolution of disputes and to address deadlocks.

Consolidation of Pennsylvania Companies

FirstEnergy is proceeding with the consolidation of the Pennsylvania Companies into FE PA, a new, single operating entity. The PA Consolidation will require, among other steps: (a) the transfer of certain Pennsylvania-based transmission assets owned by WP to KATCo, (b) the contribution of Class B equity interests of MAIT currently held by PN and ME to FE (and ultimately transferred to FET as part of the FET Minority Equity Interest Sale), (c) the formation of FE PA and (d) the merger of each of the Pennsylvania Companies with and into FE PA, with FE PA surviving such mergers as the successor-in-interest to all assets and liabilities of the Pennsylvania Companies. Following completion of the PA Consolidation, FE PA will be FE’s only regulated utility in Pennsylvania encompassing the operations previously conducted individually by the Pennsylvania Companies. Consummation of the PA Consolidation is contingent upon numerous conditions, including the approval of NYPSC, PPUC and FERC, which filings were submitted on March 6, 2023. Subject to receipt of such regulatory approvals, FirstEnergy expects that the PA Consolidation will close by early 2024.

Capitalized Financing Costs

For the three months ended June 30, 2023 and 2022, capitalized financing costs on FirstEnergy’s Consolidated Statements of Income include $11 million of allowance for equity funds used during construction for both periods and $11 million and $6 million, respectively, of capitalized interest. For the six months ended June 30, 2023 and 2022, capitalized financing costs on FirstEnergy’s Consolidated Statements of Income include $19 million and $24 million, respectively, of allowance for equity funds used during construction and $24 million and $12 million, respectively, of capitalized interest.

Equity Method Investments

Investments 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 on the Consolidated Balance Sheets. The percentage of FE's ownership share of the entity’s earnings is reported in the Consolidated Statements of Income and Comprehensive Income and reflected in “Other Income (Expense)”.

Equity method investments included within "Investments" on the Consolidated Balance Sheets were approximately $93 million and $90 million as of June 30, 2023 and December 31, 2022, respectively.

Global Holding - FEV currently holds a 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in the Signal Peak mining and coal transportation operations with coal sales primarily focused on international markets. FEV is not the primary beneficiary of the joint venture, as it does not have control over the significant activities affecting the joint venture’s economic performance. FEV's ownership interest is subject to the equity method of accounting. For the three months ended June 30, 2023 and 2022, pre-tax income related to FEV’s ownership in Global Holding was $35 million and $64 million, respectively, and $89 million and $76 million for the six months ended June 30, 2023 and 2022, respectively. FEV’s pre-tax equity earnings and investment in Global Holding are included in Corporate/Other for segment reporting.

As of June 30, 2023 and December 31, 2022, the carrying value of the equity method investment was $56 million and $57 million, respectively. During the six months ended June 30, 2023 and 2022, FEV received cash dividends from Global Holding of $90 million and $70 million, which were classified with “Cash from Operating Activities” on the Consolidated Statements of Cash Flow.

PATH WV - PATH, a proposed transmission line from West Virginia through Virginia into Maryland which PJM cancelled in 2012, is a series limited liability company that is comprised of multiple series, each of which has separate rights, powers and duties regarding specified property and the series profits and losses associated with such property. A subsidiary of FE owns 100% of the Allegheny Series (PATH-Allegheny) and 50% of the West Virginia Series (PATH-WV), which is a joint venture with a subsidiary of AEP. FirstEnergy is not the primary beneficiary of PATH-WV, as it does not have control over the significant activities affecting the economics of PATH-WV. FirstEnergy's ownership interest in PATH-WV is subject to the equity method of accounting. As of June 30, 2023 and December 31, 2022, the carrying value of the equity method investment was $18 million.

Reference Rate Reform

In March of 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): “Facilitation of the Effects of Reference Rate Reform on Financial Reporting” (issued March 2020 and subsequently updated). This ASU, which introduces Topic ASC 848 to the FASB codification, provides temporary optional expedients and exceptions, that if elected, will ease the financial reporting burdens related to the market transition from LIBOR and other interbank offered rates to alternative reference rates.

On April 27, 2023, FE, FET, the Utilities and the Transmission Companies entered into the 2023 Amendments to, among other things, (i) permit the sale from FE to Brookfield of an incremental 30% equity interest in FET for a purchase price of $3.5 billion, (ii) permit the consolidation of the Pennsylvania Companies into a new, single operating entity, FE PA, which will be FE’s only regulated utility in Pennsylvania encompassing the operations previously conducted individually by the Pennsylvania Companies, and (iii) transition the benchmark interest rate for borrowings under the 2021 Credit Facilities from LIBOR to SOFR. During the second quarter of 2023, FirstEnergy utilized the optional expedient within ASC 848 to account for the amendments to the credit facilities as a continuation of the existing contract without additional analysis.

New Accounting Pronouncements

Recently Issued Pronouncements - FirstEnergy is currently assessing the impact of new authoritative accounting guidance issued by the FASB that has not yet been adopted and the impact it will have on its financial statements and disclosures, as well as the potential to early adopt where applicable. The current expectation is that such new standards will not significantly impact FirstEnergy's financial reporting.

2. REVENUE

The following represents a disaggregation of revenue from contracts with customers for the three and six months ended June 30, 2023 and 2022:


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2023		2022		2023		2022
Regulated Distribution
Retail generation and distribution services
Residential	$	1,414	$	1,310	$	3,116	$	2,852
Commercial	627		575		1,272		1,172
Industrial	353		312		706		595
Other	27		18		52		38
Wholesale	61		159		108		249
Other revenue from contracts with customers	32		29		56		55
Total revenues from contracts with customers	2,514		2,403		5,310		4,961

Other revenue unrelated to contracts with customers	28		23		58		54
Total Regulated Distribution	$	2,542	$	2,426	$	5,368	$	5,015

Regulated Transmission
ATSI	$	242	$	217	$	468	$	434
TrAIL	65		64		131		127
MAIT	99		77		188		156
JCP&L	57		46		100		106
MP, PE and WP	55		36		91		68
Total revenues from contracts with customers	518		440		978		891
Other revenue unrelated to contracts with customers	2		1		3		3
Total Regulated Transmission	$	520	$	441	$	981	$	894

Corporate/Other and Reconciling Adjustments (1)
Wholesale	$	3	$	8	$	5	$	14
Retail generation and distribution services (1)	(46)		(45)		(91)		(90)
Other revenue unrelated to contracts with customers (1)	(13)		(12)		(26)		(26)
Total Corporate/Other and Reconciling	$	(56)	$	(49)	$	(112)	$	(102)

FirstEnergy Total Revenues	$	3,006	$	2,818	$	6,237	$	5,807

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

Other revenue unrelated to contracts with customers includes revenue from late payment charges of $10 million and $9 million for the three months ended June 30, 2023 and 2022, respectively. Other revenue unrelated to contracts with customers also includes revenue from derivatives of $6 million and $2 million for the three months ended June 30, 2023 and 2022, respectively.

Other revenue unrelated to contracts with customers includes revenue from late payment charges of $21 million and $19 million for the six months ended June 30, 2023 and 2022, respectively. Other revenue unrelated to contracts with customers also includes revenue from derivatives of $12 million and $11 million for the six months ended June 30, 2023 and 2022, respectively.

Customer Receivables

Receivables from contracts with customers include distribution services and retail generation sales to residential, commercial and industrial customers of the Utilities. Billed and unbilled customer receivables as of June 30, 2023 and December 31, 2022, are included below:


Customer Receivables	June 30, 2023		December 31, 2022
	(In millions)
Billed	$	625	$	674
Unbilled	646		781
	1,271		1,455

Less: Uncollectible Reserve	85		137
Total Customer Receivables	$	1,186	$	1,318

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 the pandemic and the impact on customer receivable balances outstanding and write-offs since the pandemic began and subsequent economic slowdown. FirstEnergy’s uncollectible risk on PJM receivables, resulting from transmission and wholesale sales, is minimal due to the nature of PJM’s settlement process and as a result there is no current allowance for doubtful accounts.

During 2023, various regulatory actions, including extended installment plans, continue to impact the level of past due balances in certain states, resulting in the allowance for uncollectible accounts on receivables to remain elevated above 2019 pre-pandemic levels. However, normal collection activity has resumed and arrears levels continue to decline towards pre-pandemic levels. As a result, FirstEnergy recognized a $52 million decrease to its allowance during the first six months of 2023, of which $27 million was applied to existing deferred regulatory assets.

Activity in the allowance for uncollectible accounts on customer receivables for the six months ended June 30, 2023 and for the year ended December 31, 2022 are as follows:


	(In millions)

Balance, January 1, 2022	$	159
Provision for expected credit losses (1)	59
Charged to other accounts (2)	62
Write-offs	(143)
Balance, December 31, 2022	$	137
Provision for expected credit losses (1)	(12)
Charged to other accounts (2)	18
Write-offs	(58)
Balance, June 30, 2023	$	85

(1) Approximately $(13) million and $11 million of which was deferred for future recovery (refund) in the six months ended June 30, 2023 and the year ended December 31, 2022, respectively.

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

3. EARNINGS PER SHARE

EPS is calculated by dividing earnings attributable to FE by the weighted average number of common shares outstanding.

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 and convertible securities. 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 dilutive effect of the 2026 Convertible Notes, as further discussed in Note 6, “Fair Value Measurements” under Long-term debt and other long-term obligations, is computed using the if-converted method.

The following table reconciles basic and diluted EPS attributable to FE:


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
Reconciliation of Basic and Diluted EPS	2023		2022		2023		2022

(In millions, except per share amounts)



Earnings attributable to FE	$	235	$	187	$	527	$	475

Share count information:
Weighted average number of basic shares outstanding	573		571		573		571
Assumed exercise of dilutive stock options and awards	1		1		1		1
Weighted average number of diluted shares outstanding	574		572		574		572

EPS attributable to FE:



Basic EPS	$	0.41	$	0.33	$	0.92	$	0.83



Diluted EPS	$	0.41	$	0.33	$	0.92	$	0.83

For the three and six months ended June 30, 2023 and 2022, no shares from stock options and awards were excluded from the calculation of diluted shares outstanding, as their inclusion would have been antidilutive.

The dilutive effect of the 2026 Convertible Notes is limited to the conversion obligation in excess of the aggregate principal amount of the 2026 Convertible Notes being converted. For the three and six months ended June 30, 2023, there was no dilutive effect resulting from the 2026 Convertible Notes as the average market price of FE shares of common stock was below the initial conversion price of $46.81 per share. See Note 6, “Fair Value Measurements” for additional details on the 2026 Convertible Notes that were issued during the second quarter of 2023.

4. PENSION AND OTHER POST-EMPLOYMENT BENEFITS

The components of FirstEnergy’s net periodic benefit costs (credits) for pension and OPEB were as follows:


Components of Net Periodic Benefit Costs (Credits)	Pension				OPEB
For the Three Months Ended June 30,	2023		2022		2023		2022
	(In millions)
Service costs	$	35	$	46	$	—	$	1
Interest costs	107		68		6		2
Expected return on plan assets	(142)		(164)		(8)		(10)
Amortization of prior service costs (credits)	1		—		(2)		(2)
Special termination benefits (1)	5		—		2		—
Pension and OPEB mark-to-market adjustment	(59)		—		—		—
Net periodic benefit credits	$	(53)	$	(50)	$	(2)	$	(9)
Net periodic benefit credits, net of amounts capitalized	$	(70)	$	(72)	$	(3)	$	(10)

(1) Related to benefits provided in connection with the PEER.


Components of Net Periodic Benefit Costs (Credits)	Pension				OPEB
For the Six Months Ended June 30,	2023		2022		2023		2022
	(In millions)
Service costs	$	69	$	92	$	1	$	2
Interest costs	216		136		11		5
Expected return on plan assets	(270)		(328)		(16)		(20)
Amortization of prior service costs (credits) (1)	1		1		(4)		(5)
Special termination benefits (2)	5		—		2		—
Pension and OPEB mark-to-market adjustment	(59)		—		—		—
Net periodic benefit credits	$	(38)	$	(99)	$	(6)	$	(18)
Net periodic benefit credits, net of amounts capitalized	$	(73)	$	(141)	$	(7)	$	(19)

(1) The income tax benefits associated with the pension and OPEB prior service costs amortized out of AOCI were $1 million for the six months ended June 30, 2023 and 2022.

(2) Related to benefits provided in connection with the PEER.

On May 9, 2023, FirstEnergy announced a voluntary retirement program for eligible non-bargaining employees, known as the PEER. More than 65% of eligible employees, totaling approximately 450 employees accepted the PEER, which included lump sum compensation equivalent to severance benefits, healthcare continuation costs and a temporary pension enhancement with most participating employees expected to depart by the end of 2023. The temporary pension enhancement and healthcare continuation costs are classified as special termination costs within net periodic benefit costs (credits). In addition to the PEER, FirstEnergy notified and involuntarily separated approximately 90 employees on May 9, 2023. Management expects the cost savings resulting from these initiatives to support FirstEnergy’s growth plans.

FirstEnergy’s pension and OPEB funding policy is based on actuarial computations using the projected unit credit method. On May 12, 2023, FirstEnergy made a $750 million voluntary cash contribution to the qualified pension plan. As a result of this contribution, FirstEnergy does not currently expect to have a required contribution to the pension plan through 2027 based on various assumptions, including an annual expected rate of return on assets of 8.0% in 2023. However, FirstEnergy may elect to contribute to the pension plan voluntarily.

FirstEnergy recognizes a pension and OPEB mark-to-market adjustment for the change in fair value of plan assets and net actuarial gains and losses annually in the fourth quarter of each fiscal year and whenever a plan is determined to qualify for remeasurement. The size of the voluntary contribution made on May 12, 2023, in relation to total pension assets triggered a remeasurement of the pension plan, and as a result, FirstEnergy recognized a non-cash, pre-tax pension mark-to-market adjustment gain of approximately $59 million in the second quarter of 2023. The pension mark-to-market adjustment primarily reflects higher than expected return on assets, partially offset by a 29 basis points decrease in the discount rate used to measure benefit obligations. The discount rate used to measure pension obligations was 4.94% as of April 30, 2023 and 5.23% as of December 31, 2022. The discount rate used to measure OPEB obligations was 5.16% as of December 31, 2022. Actual returns on the pension assets through the date of the voluntary contribution were approximately 7.7%, as compared to expected return on assets of 2.67% (8.0% on an annualized basis). FirstEnergy elected the practical expedient to remeasure pension plan assets and obligations as of April 30, 2023, which is the month-end closest to the date of the voluntary contribution.

Based on the following assumptions, FirstEnergy expects its 2023 pre-tax net periodic costs, including amounts capitalized and the $59 million pension mark-to-market adjustment gain in the second quarter of 2023, to be a credit of approximately $47 million.


Assumption	Pension	OPEB
Effective rate for interest costs on benefit obligations(1)	5.10%/4.80%	5.06	%
Effective rate for service costs(1)	5.34%/5.11%	5.41	%
Effective rate for interest on service costs(1)	5.22%/4.94%	5.33	%
Annual expected rate of return on plan assets	8.00%	7.00	%

(1) Pension rates effective for January 1, 2023 through April 30, 2023 and May 1, 2023 through December 31, 2023, respectively.

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 2023 and 2022. These tax rates are affected by estimated annual permanent items, such as AFUDC equity and other flow-through items, as well as certain discrete items. The following tables reconcile the effective tax rate to the federal income tax statutory rate for the three and six months ended June 30, 2023 and 2022:


	For the Three Months						For the Six Months
	Ended June 30,						Ended June 30,
	2023			2022			2023			2022
	(In millions)
Income before income taxes	$	328		$	241		$	728		$	612
Federal income tax expense at statutory rate (21%)	$	69		$	51		$	153		$	129
Increases (reductions) in tax expense resulting from:
State income taxes, net of federal tax benefit	19			17			43			44
AFUDC equity and other flow-through	(4)			(7)			(9)			(14)
Excess deferred tax amortization due to the Tax Act	(16)			(15)			(32)			(31)

Valuation allowances	—			—			—			34
Remeasurement of state deferred taxes	—			—			—			(26)

Other, net	6			3			9			(4)
Total income taxes	$	74		$	49		$	164		$	132
Effective income tax rate	22.6		%	20.3		%	22.5		%	21.6		%

During the six months ended June 30, 2023, there was no change to FirstEnergy’s reserve for uncertain tax positions. As of June 30, 2023, it remains reasonably possible that approximately $25 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.

On March 29, 2023, the West Virginia Governor signed into law House Bill 3286, which allows corporate taxpayers a reduction to pre-apportionment federal taxable income with the amount necessary to offset the increase in the net deferred tax liability (or decrease in the net deferred tax asset) caused by West Virginia’s apportionment law change enacted in 2021. Beginning with the 2033 tax year, qualifying taxpayers can subtract one-tenth of the amount each year for ten years. Taxpayers intending to claim this subtraction will have to file a statement with the West Virginia tax commissioner by July 1, 2024, specifying the total amount of subtraction to be claimed. Accordingly, FirstEnergy recorded a state deferred tax asset of approximately $9 million in the first quarter of 2023, which has been fully reserved due to current estimates and assumptions of future taxable income apportioned to West Virginia.

On August 16, 2022, President Biden signed into law the IRA of 2022, which, among other things, imposes a new 15% corporate AMT based on AFSI applicable to corporations with a three-year average AFSI over $1 billion. The AMT is effective for the 2023 tax year and, if applicable, corporations must pay the greater of the regular corporate income tax or the AMT. Although NOL carryforwards created through the regular corporate income tax system cannot be used to reduce the AMT, financial statement net operating losses can be used to reduce AFSI and the amount of AMT owed. The IRA of 2022 as enacted requires the U.S. Treasury to provide regulations and other guidance necessary to administer the AMT, including further defining allowable adjustments to determine AFSI, which directly impacts the amount of AMT to be paid. Based on interim guidance issued by the U.S. Treasury in late December 2022, FirstEnergy continues to believe that it is more likely than not it will be subject to the AMT beginning in 2023. Accordingly, FirstEnergy made a first quarter estimated payment of AMT of approximately $49 million in April 2023. In June 2023, the U.S. Treasury issued additional guidance that eliminated the requirement of corporations to include AMT in quarterly estimated tax payments, pending further guidance on the application and administration of AMT. As a result of this guidance, current forecast of AMT obligation and the amount of AMT already paid in April 2023, FirstEnergy does not expect to make any additional AMT payments in 2023. Until final U.S. Treasury guidance is issued, the amount of AMT FirstEnergy pays could be significantly different than current estimates or it may not be a payer at all. The regulatory treatment of the impacts of this legislation will also be subject to the discretion of the FERC and state public utility commissions. Any adverse development in this legislation, including guidance from the U.S. Treasury and/or the IRS or unfavorable regulatory treatment, could reduce FirstEnergy’s future cash flows and impact financial condition.

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 June 30, 2023, from those used as of December 31, 2022. 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 table sets forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy:


	June 30, 2023								December 31, 2022
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(In millions)


Derivative assets FTRs (1)	$	—	$	—	$	10	$	10	$	—	$	—	$	11	$	11

Equity securities	2		—		—		2		2		—		—		2


U.S. state and municipal debt securities	—		269		—		269		—		266		—		266
Cash, cash equivalents and restricted cash (2)	214		—		—		214		206		—		—		206
Other (3)	—		41		—		41		—		40		—		40
Total assets	$	216	$	310	$	10	$	536	$	208	$	306	$	11	$	525

Liabilities

Derivative liabilities FTRs (1)	$	—	$	—	$	(5)	$	(5)	$	—	$	—	$	(2)	$	(2)


Total liabilities	$	—	$	—	$	(5)	$	(5)	$	—	$	—	$	(2)	$	(2)

Net assets	$	216	$	310	$	5	$	531	$	208	$	306	$	9	$	523

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

(2) Restricted cash of $43 million and $46 million as of June 30, 2023 and December 31, 2022, 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.

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 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 Unites States Department of Energy 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 June 30, 2023, and December 31, 2022:


	June 30, 2023 (1)								December 31, 2022 (1)
	Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value		Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value
	(In millions)

Debt securities	$	298	$	—	$	(29)	$	269	$	294	$	—	$	(28)	$	266

(1) Excludes short-term cash investments of $5 million as of June 30, 2023 and December 31, 2022.

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 and six months ended June 30, 2023 and 2022, were as follows:














	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2023		2022		2023		2022
	(In millions)
Sale proceeds	$	17	$	10	$	18	$	16
Realized gains	—		1		—		1
Realized losses	(1)		(1)		(2)		(2)

Interest and dividend income	3		3		6		6

Other Investments

Other investments include employee benefit trusts, which are primarily invested in corporate-owned life insurance policies and equity method investments. Earnings and losses associated with corporate-owned life insurance policies are reflected in “Miscellaneous Income, net” on FirstEnergy’s Consolidated Statements of Income. The total carrying value of other investments were $364 million and $351 million as of June 30, 2023, and December 31, 2022, respectively, and are excluded from the amounts reported above. See Note 1, "Organization and Basis of Presentation," for additional information on FirstEnergy's equity method investments.

For the three months ended June 30, 2023 and 2022, pre-tax income (expense) related to corporate-owned life insurance policies were $3 million and $(16) million, respectively, and $10 million and $(22) million for the six months ended June 30, 2023 and 2022, respectively. Corporate-owned life insurance policies are valued using the cash surrender value and any changes in value during the period are recognized as income or expense.

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 June 30, 2023 and December 31, 2022:


	June 30, 2023		December 31, 2022
	(In millions)
Carrying value	$	23,726	$	21,641
Fair value	$	21,921	$	19,784

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 June 30, 2023, and December 31, 2022.

FirstEnergy had the following redemptions and issuances during the six months ended June 30, 2023:


Company	Type	Redemption / Issuance Date	Interest Rate	Maturity	Amount (In millions)	Description
Redemptions (1)
ME	Unsecured Notes	March, 2023	3.50%	2023	$300	ME redeemed unsecured notes that became due.
FE	Unsecured Notes	May, 2023	7.375%	2031	$194	FE repurchased approximately $194 million of the principal amount of its 2031 Notes through the open market for $228 million including a premium of approximately $34 million ($27 million after-tax). In addition, FE recognized approximately $2 million ($1 million after-tax) of deferred cash flow hedge losses associated with the FE debt redemptions.









Issuances
WP	FMBs	January, 2023	5.29%	2033	$50	Proceeds were used to repay short-term borrowings, to finance capital expenditures and for other general corporate purposes.
MAIT	Unsecured Notes	February, 2023	5.39%	2033	$175	Proceeds were used to repay short-term borrowings, to finance capital expenditures and for other general corporate purposes.
ME	Unsecured Notes	March, 2023	5.20%	2028	$425	Proceeds were used to repay short-term borrowings, including borrowings incurred to repay, at maturity, the $300 million aggregate principal amount of ME's 3.50% unsecured notes due March 15, 2023, to finance capital expenditures and for other general corporate purposes.
PN	Unsecured Notes	March, 2023	5.15%	2026	$300	Proceeds were used to repay short-term borrowings, to finance capital expenditures and for other general corporate purposes.
ATSI	Unsecured Notes	May, 2023	5.13%	2033	$150	Proceeds were used to repay short-term borrowings, to finance capital expenditures and for other general corporate purposes
FE	Unsecured Convertible Notes	May, 2023	4.00%	2026	$1,500	Proceeds were used to repay short-term borrowings, to repurchase a portion of its 2031 Notes, to fund the qualified pension plan and for other general corporate purposes.

(1) Excludes principal payments on securitized bonds.

Convertible Notes

As discussed above, on May 4, 2023, FE issued $1.5 billion aggregate principal amount of 2026 Convertible Notes, with a fixed interest rate of 4.00% per year, payable semiannually in arrears on May 1 and November 1 of each year, beginning on November 1, 2023. The 2026 Convertible Notes are unsecured and unsubordinated obligations of FE, and will mature on May 1, 2026, unless required to be converted or repurchased in accordance with their terms. However, FE may not elect to redeem the 2026 Convertible Notes prior to the maturity date. The 2026 Convertible Notes are included within “Long-term debt and other long-term obligations” on the FirstEnergy Consolidated Balance Sheets. Proceeds from the issuance were approximately $1.48 billion, net of issuance costs.

Prior to the close of business on the business day immediately preceding February 1, 2026, the 2026 Convertible Notes will be convertible at the option of the holders only under the following conditions:

During any calendar quarter, if the last reported sale price of FE’s common stock for at least 20 trading days during the period of 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day;
During the five consecutive business day period immediately after any 10 consecutive trading day period in which the trading price per $1,000 principal amount of the 2026 Convertible Notes for each trading day of such 10 trading day period was less than 98% of the product of the last reported sale price of FE’s common stock and the conversion rate on each such trading day; or
Upon the occurrence of certain corporate events specified in the indenture governing the 2026 Convertible Notes.

On and after February 1, 2026, until the close of business on the second scheduled trading day immediately preceding the maturity date, holders of the 2026 Convertible Notes may convert all or any portion of their 2026 Convertible Notes at their option at any time at the conversion rate then in effect, irrespective of these conditions. FE will settle conversions of the 2026 Convertible Notes, if any, by paying cash up to the aggregate principal amount of the 2026 Convertible Notes being converted and by paying cash or delivering shares of FE’s common stock (or a combination of each), at its election, of its conversion obligation in excess of the aggregate principal amount of the 2026 Convertible Notes being converted.

The conversion rate for the 2026 Convertible Notes will initially be 21.3620 shares of FE’s common stock per $1,000 principal amount of the 2026 Convertible Notes (equivalent to an initial conversion price of approximately $46.81 per share of FE’s common stock). The initial conversion price of the 2026 Convertible Notes represents a premium of approximately 20% over the last reported sale price of FE’s common stock on the New York Stock Exchange on May 1, 2023. The conversion rate and the corresponding conversion price will be subject to adjustment in some events but will not be adjusted for any accrued and unpaid interest. FE may not elect to redeem the 2026 Convertible Notes prior to the maturity date.

If FE undergoes a fundamental change (as defined in the relevant indenture), subject to certain conditions, holders of the 2026 Convertible Notes may require FE to repurchase for cash all or any portion of their 2026 Convertible Notes at a repurchase price equal to 100% of the principal amount of the 2026 Convertible Notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change repurchase date (as defined in the relevant indenture). In addition, if certain fundamental changes occur, FE may be required, in certain circumstances, to increase the conversion rate for any 2026 Convertible Notes converted in connection with such fundamental changes by a specified number of shares of its common stock.

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 and/or local 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.

On March 22, 2023, PE filed a base rate case with the MDPSC, utilizing a test year based on twelve months of actual 2022 data. The base rate case requests an annual net increase in base distribution rates of $50.4 million, plus a request to establish a regulatory asset (or liability) to recover (or refund) in a subsequent base rate case the net differences between the amount of pension and OPEB expense requested in the proceeding (based on average expense from 2018 to 2022) and the actual annual amount each year using the delayed recognition method. The rate case additionally requests approval to continue an Electric Distribution Investment Surcharge to fund three service reliability and resiliency programs, two new proposed programs to assist low-income customers and cost recovery of certain expenses associated with PE’s pilot electric vehicle charger program and its COVID-19 pandemic response. In July 2023, testimony was filed by the MDPSC Staff and the Maryland Office of People’s Counsel recommending a base distribution rate increase of $29.3 million and $19.8 million, respectively. Evidentiary hearings began July 18, 2023. PE expects that new rates will be effective in the fourth quarter of 2023.

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. On October 28, 2022, PE submitted its plan, as ordered by the MDPSC, to recover all unamortized balances by the scheduled expiration of the EmPOWER program on December 31, 2029. At the further direction of the MDPSC, PE filed a revised plan on January 11, 2023. 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.

On April 17, 2023, PE submitted a proposal to the MDPSC seeking approval to end its PPA with the Warrior Run generating station. The PPA for Warrior Run was a requirement of the Public Utility Regulatory Policies Act of 1978. PE’s Maryland customers currently pay a surcharge on their electric bill in connection with the Warrior Run PPA, which fluctuates from year to year based on the difference between what PE pays for the output of the plant and what PE is able to recover by reselling that output into PJM. PE negotiated a termination of the PPA requiring it to pay Warrior Run, subject to MDPSC approval, a fixed amount of $51 million annually through 2029, for a total of $357 million. During the second quarter of 2023, a liability was established for the $357 million termination fee, of which $55 million was included in “Other current liabilities” and $302 million in “Other non-current liabilities”, and as the cost of the termination fee will be recovered through the current surcharge, an offsetting regulatory asset was established on FirstEnergy’s Consolidated Balance Sheets, and results in no impact to FirstEnergy’s or PE’s current or future earnings and is expected to result in savings for PE’s Maryland customers. The MDPSC approved the termination on June 21, 2023, and the termination became effective on June 28, 2023.

NEW JERSEY

JCP&L operates under NJBPU approved rates that took effect as of January 1, 2021, and 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.

On March 16, 2023, JCP&L filed a base rate case with the NJBPU, utilizing a test year based on six months of actual data for the second half of calendar year 2022, and six months of forecasted data for the first half of calendar year 2023. The rate case requests an annual net increase in base distribution revenues of approximately $185 million, plus a request to establish a regulatory asset (or liability) to recover (or refund) in a subsequent base rate case the net differences between the amount of pension and OPEB expense requested in the proceeding (based on 2023 expense) and the actual annual amount each year using the delayed recognition method. On June 2, 2023, JCP&L updated its base rate case to provide actual test-year data for the first quarter of calendar year 2023 and update its proposed annual net increase in base rate distribution revenues to approximately $193 million. In addition to the above, JCP&L’s request includes, among other things, approval of two new proposed programs to assist low-income customers, cost recovery of certain investments and expenses associated with its electric vehicle and AMI programs, an update of its depreciation rates, modifications to its storm cost recovery, and tariff modifications to update standard construction costs. A procedural schedule was adopted setting evidentiary hearings to be held the week of January 8, 2024.

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 $160 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 $43 million recovered on an annual basis.

On March 6, 2023, the NJBPU issued final rules modifying its regulations to reflect its 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 100% of CTA savings to customers; and (iii) exclude transmission assets of EDCs in the savings calculation. The final rules of practice were applied by JCP&L in its most recent base rate case filing described above.

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, which began in May 2021. On April 12, 2023, the NJBPU accepted the final management audit report for filing purposes and ordered that interested stakeholders file comments on the report by May 22, 2023, which deadline was extended until July 31, 2023. JCP&L filed its comments on July 31, 2023.

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. No moratorium on residential

disconnections remains in effect for investor-owned electric utilities such as JCP&L. 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. On July 17, 2023, JCP&L submitted a stand-alone filing to recover approximately $31 million, through October 1, 2023, in incremental costs and interest incurred during the COVID-19 pandemic.

On September 17, 2021, in connection with Mid-Atlantic Offshore Development, LLC, a transmission company jointly owned by Shell New Energies US and EDF Renewables North America, JCP&L submitted a proposal to the NJBPU and PJM to build transmission infrastructure connecting offshore wind-generated electricity to the New Jersey power grid. On October 26, 2022, the JCP&L proposal was accepted, in part, in an order issued by NJBPU. The proposal, as accepted, included approximately $723 million in investments for JCP&L to both build new and upgrade existing transmission infrastructure. JCP&L’s proposal projects an investment ROE of 10.2% and includes the option for JCP&L to acquire up to a 20% equity stake in Mid-Atlantic Offshore Development, LLC. The resulting rates associated with the project are expected to be shared among the ratepayers of all New Jersey electric utilities. On April 17, 2023, JCP&L applied for the FERC “abandonment” transmission rates incentive, which would provide for recovery of 100% of the cancelled prudent project costs that are incurred after the incentive is approved, and 50% of the costs incurred prior to that date, in the event that some or all of the project is cancelled for reasons beyond JCP&L’s control. FERC staff subsequently requested additional information on JCP&L’s application, which JCP&L provided. An order from FERC is expected on or before August 21, 2023. Construction is expected to begin in 2025.

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 April 5, 2023, the Ohio Companies filed an application with the PUCO for approval of ESP V, for an eight-year term beginning June 1, 2024, and continuing through May 31, 2032. ESP V proposes to continue providing power to non-shopping customers at market-based prices set through an auction process, with process enhancements designed to reduce costs to customers. ESP V also proposes to continue riders supporting investment in the Ohio Companies’ distribution system, including Rider DCR with annual revenue cap increases of $15 to $21 million per year, based on reliability performance, and Rider AMI for recovery of approved grid modernization investments. ESP V proposes new riders to support continued maintenance of the distribution system, including vegetation management and storm restoration operating expense. In addition, ESP V proposes four-year energy efficiency and peak demand reduction programs for residential and commercial customers, with cost recovery spread over eight years. ESP V further includes a commitment to spend $52 million in total over the eight-year term, without recovery from customers, on initiatives to assist low-income customers, education and incentives to help ensure customers have good experiences with electric vehicles, as well as investment in energy storage as a distribution asset if the Ohio Companies’ application to the DOE for funding under the Grid Innovation Program of the federal Infrastructure Investment and Jobs Act is accepted. Hearings are scheduled to commence on November 7, 2023.

On May 16, 2022, the Ohio Companies filed their application for determination of the existence of SEET under ESP IV for calendar year 2021, which demonstrated that each of the individual Ohio Companies did not have significantly excessive earnings.

On July 15, 2022, the Ohio Companies filed an application with the PUCO for approval of phase two of their distribution grid modernization plan that would, among other things, provide for the installation of an additional 700 thousand smart meters, distribution automation equipment on approximately 240 distribution circuits, voltage regulating equipment on approximately 220 distribution circuits, and other investments and pilot programs in related technologies designed to provide enhanced customer benefits. The Ohio Companies propose that phase two will be implemented over a four-year budget period with estimated capital investments of approximately $626 million and operations and maintenance expenses of approximately $144 million over the deployment period. Under the proposal, costs of phase two of the grid modernization plan would be recovered through the Ohio Companies’ AMI rider, pursuant to the terms and conditions approved in ESP IV. Hearings are scheduled to commence on October 24, 2023.

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. Final comments and responses were filed by parties during the second quarter of 2022.

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 May 4, 2022, the PUCO selected 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.

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.

On August 16, 2022, the U.S. Attorney for the Southern District of Ohio requested that the PUCO stay the above pending HB 6- related matters for a period of six months, which request was granted by the PUCO on August 24, 2022. Unless otherwise ordered by the PUCO, the four cases are stayed in their entirety, including discovery and motions, and all related procedural schedules are vacated. On February 22, 2023, the U.S. Attorney for the Southern District of Ohio again requested that the PUCO stay the above pending HB-6 related matters for a period of six months, which request was granted by the PUCO on March 8, 2023. A rehearing request with respect to the granting of the additional stay is currently pending before the PUCO.

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 to provide for refunds in the event such provisions of HB 6 are repealed. Neither the Ohio Companies nor FE benefit from the OVEC-related charges the Ohio Companies collect. Instead, the Ohio Companies are further required by HB 6 to remit all the OVEC-related charges they collect to non-FE Ohio electric distribution utilities. The Ohio Companies contested the motions, which are pending before the PUCO.

On May 15, 2023, the Ohio Companies filed their application for determination of the existence of SEET under ESP IV for calendar year 2022, which demonstrated that each of the individual Ohio Companies did not have significantly excessive earnings.

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 on April 20, 2022, the parties filed a partial settlement with the PPUC resolving certain of the issues in the proceeding and setting aside the remainder of the issues to be resolved through briefing. The PPUC approved the partial settlement, without modification, on August 4, 2022. 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.

Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, the Pennsylvania Companies implemented energy efficiency and peak demand reduction programs with 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.

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 Office of Consumer Advocate 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, which was approved by the PPUC without modification on April 14, 2022.

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 accumulated deferred income taxes and state taxes. The PPUC issued the order as directed.

On March 6, 2023, FirstEnergy filed applications with the PPUC, NYPSC and FERC seeking approval to consolidate the Pennsylvania Companies into a new, single operating entity. The PA Consolidation includes, among other steps: (a) the transfer of certain Pennsylvania-based transmission assets owned by WP to KATCo, (b) the contribution of Class B equity interests of MAIT currently held by PN and ME to FE (and ultimately transferred to FET as part of the FET Minority Equity Interest Sale), (c) the formation of FE PA and (d) the merger of each of the Pennsylvania Companies with and into FE PA, with FE PA surviving such mergers as the successor-in-interest to all assets and liabilities of the Pennsylvania Companies. Following completion of the PA Consolidation, FE PA will be FE’s only regulated utility in Pennsylvania encompassing the retail utility operations previously conducted individually by the Pennsylvania Companies. Consummation of the PA Consolidation is contingent upon numerous conditions, including the approval of NYPSC, PPUC and FERC. On April 25, 2023, the PPUC’s presiding officers held a prehearing conference, which, among other things, set evidentiary hearings on August 10 and 11, 2023. On March 27, 2023, a protest was filed in the FERC proceeding to which the Pennsylvania Companies responded. FERC is required to act on the Pennsylvania Companies’ application by September 1, 2023. Subject to receipt of all regulatory approvals, FirstEnergy expects that the PA Consolidation will close by early 2024.

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 August 25, 2022, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates of $183.8 million beginning January 1, 2023, which represents a 12.2% increase to the rates then in effect. The increase was driven by an underrecovery during the review period (July 1, 2021, to June 30, 2022) of approximately $145 million due to higher coal, reagent, and emission allowance expenses. This filing additionally addresses, among other things, the WVPSC’s May 2022 request for a prudence review of current rates. At a hearing on December 8, 2022, the parties in the case presented a unanimous settlement to increase rates by approximately $92 million, effective January 1, 2023, and carry over to MP and PE’s 2023 ENEC case, approximately $92 million at a carrying charge of 4%. In an order dated December 30, 2022, the WVPSC approved the settlement with respect to the proposed rate increase, but MP and PE rates remain subject to a prudence review in their 2023 ENEC case. The order also instructed MP to evaluate the feasibility of purchasing the 1,200 MW Pleasants Power Station and file a summary of the evaluation, which MP and PE filed on March 31, 2023. Among other things, the filing by MP and PE, noted that the final analysis to determine if the proposed transaction would be in the best interests of MP, PE and their customers would not be complete before the currently scheduled date for Pleasants Power Station to close, proposed an interim solution to preserve Pleasants’ operations while MP and PE completed their analysis, and outlined certain WVPSC actions needed to facilitate the interim solution, including a temporary surcharge for costs to preserve its operations. Based on the WVPSC procedural order, comments were filed on April 14, 2023, a public hearing was held on April 20, 2023, and an evidentiary hearing occurred on April 21, 2023. On April 24, 2023, the WVPSC issued an order approving MP and PE’s interim solution request, authorizing negotiations with the owner of Pleasants for a letter of intent, the terms of which will provide, among other things, for the reimbursement of certain expenses necessary to keep Pleasants in operating condition, and directing MP and PE to file the letter of intent for approval with the WVPSC. Once approved, MP and PE expected to establish a surcharge to recover the costs incurred under the letter of intent. At the request of the WVPSC, MP and PE filed a status report on May 24, 2023, regarding the ongoing negotiations and MP and PE’s analysis. Subsequently, the owner of Pleasants entered into an agreement to sell Pleasants to an indirect wholly owned subsidiary of Omnis Global Technologies, LLC, which FERC approved on July 24, 2023. As a result, MP and PE are no longer reviewing the possible purchase of Pleasants and will update the WVPSC upon the completion of the sale to the Omnis subsidiary.

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 through a surcharge for any solar investment not fully subscribed by their customers. A hearing was held in mid-March 2022 and on April 21, 2022, the WVPSC issued an order approving, effective May 1, 2022, the requested tariff and requiring MP and PE to subscribe at least 85% of the planned 50 MWs before seeking final tariff approval. MP and PE must seek separate approval from the WVPSC to recover any solar generation costs in excess of the approved tariff. On April 24, 2023, MP and PE sought final tariff approval from the WVPSC for three of the five solar sites, representing 30 MWs of generation, and requested approval of a surcharge to recover any costs above the final approved tariff. The first solar generation site is expected to be in-service by the end of 2023 and all construction completed at the other sites no later than the end of 2025 at a total investment cost of approximately $110 million.

On January 13, 2023, MP and PE filed a request with the WVPSC seeking approval of new depreciation rates for existing and future capital assets. Specifically, MP and PE are seeking to increase depreciation expense by approximately $76 million per year, primarily for regulated generation-related assets. Any depreciation rates approved by the WVPSC would not become effective until new base rates were established. Staff filed testimony recommending a $33.4 million increase and Consumer Advocate recommended a $300 thousand increase. Evidentiary hearings have been set for late August 2023.

On March 2, 2023, the WVPSC ordered an audit of MP and PE focused on (i) the lobbying and promotional/image building expenses, including those related to HB 6, incurred by MP and PE from 2018 to 2022 (ii) intra-corporate charges, (iii) the accounting for charges included in the ENEC cost recovery accounts of MP and PE during the same time period, and (iv) review and report on the findings, including those specific to MP and PE, set forth in the FERC Audit described below as well as a review and report of the responses by MP and PE thereto. The audit is expected to begin in August 2023 and conclude by year-end with the findings incorporated into the base rate case currently pending before the WVPSC.

On May 31, 2023, MP and PE filed a base rate case with the WVPSC requesting a total revenue increase of approximately $207 million utilizing a test year of 2022 with adjustments plus a request to establish a regulatory asset (or liability) to recover (or refund) in a subsequent base rate case the net differences between the amount of pension and OPEB expense requested in the proceeding (based on average expense from 2018 to 2022) and the actual annual amount each year using the delayed recognition method. Among other things, the increase includes the approximate $76 million requested in a depreciation case filed on January 13, 2023 and described more fully above, and amounts to support a new low-income customer advocacy program, storm restoration work and service reliability investments. New rates are expected to be effective March 2024. A hearing has been set for late January 2024.

FERC REGULATORY MATTERS

Under the Federal Power Act, FERC regulates rates for interstate wholesale sales and transmission of electric power, regulatory accounting and reporting under the Uniform System of Accounts, 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 Electric Reliability Organization 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 that FirstEnergy has accepted. The audit report included a finding and related recommendation on FirstEnergy’s methodology for allocation of certain corporate support costs to regulatory capital accounts under certain FERC regulations and reporting. Effective in the first quarter of 2022 and in response to the finding, FirstEnergy had implemented a new methodology for the allocation of these corporate support costs to regulatory capital accounts for its regulated distribution and transmission companies on a prospective basis. With the assistance of an independent outside firm, FirstEnergy completed an analysis during the third quarter of 2022 of these costs and how it impacted certain FERC-jurisdictional wholesale transmission customer rates for the audit period of 2015 through 2021. As a result of this analysis, FirstEnergy recorded in the third quarter of 2022 approximately $45 million ($34 million after-tax) in expected customer refunds, plus interest, due to its wholesale transmission customers and reclassified approximately $195 million of certain transmission capital assets to operating expenses for the audit period, of which $90 million ($67 million after-tax) are not expected to be recoverable and impacted FirstEnergy’s earnings since they relate to costs capitalized during stated transmission rate time periods. These reclassifications also resulted in a reduction to the Regulated Transmission segment’s rate base by approximately $160 million, which is not expected to materially impact FirstEnergy or the segment’s future earnings. The expected wholesale transmission customer refunds were recognized as a reduction to revenue, and the amount of reclassified transmission capital assets that are not expected to be recoverable were recognized within “Other operating expenses” at the Regulated Transmission segment and on FirstEnergy’s Consolidated Statements of Income.

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. On December 15, 2022, FERC denied the complaint as to ATSI and Duke, but granted it as to AEP. AEP and OCC appealed FERC’s orders to the Sixth Circuit. FirstEnergy is actively participating in the appeal and the

case remains pending. FirstEnergy is unable to predict the outcome of this proceeding, but it is not expected to have a material impact.

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 the Edison Electric Institute 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's 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 filed uncontested settlement agreements with FERC on January 18, 2023. Also on January 18, 2023, MP, PE and WP filed a motion for interim rates to implement certain aspects of the settled rate. The interim rates were approved by the FERC Chief Administrative Law Judge and took effect on January 1, 2023. As a result of the filed settlement, FirstEnergy recognized a $25 million pre-tax charge during the fourth quarter of 2022, which reflects the difference between amounts originally recorded as assets and amounts which will ultimately be recovered from customers as a result. On May 4, 2023, FERC issued an order approving the settlement agreement without condition or modification. Pursuant to the order, a compliance filing was filed on May 19, 2023, that implemented the terms of the settlement. On June 26, 2023, FERC issued a letter order approving the compliance filing.

Sale of Equity Interest in FirstEnergy Transmission, LLC

On May 5, 2023, FirstEnergy and Brookfield submitted applications to FERC and to the PPUC to facilitate the FET Minority Equity Interest Sale. On May 12, 2023, the parties also filed an application with the VSCC, which was approved on June 20, 2023. The parties also must obtain successful review of the transaction by the federal CFIUS.

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 LOCs, 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 June 30, 2023, outstanding guarantees and other assurances aggregated $796 million, consisting of parental guarantees on behalf of its consolidated subsidiaries ($510 million) and other assurances ($286 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 June 30, 2023, $66 million of net cash 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. FE or its subsidiaries are holding $33 million of net cash collateral as of June 30, 2023, from certain generation suppliers, and such amount is included in “Other current liabilities” 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 June 30, 2023:


Potential Collateral Obligations		Utilities and Transmission Companies		FE		Total
	(In millions)
Contractual Obligations for Additional Collateral

Upon Further Downgrade		$	62	$	—	$	62

Surety Bonds (Collateralized Amount) (1)		67		79		146
Total Exposure from Contractual Obligations		$	129	$	79	$	208

(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. During the second quarter of 2023, FE was released from its $169 million surety bond to the Pennsylvania Department of Environmental Protection related to the Little Blue Run Disposal Impoundment.

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 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 National Ambient Air Quality Standards. 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 addressed, 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 upwind states, including West Virginia, with the stated purpose of allowing downwind states to attain or maintain compliance with the 2015 ozone National Ambient Air Quality Standards. On February 13, 2023, the EPA disapproved 21 SIPs, which was a prerequisite for the EPA to issue a final Good Neighbor Plan or FIP. On June 5, 2023, the EPA issued the final Good Neighbor Plan with an effective date 60 days thereafter. Certain states, including West Virginia, have appealed the disapprovals of their respective SIPs, and some of those states have obtained stays of those disapprovals precluding the Good Neighbor Plan from taking effect in those states. West Virginia filed its Motion to Stay the disapproval of its SIP on July 18, 2023, and is awaiting a decision. In addition, certain states including West Virginia, and certain trade organizations, including the Midwest Ozone Group of which FE is a member, have separately appealed the Good Neighbor Plan itself, with more appeals expected. Unless either the West Virginia SIP disapproval or the FIP is successfully stayed, the Good Neighbor Plan will be effective in West

Virginia in early August 2023, which could cause MP to accelerate certain of its planned capital expenditures to comply with the new rule.

Climate Change

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. There are several initiatives to reduce GHG emissions at the state, federal and international level. Certain northeastern states are participating in the Regional Greenhouse Gas Initiative 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.

FirstEnergy has pledged to achieve carbon neutrality by 2050 and set an interim goal for a 30% reduction in GHGs within FirstEnergy’s direct operational control (Scope 1) by 2030, based on 2019 levels. 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 subject to the West Virginia legislation effective March 7, 2023, which requires prior approval from the West Virginia Public Energy Authority to decommission MP’s generating facilities. FirstEnergy will work collaboratively with regulators in West Virginia to achieve its climate goals. 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. Vacating the ACE rule had the unintended effect of reinstating the CPP because the repeal of the CPP was a provision within the ACE rule. The D.C. Circuit decision was appealed by several states and interested parties, including West Virginia, arguing that the EPA did not have the authorization under Section 111(d) of the CAA to require “generation shifting” as a way to limit GHGs. On June 30, 2022, the U.S. Supreme Court in West Virginia v. Environmental Protection Agency held that the method the EPA used to regulate GHGs (generation shifting) under Section 111(d) of the CAA (the CPP) was not authorized by Congress and remanded the rule to the EPA for further reconsideration. In response, on May 23, 2023, the EPA published a proposed rule pursuant to CAA Section 111 (b) and (d) in line with the decision in West Virginia v. Environmental Protection Agency intended to reduce power sector GHG emissions (primarily CO2 emissions) from fossil fuel based EGUs. The rule proposes stringent emissions limitations based on fuel type and unit retirement date. Comments on the proposed rule are due to the EPA on or before August 8, 2023. Depending on how final rules are ultimately implemented and the outcome of any appeals, compliance with these standards could require additional capital expenditures or changes in operation at the Ft. Martin and Harrison power stations.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal Clean Water Act 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. On March 29, 2023, the EPA published proposed revised ELGs applicable to coal-fired power plants that include more stringent effluent limitations for wet scrubber systems and ash transport water, and new limits on landfill leachate. Public hearings on the proposed rules were held in April 2023 and comments were accepted through May 30, 2023. In the interim, the rule issued on August 31, 2020, remains in effect. Depending on the outcome of appeals and how final revised rules are ultimately implemented, compliance with these standards could require additional capital expenditures or changes in operation at the Ft. Martin and Harrison power stations from what was approved by the WVPSC in September 2022 to comply with the 2020 ELG rule.

Regulation of Waste Disposal

Federal and state hazardous waste regulations have been promulgated as a result of the Resource Conservation and Recovery Act, 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 identified site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to extend the cease accepting waste date for the 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 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 June 30, 2023, 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 $96 million have been accrued through June 30, 2023, of which, approximately $62 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 societal benefits charge. 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. In March 2023, a jury found Mr. Householder and his co-defendant, Matthew Borges, guilty and in June 2023, the two were sentenced to prison for 20 and 5 years, respectively. Messrs. Householder and Borges have appealed their sentences. Also, on July 21, 2020, and in connection with the DOJ’s investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s Office for the Southern District 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, July 11, 2022, and May 25, 2023, the SEC issued additional subpoenas to FE, with which FE has complied. 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.

On June 29, 2023, the OOCIC served FE a subpoena, seeking information relating to the conduct described in the DPA. FirstEnergy was not aware of the OOCIC’s investigation prior to receiving the subpoena and understands that the OOCIC’s investigation is also focused on the conduct described in the DPA. FirstEnergy is cooperating with the OOCIC in its investigation. No contingency has been reflected in FirstEnergy’s consolidated financial statements, as a loss is neither probable, nor is a loss or range of loss reasonably estimable.

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 (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. On March 30, 2023, the court granted plaintiffs’ motion for class certification. On April 14, 2023, FE filed a petition in the U.S. Court of Appeals for the Sixth Circuit seeking to appeal that order. Discovery is ongoing. 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. (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, each alleging civil violations of the Ohio Corrupt Activity Act and related claims 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 (Conservation Support Rider) 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. On August 13, 2021, new defendants were added to the complaint, including two former officers of FirstEnergy. On December 2, 2021, the cities and FE entered a stipulated dismissal with prejudice of the cities’ suit. After a stay, pending final resolution of the United States v. Larry Householder, et al. criminal

proceeding described above, the litigation has resumed pursuant to an order, dated March 15, 2023. Discovery is ongoing.

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, Ohio, 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 current and former FE directors and officers, alleging, among other things, breaches of fiduciary duty.
Miller v. Anderson, et al. (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. (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, which the S.D. Ohio granted on May 9, 2022. Subsequently, following a hearing on August 4, 2022, the S.D. Ohio granted final approval of the settlement on August 24, 2022. The settlement agreement is expected to resolve fully these shareholder derivative lawsuits and included a series of corporate governance enhancements.

The settlement also includes a payment to FE of $180 million, to be paid by insurance after the judgment has become final, less approximately $36 million in court-ordered attorney’s fees awarded to plaintiffs. On September 20, 2022, a purported FE stockholder filed a motion for reconsideration of the S.D. Ohio’s final settlement approval. The parties filed oppositions to that motion on October 11, 2022, and the S.D. Ohio denied that motion on May 22, 2023. On June 15, 2023, the purported FE stockholder filed an appeal in the U.S. Court of Appeals for the Sixth Circuit. The N.D. Ohio matter remains pending. On June 2, 2022, the N.D. Ohio entered an order to show cause why the court should not appoint new plaintiffs’ counsel, and thereafter, on June 10, 2022, the parties filed a joint motion to dismiss the matter without prejudice, which the N.D. Ohio denied on July 5, 2022. On August 15, 2022, the N.D. Ohio issued an order stating its intention to appoint one group of applicants as new plaintiffs’ counsel, and on August 22, 2022, the N.D. Ohio ordered that any objections to the appointment be submitted by August 26, 2022. The parties filed their objections by that deadline, and on September 2, 2022, the applicants responded to those objections. In the meantime, on August 25, 2022, a purported FE stockholder represented by the applicants filed a motion to intervene, attaching a proposed complaint-in-intervention purporting to assert claims that the FE Board and officers breached their fiduciary duties and committed violations of Section 14(a) of the Exchange Act as well as a claim against a third party for professional negligence and malpractice. The parties filed oppositions to that motion to intervene on September 8, 2022, and the proposed intervenor's reply in support of his motion to intervene was filed on September 22, 2022.

On August 24, 2022, the parties filed a joint motion to dismiss the action pending in the N.D. Ohio based upon and in light of the approval of the settlement by the S.D. Ohio. On August 30, 2022, the parties filed a joint motion to dismiss the state court action, which the court granted on September 2, 2022.

In letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that the Division was 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. On December 30, 2022, FERC approved a Stipulation and Consent Agreement that resolves the investigation. The agreement includes a FirstEnergy admission of violating FERC’s “duty of candor” rule and related laws, and obligates FirstEnergy to pay a civil penalty of $3.86 million, and to submit two annual compliance monitoring reports to FERC’s Office of Enforcement regarding improvements to FirstEnergy’s compliance programs. FE paid the civil penalty on January 4, 2023 and it will not be recovered from customers.

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. FirstEnergy evaluates segment performance based on Earnings attributable to FE.

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 provider of last resort, SOS, standard service offer 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 I, 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 would own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion. The transaction closed on May 31, 2022. KATCo, which was a subsidiary of FET, became a wholly owned subsidiary of FE prior to the closing of the FET P&SA I and remains in the Regulated Transmission segment.

On February 2, 2023, FE, along with FET, entered into the FET P&SA II with Brookfield and the Brookfield Guarantors, pursuant to which FE agreed to sell to Brookfield at the closing, and Brookfield agreed to purchase from FE, an incremental 30% equity interest in FET for a purchase price of $3.5 billion. The purchase price will be payable in part by the issuance of a promissory note expected to be in the principal amount of $1.75 billion. The remaining $1.75 billion of the purchase price will be payable in cash at the closing. As a result of the consummation of the transaction, Brookfield’s interest in FET will increase from 19.9% to 49.9%, while FE will retain the remaining 50.1% ownership interests of FET. The transaction is subject to customary closing conditions, including approval from FERC and certain state utility commissions, and completion of review by the CFIUS. In addition, pursuant to the FET P&SA II, FirstEnergy has agreed to make the necessary filings with the applicable regulatory authorities for the PA Consolidation. The FET Minority Equity Interest Sale is expected to close by early 2024. Upon closing, FET will continue to be consolidated in FirstEnergy’s GAAP financial statements.

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 former subsidiaries, interest expense on FE’s holding company debt and other investments or businesses that do not constitute an operating segment, including FEV’s investment of 33-1/3% equity ownership in Global Holding. Reconciling adjustments for the elimination of inter-segment transactions are shown separately in the following table of Segment Financial Information. As of June 30, 2023, 67 MWs of electric generating capacity, representing AE Supply’s OVEC capacity entitlement, was also included in Corporate/Other for segment reporting. As of June 30, 2023, Corporate/Other had approximately $6.8 billion of FE holding company debt.

Financial information for FirstEnergy’s business segments and reconciliations to consolidated amounts is presented below:


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2023		2022		2023		2022

External revenues
Regulated Distribution	$	2,484	$	2,370	$	5,253	$	4,902
Regulated Transmission	519		440		979		891
Corporate/Other	3		8		5		14
Reconciling Adjustments	—		—		—		—
Total external revenues	$	3,006	$	2,818	$	6,237	$	5,807

Internal revenues
Regulated Distribution	$	58	$	56	$	115	$	113
Regulated Transmission	1		1		2		3
Corporate/Other	—		—		—		—
Reconciling Adjustments	(59)		(57)		(117)		(116)
Total internal revenues	$	—	$	—	$	—	$	—

Total revenues	$	3,006	$	2,818	$	6,237	$	5,807





Depreciation
Regulated Distribution	$	255	$	242	$	506	$	477
Regulated Transmission	88		87		179		173
Corporate/Other	1		1		3		3
Reconciling Adjustments	17		18		34		35
Total depreciation	$	361	$	348	$	722	$	688

Amortization (deferral) of regulatory assets, net
Regulated Distribution	$	(34)	$	(127)	$	(113)	$	(165)
Regulated Transmission	1		(2)		—		(1)
Corporate/Other	—		—		—		—
Reconciling Adjustments	—		—		—		—
Total amortization (deferral) of regulatory assets, net	$	(33)	$	(129)	$	(113)	$	(166)

Equity method investment earnings
Regulated Distribution	$	—	$	—	$	—	$	—
Regulated Transmission	—		—		—		—
Corporate/Other	35		65		91		77
Reconciling Adjustments	—		—		—		—
Total equity method investment earnings	$	35	$	65	$	91	$	77










Interest expense
Regulated Distribution	$	151	$	128	$	297	$	257
Regulated Transmission	61		55		120		114
Corporate/Other	82		88		157		177
Reconciling Adjustments	(18)		(6)		(35)		(8)
Total interest expense	$	276	$	265	$	539	$	540


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2023		2022		2023		2022
Income taxes (benefits)
Regulated Distribution	$	44	$	52	$	100	$	121
Regulated Transmission	46		39		86		80
Corporate/Other	(16)		(42)		(22)		(69)
Reconciling Adjustments	—		—		—		—
Total income taxes (benefits)	$	74	$	49	$	164	$	132



























Earnings attributable to FE
Regulated Distribution	$	177	$	202	$	413	$	467
Regulated Transmission	134		123		248		248
Corporate/Other	(76)		(138)		(134)		(240)
Reconciling Adjustments	—		—		—		—
Total earnings attributable to FE	$	235	$	187	$	527	$	475

Capital investments
Regulated Distribution	$	393	$	376	$	727	$	712
Regulated Transmission	365		267		673		464
Corporate/Other	11		4		18		10
Reconciling Adjustments	—		—		—		—
Total capital investments	$	769	$	647	$	1,418	$	1,186

(In millions)	As of June 30, 2023				As of December 31, 2022
Assets
Regulated Distribution	$	32,201			$	31,749
Regulated Transmission	14,199				13,835
Corporate/Other	665				524
Reconciling Adjustments	—				—
Total assets	$	47,065			$	46,108

Goodwill
Regulated Distribution	$	5,004			$	5,004
Regulated Transmission	614				614
Corporate/Other	—				—
Reconciling Adjustments	—				—
Total goodwill	$	5,618			$	5,618

Next: Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations