fe-20230630

Provision for depreciation

^[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

361

348

722

688

Debt redemption costs (Note 6)

(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):

(36)

(118)

(36)

(156)

Equity method investment earnings (Note 1)

Miscellaneous income, net

189

Pension and OPEB mark-to-market adjustment (Note 4)

Capitalized financing costs

(276)

(265)

(539)

(540)

Total other expense

(153)

(206)

(304)

(394)

INCOME BEFORE INCOME TAXES

328

241

728

612

INCOME TAXES

164

132

NET INCOME

254

192

564

480

Income attributable to noncontrolling interest

EARNINGS ATTRIBUTABLE TO FIRSTENERGY CORP.

$ 235

$ 187

$ 527

$ 475

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

Basic - Earnings Per Share Attributable to FirstEnergy Corp. (in dollars per share)

$ 0.41

$ 0.33

$ 0.92

$ 0.83

Diluted - Earnings Per Share Attributable to FirstEnergy Corp. (in dollars per share)

$ 0.41

$ 0.33

$ 0.92

$ 0.83

WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:

Basic (in shares)

573

571

573

571

Diluted (in shares)

574

572

574

572

Distribution Services and Retail Generation

REVENUES:

$ 2,375

$ 2,170

$ 5,055

$ 4,567

Transmission

REVENUES:

518

440

978

891

Other

REVENUES:

Revenue from Contract with Customer [Abstract]

$ 113

$ 208

$ 204

$ 349

[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.

XML 16 R3.htm IDEA: XBRL DOCUMENT

Consolidated Statements of Income (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Statement [Abstract]
Excise taxes collected	$ 92	$ 91	$ 201	$ 194

XML 17 R4.htm IDEA: XBRL DOCUMENT

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
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	0	1
Other comprehensive income (loss), net of tax	0	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

XML 18 R5.htm IDEA: XBRL DOCUMENT

Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
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
Receivable	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
Total current assets	2,485	2,415
PROPERTY, PLANT AND EQUIPMENT:
In service	48,963	47,850
Less — Accumulated provision for depreciation	13,671	13,258
Property, plant and equipment in service net of accumulated provision for depreciation	35,292	34,592
Construction work in progress	1,857	1,693
Total net property, plant and equipment	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
Total deferred charges and other assets	7,431	7,408
TOTAL ASSETS	47,065	46,108
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	0	223
Other	230	364
Total current liabilities	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
Total noncurrent liabilities	31,945	31,507
Liabilities	36,094	35,465
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
Customer
Receivables-
Customers	1,271	1,455
Less — Allowance for uncollectible customer receivables	85	137
Receivable	$ 1,186	$ 1,318

XML 19 R6.htm IDEA: XBRL DOCUMENT

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Receivables-
Allowance for uncollectible accounts	$ 85	$ 137
Common stock, par value (in dollars per share)	$ 0.10	$ 0.10
Common stock, authorized (in shares)	700,000,000	700,000,000
Common stock, outstanding (in shares)	573,362,380	572,130,932
Other
Receivables-
Allowance for uncollectible accounts	$ 15	$ 11

XML 20 R7.htm IDEA: XBRL DOCUMENT

Consolidated Statements of Equity - USD ($) $ in Millions	Total	Total Common Stockholders’ Equity	Common Stock	OPIC	AOCI	Accumulated Deficit	NCI
Beginning balance, (in shares) at Dec. 31, 2021			570,000,000
Beginning balance at Dec. 31, 2021	$ 8,675	$ 8,675	$ 57	$ 10,238	$ (15)	$ (1,605)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	288	288				288
Other comprehensive Income (loss), net of tax	(1)	(1)			(1)
Stock Investment Plan and share-based benefit plans (in shares)			1,000,000
Stock Investment Plan and share-based benefit plans	20	20		20
Cash dividends declared on common stock	(223)	(223)		(223)
Other	(4)	(4)		(4)
Ending balance (in shares) at Mar. 31, 2022			571,000,000
Ending balance at Mar. 31, 2022	8,755	8,755	$ 57	10,031	(16)	(1,317)	$ 0
Beginning balance, (in shares) at Dec. 31, 2021			570,000,000
Beginning balance at Dec. 31, 2021	8,675	8,675	$ 57	10,238	(15)	(1,605)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	480
Other comprehensive Income (loss), net of tax	3
Ending balance (in shares) at Jun. 30, 2022			571,000,000
Ending balance at Jun. 30, 2022	11,314	10,858	$ 57	11,943	(12)	(1,130)	456
Beginning balance, (in shares) at Mar. 31, 2022			571,000,000
Beginning balance at Mar. 31, 2022	8,755	8,755	$ 57	10,031	(16)	(1,317)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	192	187				187	5
Other comprehensive Income (loss), net of tax	4	4			4
Stock Investment Plan and share-based benefit plans	25	25
FET minority interest sale, net of transaction costs	2,338	1,887		1,887			451
Ending balance (in shares) at Jun. 30, 2022			571,000,000
Ending balance at Jun. 30, 2022	$ 11,314	10,858	$ 57	11,943	(12)	(1,130)	456
Beginning balance, (in shares) at Dec. 31, 2022	572,130,932		572,000,000
Beginning balance at Dec. 31, 2022	$ 10,643	10,166	$ 57	11,322	(14)	(1,199)	477
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	310	292				292	18
Other comprehensive Income (loss), net of tax	(1)	(1)			(1)
Stock Investment Plan and share-based benefit plans (in shares)			1,000,000
Stock Investment Plan and share-based benefit plans	19	19		19
Cash dividends declared on common stock	(223)	(223)		(223)
Distributions to FET minority interest	(17)	0					(17)
Ending balance (in shares) at Mar. 31, 2023			573,000,000
Ending balance at Mar. 31, 2023	$ 10,731	10,253	$ 57	11,118	(15)	(907)	478
Beginning balance, (in shares) at Dec. 31, 2022	572,130,932		572,000,000
Beginning balance at Dec. 31, 2022	$ 10,643	10,166	$ 57	11,322	(14)	(1,199)	477
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	564
Other comprehensive Income (loss), net of tax	$ (1)
Ending balance (in shares) at Jun. 30, 2023	573,362,380		573,000,000
Ending balance at Jun. 30, 2023	$ 10,971	10,510	$ 57	11,140	(15)	(672)	461
Beginning balance, (in shares) at Mar. 31, 2023			573,000,000
Beginning balance at Mar. 31, 2023	10,731	10,253	$ 57	11,118	(15)	(907)	478
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	254	235				235	19
Other comprehensive Income (loss), net of tax	0
Stock Investment Plan and share-based benefit plans (in shares)			0
Stock Investment Plan and share-based benefit plans	22	22		22
Distributions to FET minority interest	$ (36)	0					(36)
Ending balance (in shares) at Jun. 30, 2023	573,362,380		573,000,000
Ending balance at Jun. 30, 2023	$ 10,971	$ 10,510	$ 57	$ 11,140	$ (15)	$ (672)	$ 461

XML 21 R8.htm IDEA: XBRL DOCUMENT

Consolidated Statements of Equity (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Stockholders' Equity [Abstract]
Dividends declared (in dollars per share)	$ 0.39	$ 0.39

XML 22 R9.htm IDEA: XBRL DOCUMENT

Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 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)	0
Pension and OPEB mark-to-market adjustment	(59)	0
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)
New financing-
Long-term debt	2,600	0
Short-term borrowings, net	250	0
Redemptions and repayments-
Long-term debt	(515)	(2,745)
Proceeds from FET minority interest sale, net of transaction costs	0	2,348
Distributions to FET minority interest	(53)	0
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
Significant non-cash transactions:
Accrued capital investments	$ 143	$ 106

XML 23 R10.htm IDEA: XBRL DOCUMENT

ORGANIZATION AND BASIS OF PRESENTATION	6 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND BASIS OF PRESENTATION	ORGANIZATION AND BASIS OF PRESENTATION Unless otherwise indicated, defined terms and abbreviations used herein have the meanings set forth in the accompanying Glossary of Terms. FE was incorporated under Ohio law in 1996. FE’s principal business is the holding, directly or indirectly, of all of the outstanding equity of its principal subsidiaries: OE, CEI, TE, Penn (a wholly owned subsidiary of OE), JCP&L, ME, PN, FESC, MP, AGC (a wholly owned subsidiary of MP), PE 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.

XML 24 R11.htm IDEA: XBRL DOCUMENT

REVENUE

6 Months Ended

Jun. 30, 2023

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.

Customer Receivables


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

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.

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 9
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-9

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 10
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-10

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 15
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-15

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-13

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Name Accounting Standards Codification
-Topic 606
-Publisher FASB
-URI https://asc.fasb.org//606/tableOfContent

PENSION AND OTHER POST-EMPLOYMENT BENEFITS

XML 25 R12.htm IDEA: XBRL DOCUMENT

EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

EARNINGS PER SHARE

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

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

XML 26 R13.htm IDEA: XBRL DOCUMENT

PENSION AND OTHER POST-EMPLOYMENT BENEFITS

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

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.


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.

The entire disclosure for retirement benefits.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 70
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480794/715-70-50-1

Reference 2: http://www.xbrl.org/2003/role/exampleRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 55
-Paragraph 17
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480482/715-20-55-17

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (d)(iv)(03)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (d)(i)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (q)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (l)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org//715/tableOfContent

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (d)(iii)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (o)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (p)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (r)(1)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (r)(2)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480506/715-20-50-1

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480126/715-20-S99-2

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 60
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480266/715-60-50-3

XML 27 R14.htm IDEA: XBRL DOCUMENT

INCOME TAXES

6 Months Ended

Jun. 30, 2023

Income Tax Disclosure [Abstract]

INCOME TAXES


	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		%

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 13
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480990/946-20-50-13

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(h)(2))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480678/235-10-S99-1

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org//740/tableOfContent

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 14
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482685/740-10-50-14

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 21
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482685/740-10-50-21

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 270
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482526/740-270-50-1

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 17
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482685/740-10-50-17

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.5.Q1)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479360/740-10-S99-1

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Subparagraph (SAB Topic 11.C)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479360/740-10-S99-2

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 30
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482603/740-30-50-2

XML 28 R15.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

RECURRING FAIR VALUE MEASUREMENTS


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.


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

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.

(3) Primarily consists of short-term investments.

INVESTMENTS

Spent Nuclear Fuel Disposal Trusts


	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.














	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

LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS


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

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)

Unsecured Notes

March, 2023

3.50%

2023

$300

ME redeemed unsecured notes that became due.

Unsecured Notes

May, 2023

7.375%

2031

$194

Issuances

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.

Unsecured Notes

March, 2023

5.20%

2028

$425

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

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

•Upon the occurrence of certain corporate events specified in the indenture governing the 2026 Convertible Notes.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

Commitments and Contingencies Disclosure [Abstract]

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REGULATORY MATTERS	6 Months Ended
REGULATORY MATTERS	Jun. 30, 2023
Regulated Operations [Abstract]
REGULATORY MATTERS	REGULATORY MATTERS STATE REGULATION Each of the Utilities' retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE in Virginia, ATSI in Ohio, and the Transmission Companies in Pennsylvania are subject to certain regulations of the VSCC, PUCO and PPUC, respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new transmission facilities, depending on the state, they may be required to obtain state 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.

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COMMITMENTS, GUARANTEES AND CONTINGENCIES

6 Months Ended

Jun. 30, 2023

COMMITMENTS, GUARANTEES AND CONTINGENCIES

GUARANTEES AND OTHER ASSURANCES

COLLATERAL AND CONTINGENT-RELATED FEATURES


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

ENVIRONMENTAL MATTERS

Clean Air Act

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

Clean Water Act

Regulation of Waste Disposal

OTHER LEGAL PROCEEDINGS

United States v. Larry Householder, et al.

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.

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

Other Legal Matters

XML 31 R18.htm IDEA: XBRL DOCUMENT

SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

SEGMENT INFORMATION

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.

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

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pay vs Performance Disclosure
Earnings attributable to FE	$ 235	$ 187	$ 527	$ 475

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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-Name Accounting Standards Codification
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XML 33 R20.htm IDEA: XBRL DOCUMENT

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Jun. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

XML 34 R21.htm IDEA: XBRL DOCUMENT

ORGANIZATION AND BASIS OF PRESENTATION (Policies)	6 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION (Policies)	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting	These interim financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and disclosures normally included in financial statements and notes prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. These interim financial statements should be read in conjunction with the financial statements and notes included in the Annual Report on Form 10-K for the year ended December 31, 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.
Consolidation	FE and its subsidiaries consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. FE and its subsidiaries consolidate a 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.
New Accounting Pronouncements	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.
Customer Receivables	Customer Receivables Receivables from contracts with customers include distribution services and retail generation sales to residential, commercial and industrial customers of the Utilities. The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for credit losses. FirstEnergy reviews its allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Utilities are able to utilize to ensure payment. This analysis includes consideration of the outbreak of 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.
Earnings Per Share	Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised. Diluted EPS reflects the dilutive effect of potential common shares from share-based awards 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.
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.
Long-Term Debt and Other Long-Term Obligations	LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONSAll borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature, FirstEnergy believes that their costs approximate their fair market value.

Disclosure of accounting policy for investment in financial asset.

Revenue from Contract with Customer [Abstract]

XML 35 R22.htm IDEA: XBRL DOCUMENT

REVENUE (Tables)

6 Months Ended

Jun. 30, 2023

Schedule of Disaggregation of 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.

Schedule of Receivables from customers

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

Schedule of Activity in the allowance for uncollectible accounts on customer receivables

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.

XML 36 R23.htm IDEA: XBRL DOCUMENT

EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Schedule of Reconciliation of Basic and Diluted Earnings Per Share

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

XML 37 R24.htm IDEA: XBRL DOCUMENT

PENSION AND OTHER POST-EMPLOYMENT BENEFITS (Tables)

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

Schedule of Components of Net Periodic Benefit Costs

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.

Schedule of Assumptions Used to Determine Net Periodic Benefit Cost


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.

XML 38 R25.htm IDEA: XBRL DOCUMENT

INCOME TAXES (Tables)

6 Months Ended

Jun. 30, 2023

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation

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		%

XML 39 R26.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured on Recurring Basis

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.

(3) Primarily consists of short-term investments.

Schedule of Amortized Cost Basis, Unrealized Gains and Losses and Fair Values of Investments in Available-for-sale Securities


	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.

Schedule of Proceeds from the Sale of Investments in Available-for-sale Securities, Realized Gains and Losses on Those Sales, and Interest and Dividend Income














	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

Schedule of Fair Value and Related Carrying Amounts of Long-term Debt and Other Long-term Obligations


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

Schedule of Long-term Debt Redemption and Issuance

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)

Unsecured Notes

March, 2023

3.50%

2023

$300

ME redeemed unsecured notes that became due.

Unsecured Notes

May, 2023

7.375%

2031

$194

Issuances

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.

Unsecured Notes

March, 2023

5.20%

2028

$425

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

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.

Tabular disclosure of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale).

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Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

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Commitments and Contingencies Disclosure [Abstract]

XML 40 R27.htm IDEA: XBRL DOCUMENT

COMMITMENTS, GUARANTEES AND CONTINGENCIES (Tables)

6 Months Ended

Jun. 30, 2023

Schedule of Guarantor Obligations


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

XML 41 R28.htm IDEA: XBRL DOCUMENT

SEGMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

Schedule of Segment Financial Information

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

XML 42 R29.htm IDEA: XBRL DOCUMENT

ORGANIZATION AND BASIS OF PRESENTATION - Narrative (Details) mi in Thousands, customer in Millions, $ in Millions			3 Months Ended		6 Months Ended
	Feb. 02, 2023 USD ($) director	May 31, 2022 USD ($)	Jun. 30, 2023 USD ($) company transmissionCenter MW	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) company customer transmissionCenter mi MW	Jun. 30, 2022 USD ($)	Apr. 27, 2023 USD ($)	Dec. 31, 2022 USD ($)
Property, Plant and Equipment [Line Items]
Length of transmission lines \| mi					24
Number of regional transmission centers \| transmissionCenter			2		2
Capitalized cost of equity			$ 11	$ 11	$ 19	$ 24
Capitalized interest			11	6	24	12
Equity method investment earnings			$ 35	65	$ 91	77
Regulated Distribution
Property, Plant and Equipment [Line Items]
Number of existing utility operating companies \| company			10		10
Number of customers served by utility operating companies \| customer					6
Plant capacity (in MW's) \| MW			3,580		3,580
North American Transmission Company II LLC \| FET
Property, Plant and Equipment [Line Items]
Sale of ownership interest by parent	30.00%						30.00%
Noncontrolling interest, ownership percentage by noncontrolling owners	49.90%
Global Holding
Property, Plant and Equipment [Line Items]
Equity method investments			$ 56		$ 56			$ 57
FET \| FirstEnergy
Property, Plant and Equipment [Line Items]
Equity method investment, ownership percentage	50.10%
Other Sundry Investments
Property, Plant and Equipment [Line Items]
Equity method investments			93		93			90
Path Wv \| Variable Interest Entity, Not Primary Beneficiary
Property, Plant and Equipment [Line Items]
Equity method investments			$ 18		$ 18			$ 18
Percentage of high-voltage transmission line project owned by subsidiary of FE on the Allegheny Series			100.00%		100.00%
Percentage of high-voltage transmission line project owned by subsidiary of FE on the West Virginia Series			50.00%		50.00%
FET
Property, Plant and Equipment [Line Items]
Net of transaction costs		$ 37
Carrying value of the noncontrolling interest		$ 451
Number of directors \| director	5
FET \| FirstEnergy
Property, Plant and Equipment [Line Items]
Number of directors \| director	3
FET \| North American Transmission Company II LLC
Property, Plant and Equipment [Line Items]
Sale of ownership interest by parent		19.90%
Sale price of ownership interest by parent		$ 2,375
Disposal group, including discontinued operation, consideration	$ 3,500						$ 3,500
Business combination, consideration transferred, liabilities incurred	$ 1,750
Number of directors \| director	2
Minimum ownership interest	30.00%
FEV \| Global Holding
Property, Plant and Equipment [Line Items]
Investment ownership percentage			33.30%		33.30%
Proceeds from dividends received					$ 90	70
FEV \| Global Holding \| Corporate and Other \| Other Nonoperating Income (Expense)
Property, Plant and Equipment [Line Items]
Equity method investment earnings			$ 35	$ 64	$ 89	$ 76

XML 43 R30.htm IDEA: XBRL DOCUMENT

REVENUE - Schedule of Disaggregation of Revenue (Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

Operating Segments | Regulated Distribution

^[1]

$ 3,006

$ 2,818

$ 6,237

$ 5,807

2,514

2,403

5,310

4,961

Operating Segments | Regulated Distribution | Wholesale

2,542

2,426

5,368

5,015

Operating Segments | Regulated Distribution | Other Services

159

108

249

Operating Segments | Regulated Distribution | Product and Service, Other

Operating Segments | Regulated Transmission

518

440

978

891

Operating Segments | Regulated Transmission | Product and Service, Other

520

441

981

894

Operating Segments | Residential | Regulated Distribution

Operating Segments | Commercial | Regulated Distribution

1,414

1,310

3,116

2,852

Operating Segments | Industrial | Regulated Distribution

627

575

1,272

1,172

Operating Segments | Other | Regulated Distribution

353

312

706

595

Operating Segments | ATSI | Regulated Transmission

Operating Segments | TrAIL | Regulated Transmission

242

217

468

434

Operating Segments | MAIT | Regulated Transmission

131

127

Operating Segments | JCP&L | Regulated Transmission

188

156

Operating Segments | MP, PE and WP | Regulated Transmission

100

106

Corporate/Other and Reconciling Adjustments

Corporate/Other and Reconciling Adjustments | Wholesale

(56)

(49)

(112)

(102)

Corporate/Other and Reconciling Adjustments | Product and Service, Other

Corporate/Other and Reconciling Adjustments | Retail Generation and Distribution Services

(13)

(12)

(26)

$ (46)

$ (45)

$ (91)

$ (90)

[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.

XML 44 R31.htm IDEA: XBRL DOCUMENT

REVENUE - Narrative (Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

Incremental decrease to uncollectible expense due to Covid-19

^[1]

$ 3,006

$ 2,818

$ 6,237

$ 5,807

Deferred Regulatory Assets

Incremental decrease to uncollectible expense due to Covid-19

Other Non-Customer Revenue | Derivative revenue

Late payment charges

$ 6

$ 2

$ 12

$ 11

[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.

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

XML 45 R32.htm IDEA: XBRL DOCUMENT

REVENUE - Receivables from Customers (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Accounts, Notes, Loans and Financing Receivable [Line Items]
Customers	$ 1,271	$ 1,455
Less: Uncollectible Reserve	85	137
Receivable	1,186	1,318
Billed Revenues
Accounts, Notes, Loans and Financing Receivable [Line Items]
Customers	625	674
Unbilled Revenues
Accounts, Notes, Loans and Financing Receivable [Line Items]
Customers	$ 646	$ 781

XML 46 R33.htm IDEA: XBRL DOCUMENT

REVENUE - Activity in Uncollectable Accounts (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 137	$ 159
Provision for expected credit losses	(12)	59
Charged to other accounts	18	62
Write-offs	(58)	(143)
Ending balance	85	137
Deferred (refunded to customer) for recovery	$ (13)	$ 11

XML 47 R34.htm IDEA: XBRL DOCUMENT

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Earnings Per Share [Abstract]
Earnings attributable to FE	$ 235	$ 187	$ 527	$ 475
Share count information:
Weighted average number of basic shares outstanding (in shares)	573	571	573	571
Assumed exercise of dilutive stock options and awards (in shares)	1	1	1	1
Weighted average number of diluted shares outstanding	574	572	574	572
EPS attributable to FE:
Basic EPS (in dollars per share)	$ 0.41	$ 0.33	$ 0.92	$ 0.83
Diluted EPS (in dollars per share)	$ 0.41	$ 0.33	$ 0.92	$ 0.83

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

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The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

XML 48 R35.htm IDEA: XBRL DOCUMENT

EARNINGS PER SHARE - Narrative (Details) - shares shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Stock Options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of EPS (in shares)	0	0	0	0

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PENSION AND OTHER POST-EMPLOYMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and OPEB prior service costs amortized out of AOCI				$ 1
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service costs	$ 35	$ 46	$ 69	92
Interest costs	107	68	216	136
Expected return on plan assets	(142)	(164)	(270)	(328)
Amortization of prior service costs (credits)	1	0	1	1
Special termination benefits	5	0	5	0
Pension and OPEB mark-to-market adjustment	(59)	0	(59)	0
Net periodic benefit credits	(53)	(50)	(38)	(99)
Net periodic benefit credits, net of amounts capitalized	(70)	(72)	(73)	(141)
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service costs	0	1	1	2
Interest costs	6	2	11	5
Expected return on plan assets	(8)	(10)	(16)	(20)
Amortization of prior service costs (credits)	(2)	(2)	(4)	(5)
Special termination benefits	2	0	2	0
Pension and OPEB mark-to-market adjustment	0	0	0	0
Net periodic benefit credits	(2)	(9)	(6)	(18)
Net periodic benefit credits, net of amounts capitalized	$ (3)	$ (10)	$ (7)	$ (19)

XML 50 R37.htm IDEA: XBRL DOCUMENT

PENSION AND OTHER POST-EMPLOYMENT BENEFITS - Narrative (Details) $ in Millions				3 Months Ended		6 Months Ended		12 Months Ended
	May 12, 2023 USD ($)	Apr. 30, 2023	Dec. 31, 2022	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2023	May 09, 2023 employee
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Percent of eligible employees that accepted the voluntary retirement program									0.65
Number of employees \| employee									450
Number of separated employees \| employee									90
Defined benefit plan, assumptions used calculating benefit obligation, increase (decrease) in discount rate				0.29%
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary cash contribution	$ 750
Discount rate		4.94%	5.23%
Pension and OPEB mark-to-market adjustment				$ (59)	$ 0	$ (59)	$ 0
Voluntary contribution, percentage		7.70%
Estimated return		2.67%				800.00%
Pension \| Forecast
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate								8.00%
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate			5.16%
Pension and OPEB mark-to-market adjustment				0	$ 0	$ 0	$ 0
Estimated return						7.00%
Pension Mark-to-market Adjustment
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost, pre-tax				$ 47

XML 51 R38.htm IDEA: XBRL DOCUMENT

PENSION AND OTHER POST-EMPLOYMENT BENEFITS - Assumptions Used to Determine Net Periodic Benefit Cost (Details)			6 Months Ended
	Apr. 30, 2023	Dec. 31, 2022	Jun. 30, 2023
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate	4.94%	5.23%
Expected rate of return on plan assets	2.67%		800.00%
Pension \| Interest Cost on Benefit Obligations \| Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.10%
Pension \| Interest Cost on Benefit Obligations \| Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			4.80%
Pension \| Service Cost \| Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.34%
Pension \| Service Cost \| Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.11%
Pension \| Interest Cost \| Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.22%
Pension \| Interest Cost \| Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			4.94%
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate		5.16%
Expected rate of return on plan assets			7.00%
OPEB \| Interest Cost on Benefit Obligations
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.06%
OPEB \| Service Cost
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.41%
OPEB \| Interest Cost
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted-average discount rate			5.33%

XML 52 R39.htm IDEA: XBRL DOCUMENT

INCOME TAXES - Reconciliation of Federal Income Tax Expense (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Tax Disclosure [Abstract]
Income before income taxes	$ 328	$ 241	$ 728	$ 612
Income before income taxes			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	0	0	0	34
Remeasurement of state deferred taxes	0	0	0	(26)
Other, net	6	3	9	(4)
Total income taxes	$ 74	$ 49	$ 164	$ 132
Effective income tax rate	22.60%	20.30%	22.50%	21.60%

XML 53 R40.htm IDEA: XBRL DOCUMENT

INCOME TAXES - Narrative (Details) - USD ($) $ in Millions	1 Months Ended
INCOME TAXES - Narrative (Details) - USD ($) $ in Millions	Apr. 30, 2023	Jun. 30, 2023	Mar. 31, 2023
Income Tax Disclosure [Abstract]
Unrecognized tax benefits, portion expected to be resolved in the next fiscal year		$ 25
Unrecognized tax benefits that would impact effective tax rate		$ 24
Deferred tax assets			$ 9
Estimated AMT paid	$ 49

XML 54 R41.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS - Recurring Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Liabilities
Restricted cash	$ 43	$ 46
Recurring
Assets
Fair value, assets	536	525
Liabilities
Fair value, liabilities	(5)	(2)
Net assets	531	523
Recurring \| FTRs \| Derivative Liabilities
Liabilities
Fair value, liabilities	(5)	(2)
Recurring \| FTRs \| Derivative Assets
Assets
Fair value, assets	10	11
Recurring \| Equity securities
Assets
Fair value, assets	2	2
Recurring \| U.S. state debt securities
Assets
Fair value, assets	269	266
Recurring \| Cash, cash equivalents and restricted cash
Assets
Fair value, assets	214	206
Recurring \| Other
Assets
Fair value, assets	41	40
Recurring \| Level 1
Assets
Fair value, assets	216	208
Liabilities
Fair value, liabilities	0	0
Net assets	216	208
Recurring \| Level 1 \| FTRs \| Derivative Liabilities
Liabilities
Fair value, liabilities	0	0
Recurring \| Level 1 \| FTRs \| Derivative Assets
Assets
Fair value, assets	0	0
Recurring \| Level 1 \| Equity securities
Assets
Fair value, assets	2	2
Recurring \| Level 1 \| U.S. state debt securities
Assets
Fair value, assets	0	0
Recurring \| Level 1 \| Cash, cash equivalents and restricted cash
Assets
Fair value, assets	214	206
Recurring \| Level 1 \| Other
Assets
Fair value, assets	0	0
Recurring \| Level 2
Assets
Fair value, assets	310	306
Liabilities
Fair value, liabilities	0	0
Net assets	310	306
Recurring \| Level 2 \| FTRs \| Derivative Liabilities
Liabilities
Fair value, liabilities	0	0
Recurring \| Level 2 \| FTRs \| Derivative Assets
Assets
Fair value, assets	0	0
Recurring \| Level 2 \| Equity securities
Assets
Fair value, assets	0	0
Recurring \| Level 2 \| U.S. state debt securities
Assets
Fair value, assets	269	266
Recurring \| Level 2 \| Cash, cash equivalents and restricted cash
Assets
Fair value, assets	0	0
Recurring \| Level 2 \| Other
Assets
Fair value, assets	41	40
Recurring \| Level 3
Assets
Fair value, assets	10	11
Liabilities
Fair value, liabilities	(5)	(2)
Net assets	5	9
Recurring \| Level 3 \| FTRs \| Derivative Liabilities
Liabilities
Fair value, liabilities	(5)	(2)
Recurring \| Level 3 \| FTRs \| Derivative Assets
Assets
Fair value, assets	10	11
Recurring \| Level 3 \| Equity securities
Assets
Fair value, assets	0	0
Recurring \| Level 3 \| U.S. state debt securities
Assets
Fair value, assets	0	0
Recurring \| Level 3 \| Cash, cash equivalents and restricted cash
Assets
Fair value, assets	0	0
Recurring \| Level 3 \| Other
Assets
Fair value, assets	$ 0	$ 0

XML 55 R42.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS - Investments Held in Trusts (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Short-term cash investments	$ 5	$ 5
Debt securities
Debt Securities, Available-for-sale [Line Items]
Cost Basis	298	294
Unrealized Gains	0	0
Unrealized Losses	(29)	(28)
Fair Value	$ 269	$ 266

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (aa)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (aaa)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

XML 56 R43.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS - Proceeds from the Sale of Investments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Proceeds from the sale of investments in available-for-sale securities, realized gains and losses on those sales, and interest and dividend income
Sale proceeds	$ 17	$ 10	$ 18	$ 16
Realized gains	0	1	0	1
Realized losses	(1)	(1)	(2)	(2)
Interest and dividend income	$ 3	$ 3	$ 6	$ 6

XML 57 R44.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS - Narrative (Details) $ / shares in Units, $ in Millions			3 Months Ended		6 Months Ended
	May 04, 2023 USD ($) tradingDay	May 01, 2023	Jun. 30, 2023 USD ($) $ / shares	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) $ / shares	Jun. 30, 2022 USD ($)	Apr. 30, 2023	Dec. 31, 2022 USD ($)
Fair Value of Financial Instruments [Line Items]
Investments not required to be disclosed \| $			$ 364		$ 364			$ 351
Debt instrument, conversion rate					0.021362
2026 Convertible Notes \| Unsecured Debt
Fair Value of Financial Instruments [Line Items]
Issuance interest rate							4.00%
FE \| 4.00%, 1,300 Million Notes Maturity 2026 \| Promissory Notes
Fair Value of Financial Instruments [Line Items]
Face amount of debt \| $	$ 1,500
Issuance interest rate	4.00%
Debt instrument, conversion price (in dollars per share) \| $ / shares			$ 46.81		$ 46.81
Debt instrument, convertible, threshold trading days	20
Debt instrument, convertible, threshold consecutive trading days	30
Debt instrument, convertible, threshold percentage of stock price trigger	130.00%
Debt instrument, convertible, business days	5
Threshold trading days measurement period	10
Debt instrument, measurement period percentage	98.00%
Debt instrument convertible premium		0.20
Repurchase price, percentage		1
Corporate-Owned Life Insurance
Fair Value of Financial Instruments [Line Items]
Gain (loss) on investments \| $			$ 3	$ (16)	$ 10	$ (22)

XML 58 R45.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS - Carrying Amounts of Long-term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Carrying Value
Fair value and related carrying amounts of long-term debt and other long-term obligations
Long-term debt and other long-term obligations	$ 23,726	$ 21,641
Fair Value
Fair value and related carrying amounts of long-term debt and other long-term obligations
Long-term debt and other long-term obligations	$ 21,921	$ 19,784

Amount, after deduction of unamortized premium (discount) and debt issuance cost, of long-term debt. Excludes lease obligation.

XML 59 R46.htm IDEA: XBRL DOCUMENT

FAIR VALUE MEASUREMENTS - Schedule of Long Term Debt Redemption and Issuance (Details) - USD ($) $ in Millions		1 Months Ended
	May 04, 2023	May 31, 2023	Apr. 30, 2023	Mar. 31, 2023	Feb. 28, 2023	Jan. 31, 2023
Debt Instrument [Line Items]
Losses on deferred cash flows		$ 2
Losses on deferred cash flows, net		1
4.00%, 1,300 Million Notes Maturity 2026
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 1,480
Senior Notes
Debt Instrument [Line Items]
Early repayment of debt		194
Make-whole premium		34
Make-whole premium, net		27
Senior Notes \| 7.375% Secured Senior Notes Maturing 2031
Debt Instrument [Line Items]
Long-term debt and other long-term obligations		$ 228
ME \| Promissory Notes \| 3.50% Series B Senior Notes Due 2023
Debt Instrument [Line Items]
Issuance interest rate				3.50%
Face amount of debt				$ 300
ME \| Promissory Notes \| 3.50% Series B Senior Notes Due 2023 \| Revolving Credit Facility
Debt Instrument [Line Items]
Issuance interest rate				3.50%
Face amount of debt				$ 300
ME \| Promissory Notes \| 5.20%, 425 Million Notes Maturing 2028
Debt Instrument [Line Items]
Issuance interest rate				5.20%
Face amount of debt				$ 425
FE \| Promissory Notes \| 7.375% Secured Senior Notes Maturing 2031
Debt Instrument [Line Items]
Issuance interest rate		7.375%
Face amount of debt		$ 194
FE \| Promissory Notes \| 4.00%, 1,300 Million Notes Maturity 2026
Debt Instrument [Line Items]
Issuance interest rate	4.00%
Face amount of debt	$ 1,500
WP \| First Mortgage Bond \| 5.29%, 50 Million Notes Maturing 2023
Debt Instrument [Line Items]
Issuance interest rate						5.29%
Face amount of debt						$ 50
MAIT \| Promissory Notes \| 5.39%, 175 Million Notes Maturing 2023
Debt Instrument [Line Items]
Issuance interest rate					5.39%
Face amount of debt					$ 175
PN \| Promissory Notes \| 5.15%, 300 Million Notes Maturing 2026
Debt Instrument [Line Items]
Issuance interest rate				5.15%
Face amount of debt				$ 300
ATSI \| Promissory Notes \| 5.13%, 150 Million Notes Maturity 2033
Debt Instrument [Line Items]
Issuance interest rate			5.13%
Face amount of debt			$ 150

XML 60 R47.htm IDEA: XBRL DOCUMENT

REGULATORY MATTERS - Maryland and New Jersey (Details)									1 Months Ended
REGULATORY MATTERS - Maryland and New Jersey (Details)	Jul. 17, 2023 USD ($)	Jun. 02, 2023 USD ($)	Apr. 17, 2023 USD ($)	Mar. 22, 2023 USD ($) program	Mar. 16, 2023 USD ($) program	Oct. 26, 2022 USD ($)	Nov. 01, 2021	Oct. 28, 2020 USD ($)	Apr. 30, 2021 USD ($)
Maryland
Regulatory Matters [Line Items]
Increase base distribution rate				$ 19,800,000
PE
Regulatory Matters [Line Items]
Increase base distribution rate				29,300,000
Amount of requested rate increase (decrease)				$ 50,400,000
PE \| Maryland
Regulatory Matters [Line Items]
Number of service reliability and resiliency programs \| program				3
Number of programs \| program				2
Incremental energy savings goal per year (percent)				0.20%
Incremental energy savings goal thereafter (percent)				2.00%
Amount of requested rate increase (decrease)				$ 148,000,000
Recovery period for expenditures for cost recovery program				3 years
PE \| Maryland \| Power Purchase Agreements
Regulatory Matters [Line Items]
Annual termination fee			$ 51,000,000
Amount of termination fee			357,000,000
Expected savings of ending the program			80,000,000
PE \| Maryland \| Power Purchase Agreements \| Other Current Liabilities
Regulatory Matters [Line Items]
Amount of termination fee			55,000,000
PE \| Maryland \| Power Purchase Agreements \| Other Noncurrent Liabilities
Regulatory Matters [Line Items]
Amount of termination fee			$ 302,000,000
PE \| Maryland \| 2021-2023 EmPOWER Program Cycle
Regulatory Matters [Line Items]
Amortization period				5 years
JCP&L \| New Jersey
Regulatory Matters [Line Items]
Approved amount of annual increase						$ 723,000,000
Approved ROE						10.20%
Public utility, offshore development, percent						20.00%
Recovery of transmission incentive rates, percentage			100.00%
Recovery of transmission incentive rates prior to approval date			50.00%
JCP&L \| New Jersey \| NJBPU
Regulatory Matters [Line Items]
Requested increase to ROE							9.60%
Amount of revenue increase								$ 94,000,000
JCP&L \| New Jersey \| NJBPU \| Subsequent Event
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)	$ 31,000,000
JCP&L \| New Jersey \| Energy Efficiency and Peak Demand Reduction Stipulation Settlement \| NJBPU \| Regulated Distribution
Regulatory Matters [Line Items]
Increase base distribution rate		$ 193			$ 185,000,000
Amount of requested rate increase (decrease)									$ 203,000,000
Number of proposed programs \| program					2
Approved period of rate plan									3 years
Approved investment recovery									$ 160,000,000
Approved amount of operation and maintenance recovery									$ 43,000,000
JCP&L \| New Jersey \| Energy Efficiency and Peak Demand Reduction \| NJBPU \| Regulated Distribution
Regulatory Matters [Line Items]
Amortization period									10 years

XML 61 R48.htm IDEA: XBRL DOCUMENT

REGULATORY MATTERS - Ohio (Details) - PUCO meter in Thousands, $ in Thousands	Apr. 05, 2023 USD ($)	Jul. 15, 2022 USD ($) circuit meter	Jun. 01, 2016 USD ($)	Sep. 13, 2021 requirement	Aug. 06, 2021 USD ($)
The Ohio Companies
Regulatory Matters [Line Items]
Commitment to spend	$ 52,000
Minimum \| The Ohio Companies
Regulatory Matters [Line Items]
Approved period of rate plan	8 years
Amount of revenue increase	$ 15,000
Maximum \| The Ohio Companies
Regulatory Matters [Line Items]
Amount of revenue increase	$ 21,000
OHIO
Regulatory Matters [Line Items]
Proposed goal to reduce CO2 pollution (percent)			90.00%
OHIO \| Energy Conservation, Economic Development and Job Retention
Regulatory Matters [Line Items]
Contribution amount			$ 51,000
OHIO \| Delivery Capital Recovery Rider
Regulatory Matters [Line Items]
Annual revenue cap for rider for years three through six			20,000
Annual revenue cap for rider for years six through eight			$ 15,000
OHIO \| Rider DCR Audit Report \| The Ohio Companies
Regulatory Matters [Line Items]
Refund to customer of pole attachment sates					$ 15
Number of requirements with minor non-compliance \| requirement				8
Number of requirements \| requirement				23
OHIO \| Phase Two of Grid Modernization Plan \| The Ohio Companies
Regulatory Matters [Line Items]
Numbers of additional meters to be installed \| meter		700
Number of circuits additional automation equipment to be installed on \| circuit		240
Number of circuits additional voltage regulating equipment to be installed on \| circuit		220
Period of grid modernization plan		4 years
Requested amount of capital investments		$ 626,000
Requested amount of operations and maintenance expenses		$ 144,000

XML 62 R49.htm IDEA: XBRL DOCUMENT

REGULATORY MATTERS - Pennsylvania and West Virginia (Details) $ in Thousands								3 Months Ended	6 Months Ended
	May 31, 2023 USD ($)	Jan. 13, 2023 USD ($)	Aug. 25, 2022 USD ($) MW	May 01, 2022 USD ($)	Mar. 17, 2022	Nov. 22, 2021 site MW	Jan. 16, 2020 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2023 USD ($) proposal
FERC \| Regulated Transmission
Regulatory Matters [Line Items]
Pre-tax impairment of regulatory asset								$ 25,000	$ 25,000
FERC \| Transmission Related Vegetation Management Programs \| FirstEnergy
Regulatory Matters [Line Items]
Customer refund								45,000
Customer refund, net								34,000
Capital assets								195,000
Operating expense								90,000
Operating expense, net								67,000
Reduction in operating expense								$ 160,000
Pennsylvania \| DSP June 2019- May 2023
Regulatory Matters [Line Items]
Number of RFP's \| proposal									2
RFP term									2 years
Pennsylvania \| Three month period \| DSP June 2019- May 2023
Regulatory Matters [Line Items]
Term of energy contract									3 months
Pennsylvania \| Twelve month period \| DSP June 2019- May 2023
Regulatory Matters [Line Items]
Term of energy contract									12 months
Pennsylvania \| Twenty-four month period \| DSP June 2019- May 2023
Regulatory Matters [Line Items]
Term of energy contract									24 months
Pennsylvania \| Pennsylvania Companies \| PPUC \| New LTIIPs
Regulatory Matters [Line Items]
Recovery period							5 years
Amount of requested rate increase (decrease)							$ 572,000
Pennsylvania \| ME \| PPUC \| EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets								2.90%	2.90%
Energy consumption reduction targets								3.10%	3.10%
Pennsylvania \| PN \| PPUC \| EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets								3.30%	3.30%
Energy consumption reduction targets								3.00%	3.00%
Pennsylvania \| Penn \| PPUC \| EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets								2.00%	2.00%
Energy consumption reduction targets								2.70%	2.70%
Pennsylvania \| WP \| PPUC \| EE&C Phase IV
Regulatory Matters [Line Items]
Demand reduction targets								2.50%	2.50%
Energy consumption reduction targets								2.40%	2.40%
West Virginia \| MP and PE \| WVPSC
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)	$ 207,000
Requested amount of annual depreciation expense	$ 76,000	$ 76,000
Regulatory staff requested increase in annual amount of depreciation expense		33,400
Consumer advocate requested increase in annual amount of depreciation expense		$ 300
West Virginia \| MP and PE \| WVPSC \| ENEC
Regulatory Matters [Line Items]
Amount of requested rate increase (decrease)			$ 183,800
Under recovered amount, percent			12.20%
Supplemental requested decrease			$ 145,000
Approved amount of annual increase			$ 92,000
Approved ROE			4.00%
Plant capacity (in MW's) \| MW			1,200
West Virginia \| MP and PE \| WVPSC \| Solar Generation Project
Regulatory Matters [Line Items]
Plant capacity (in MW's) \| MW						50
Percent of subscriptions required prior to commencement of construction					85.00%
Number of proposed solar sites \| site						3
Number of solar sites \| site						5
Expected cost of the program				$ 110,000

XML 63 R50.htm IDEA: XBRL DOCUMENT

COMMITMENTS, GUARANTEES AND CONTINGENCIES - Narrative (Details) $ in Thousands	Feb. 09, 2022 USD ($)	Jul. 21, 2021 USD ($)	Oct. 29, 2020 USD ($) review	Jun. 30, 2023 USD ($)	Mar. 11, 2022 director
Guarantor Obligations [Line Items]
Outstanding guarantees and other assurances aggregated				$ 796,000
Company posted collateral related to net liability positions				66,000
Collateral received				$ 33,000
Goal to reduce in GHG emissions				30.00%
Litigation settlement, number of voluntary compliance reports \| review			2
Litigation settlement, amount awarded to other party, civil penalty			$ 3,860
United States v. Householder, et al.
Guarantor Obligations [Line Items]
Number of board members not seeking re-election \| director					6
Number of board members on special committee \| director					3
Shareholder Derivative Lawsuit
Guarantor Obligations [Line Items]
Amount awarded to other party	$ 36,000
Amount awarded from other party	$ 180,000
Regulation of Waste Disposal
Guarantor Obligations [Line Items]
Accrual for environmental loss contingencies				$ 97,000
Environmental liabilities former gas facilities				62,000
U.S. Attorney's Office \| United States v. Householder, et al.
Guarantor Obligations [Line Items]
Term of DPA		3 years
Loss in period		$ 230,000
Term of payments		60 days
United States Treasury \| United States v. Householder, et al.
Guarantor Obligations [Line Items]
Amount awarded to other party		$ 115,000
Ohio Development Service \| United States v. Householder, et al.
Guarantor Obligations [Line Items]
Amount awarded to other party		$ 115,000
FE
Guarantor Obligations [Line Items]
Outstanding guarantees and other assurances aggregated				510,000
Other Assurances
Guarantor Obligations [Line Items]
Outstanding guarantees and other assurances aggregated				$ 286,000

XML 64 R51.htm IDEA: XBRL DOCUMENT

COMMITMENTS, GUARANTEES AND CONTINGENCIES - Potential Collateral Obligations (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Guarantor Obligations [Line Items]
Guarantor obligations	$ 208
Percent of face amount of debt	100.00%
Curing period	30 days
Upon Further Downgrade
Guarantor Obligations [Line Items]
Guarantor obligations	$ 62
Surety Bond (Collateralized Amount)
Guarantor Obligations [Line Items]
Guarantor obligations	$ 146
Percent of face amount of debt	60.00%
Capped portion of surety bond obligations	$ 39
Surety Bond (Collateralized Amount) \| Pennsylvania Department of Environmental Protection
Guarantor Obligations [Line Items]
Capped portion of surety bond obligations	169
FirstEnergy
Guarantor Obligations [Line Items]
Guarantor obligations	79
FirstEnergy \| Upon Further Downgrade
Guarantor Obligations [Line Items]
Guarantor obligations	0
FirstEnergy \| Surety Bond (Collateralized Amount)
Guarantor Obligations [Line Items]
Guarantor obligations	79
Utilities and Transmission Companies
Guarantor Obligations [Line Items]
Guarantor obligations	129
Utilities and Transmission Companies \| Upon Further Downgrade
Guarantor Obligations [Line Items]
Guarantor obligations	62
Utilities and Transmission Companies \| Surety Bond (Collateralized Amount)
Guarantor Obligations [Line Items]
Guarantor obligations	$ 67

XML 65 R52.htm IDEA: XBRL DOCUMENT

SEGMENT INFORMATION - Narrative (Details) mi² in Thousands, customer in Millions, $ in Billions	6 Months Ended
	Jun. 30, 2023 USD ($) mi² company customer MW
FEV \| Global Holding
Segment Reporting Information [Line Items]
Investment ownership percentage	33.30%
Regulated Distribution
Segment Reporting Information [Line Items]
Number of existing utility operating companies \| company	10
Number of customers served by utility operating companies \| customer	6
Number of square miles in service area \| mi²	65
Megawatts of net demonstrated capacity of competitive segment	3,580
Other/Corporate \| OVEC
Segment Reporting Information [Line Items]
Megawatts of net demonstrated capacity of competitive segment	67
Other/Corporate \| FirstEnergy
Segment Reporting Information [Line Items]
Long-term debt and other long-term obligations \| $	$ 6.8

XML 66 R53.htm IDEA: XBRL DOCUMENT

SEGMENT INFORMATION- Financial Data (Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

Dec. 31, 2022

^[1]

$ 3,006

$ 2,818

$ 6,237

$ 5,807

361

348

722

688

(33)

(129)

(113)

(166)

276

265

539

540

164

132

235

187

527

475

769

647

1,418

1,186

47,065

$ 46,108

5,618

External Customers

3,006

2,818

6,237

5,807

Internal Customers

Operating Segments | Regulated Distribution

2,542

2,426

5,368

5,015

255

242

506

477

(34)

(127)

(113)

(165)

151

128

297

257

100

121

177

202

413

467

393

376

727

712

32,201

31,749

Operating Segments | Regulated Distribution | External Customers

5,004

Operating Segments | Regulated Distribution | Internal Customers

2,484

2,370

5,253

4,902

Operating Segments | Regulated Transmission

115

113

520

441

981

894

179

173

(2)

(1)

120

114

134

123

248

365

267

673

464

14,199

13,835

Operating Segments | Regulated Transmission | External Customers

614

Operating Segments | Regulated Transmission | Internal Customers

519

440

979

891

Corporate/Other

(56)

(49)

(112)

(102)

157

177

(16)

(42)

(22)

(69)

(76)

(138)

(134)

(240)

665

524

Corporate/Other | External Customers

Corporate/Other | Internal Customers

Reconciling Adjustments

(18)

(6)

(35)

(8)

Reconciling Adjustments | External Customers

$ 0

Reconciling Adjustments | Internal Customers