EQT Corp Form 10-Q Quarterly Report Filed 2024-10-30

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
			FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2024

☐

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

FOR THE TRANSITION PERIOD FROM__________ TO__________

COMMISSION FILE NUMBER: 001-03551

EQT CORPORATION

(Exact name of registrant as specified in its charter)


Pennsylvania						25-0464690
(State or other jurisdiction of incorporation or organization)						(IRS Employer Identification No.)

625 Liberty Avenue, Suite 1700
Pittsburgh, Pennsylvania						15222
(Address of principal executive offices)						(Zip Code)

(412) 553-5700

(Registrant's telephone number, including area code)

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

Title of each class

Trading symbol(s)

Name of each exchange on which registered

Common Stock, no par value

EQT

New York Stock Exchange

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

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

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

The number of shares of common stock, no par value, of the registrant outstanding (in thousands) as of October 25, 2024: 596,684

Table of Contents

TABLE OF CONTENTS


		Page
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Statements of Condensed Consolidated Operations	3
	Statements of Condensed Consolidated Comprehensive (Loss) Income	4
	Condensed Consolidated Balance Sheets	5
	Statements of Condensed Consolidated Cash Flows	6
	Statements of Condensed Consolidated Equity	7
	Notes to the Condensed Consolidated Financial Statements	9
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	38
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	58
Item 4.	Controls and Procedures	60

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	60
Item 1A.	Risk Factors	62
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	72
Item 5.	Other Information	72
Item 6.	Exhibits	73

Signatures		76

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED OPERATIONS (UNAUDITED)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands, except per share amounts)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,099,752	$	1,001,883	$	3,293,174	$	3,680,566
Gain on derivatives	66,816		177,906		234,660		1,167,144
Pipeline, net marketing services and other	117,234		6,313		120,748		18,214
Total operating revenues	1,283,802		1,186,102		3,648,582		4,865,924
Operating expenses:
Transportation and processing	440,845		554,788		1,529,093		1,592,934
Production	93,842		62,858		273,042		163,963
Operating and maintenance	40,518		4,235		65,824		6,108
Exploration	282		447		2,576		2,602
Selling, general and administrative	88,470		56,942		228,730		168,999
Depreciation, depletion and amortization	589,299		446,886		1,542,031		1,230,255
Loss (gain) on sale/exchange of long-lived assets	10,117		1,511		(309,865)		17,814
Impairment and expiration of leases	12,095		6,419		58,963		22,290
Other operating expenses	290,174		36,209		354,337		69,265
Total operating expenses	1,565,642		1,170,295		3,744,731		3,274,230
Operating (loss) income	(281,840)		15,807		(96,149)		1,591,694
(Income) loss from investments	(34,242)		546		(36,674)		(5,310)
Other income	(3,960)		(132)		(23,596)		(869)
Loss (gain) on debt extinguishment	365		1,089		5,651		(55)
Interest expense, net	158,299		60,427		268,390		146,856
(Loss) income before income taxes	(402,302)		(46,123)		(309,920)		1,451,072
Income tax (benefit) expense	(104,870)		(126,853)		(124,790)		217,975
Net (loss) income	(297,432)		80,730		(185,130)		1,233,097
Less: Net income (loss) attributable to noncontrolling interests	3,391		(525)		2,688		(80)
Net (loss) income attributable to EQT Corporation	$	(300,823)	$	81,255	$	(187,818)	$	1,233,177

(Loss) income per share of common stock attributable to EQT Corporation:
Basic:
Weighted average common stock outstanding	559,603		383,359		480,354		368,936
Net (loss) income attributable to EQT Corporation	$	(0.54)	$	0.21	$	(0.39)	$	3.34
Diluted (Note 9):
Weighted average common stock outstanding	559,603		416,190		480,354		401,859
Net (loss) income attributable to EQT Corporation	$	(0.54)	$	0.20	$	(0.39)	$	3.08

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE (LOSS) INCOME (UNAUDITED)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands)
Net (loss) income	$	(297,432)	$	80,730	$	(185,130)	$	1,233,097
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax: $13, $15, $39 and $44	28		57		114		270
Comprehensive (loss) income	(297,404)		80,787		(185,016)		1,233,367
Less: Comprehensive income (loss) attributable to noncontrolling interests	3,391		(525)		2,688		(80)
Comprehensive (loss) income attributable to EQT Corporation	$	(300,795)	$	81,312	$	(187,704)	$	1,233,447

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	September 30, 2024		December 31, 2023

	(Thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	88,980	$	80,977
Accounts receivable (less provision for doubtful accounts: $9,135 and $663)	577,599		823,695
Derivative instruments, at fair value	251,657		978,634
Income tax receivable	92,791		91,414
Prepaid expenses and other	71,265		38,255
Total current assets	1,082,292		2,012,975

Property, plant and equipment	44,884,752		33,817,169
Less: Accumulated depreciation and depletion	12,338,210		10,866,999
Net property, plant and equipment	32,546,542		22,950,170
Investment in the MVP Joint Venture	3,358,346		—
Net intangible assets	268,308		22,595
Goodwill	2,178,236		—
Other assets	511,865		299,358
Total assets	$	39,945,589	$	25,285,098

LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	400,150	$	292,432
Accounts payable	1,042,393		1,272,522
Derivative instruments, at fair value	197,712		186,363
Accrued interest	189,965		80,520
Other current liabilities	283,730		205,003
Total current liabilities	2,113,950		2,036,840

Revolving credit facility borrowings	2,297,000		—
Term Loan Facility borrowings	497,970		1,244,265
Senior notes	10,598,428		4,176,180
Note payable to EQM Midstream Partners, LP	—		82,236
Deferred income taxes	2,746,292		1,904,821
Other liabilities and credits	1,203,631		1,059,939
Total liabilities	19,457,271		10,504,281

Equity:
Common stock, no par value, shares authorized: 1,280,000 and 640,000, shares issued: 596,268 and 419,896	18,076,243		12,093,986
Retained earnings	2,261,086		2,681,898
Accumulated other comprehensive loss	(2,570)		(2,684)
Total common shareholders' equity	20,334,759		14,773,200
Noncontrolling interest in consolidated subsidiaries	153,559		7,617
Total equity	20,488,318		14,780,817
Total liabilities and equity	$	39,945,589	$	25,285,098

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED)


	Nine Months Ended September 30,
	2024		2023

	(Thousands)
Cash flows from operating activities:
Net (loss) income	$	(185,130)	$	1,233,097
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Deferred income tax (benefit) expense	(123,725)		227,701
Depreciation, depletion and amortization	1,542,031		1,230,255
Gain/loss on sale/exchange of long-lived assets and impairments	(250,902)		40,104
Income from investments	(36,674)		(5,310)
Loss (gain) on debt extinguishment	5,651		(55)
Share-based compensation expense	141,578		38,179
Distributions from equity method investments	11,187		18,073
Other	13,160		12,022
Gain on derivatives	(234,660)		(1,167,144)
Net cash settlements received on derivatives	1,037,321		625,051
Net premiums paid on derivatives	(41,970)		(231,343)
Changes in other assets and liabilities:
Accounts receivable	331,452		1,122,843
Accounts payable	(122,252)		(515,879)
Other current assets	(10,150)		91,946
Other items, net	(6,220)		(165,076)
Net cash provided by operating activities	2,070,697		2,554,464
Cash flows from investing activities:
Capital expenditures	(1,662,112)		(1,485,898)
Cash paid for acquisitions	(864,242)		(2,288,201)
Proceeds from sale/exchange of assets	451,906		4,831
Capital contributions to equity method investments	(87,804)		(5,000)
Other investing activities	(80)		159
Net cash used in investing activities	(2,162,332)		(3,774,109)
Cash flows from financing activities:
Proceeds from revolving credit facility borrowings	3,578,000		313,000
Repayment of revolving credit facility borrowings	(2,316,000)		(313,000)
Proceeds from issuance of debt	750,000		1,250,000
Proceeds from net settlement of Capped Call Transactions (Note 7)	93,290		—
Debt issuance costs	(18,854)		(5,336)
Repayment and retirement of debt	(1,655,706)		(1,014,346)
(Premiums paid) discounts received on debt extinguishment	(1,543)		5,313
Dividends paid	(232,603)		(162,567)
Repurchase and retirement of common stock	—		(201,029)
Net distribution to noncontrolling interest	(1,640)		(7,322)
Cash paid for taxes to net settle share-based incentive awards	(92,492)		(41,238)
Other financing activities	(2,814)		2,276
Net cash provided by (used in) financing activities	99,638		(174,249)
Net change in cash and cash equivalents	8,003		(1,393,894)
Cash and cash equivalents at beginning of period	80,977		1,458,644
Cash and cash equivalents at end of period	$	88,980	$	64,750

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

See Note 1 for supplemental cash flow information.

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)


	Common Stock
	Shares	Amount		Retained Earnings		Accumulated Other Comprehensive Loss (a)		Noncontrolling Interest in Consolidated Subsidiaries		Total Equity

	(Thousands, except per share amounts)
Balance at July 1, 2023	361,654	$	9,790,855	$	2,217,698	$	(2,781)	$	39,256	$	12,045,028
Comprehensive income, net of tax:
Net income (loss)				81,255				(525)		80,730
Other postretirement benefits liability adjustment, net of tax: $15						57				57
Dividends ($0.15 per share)				(54,249)						(54,249)
Share-based compensation plans	56	14,939								14,939
Convertible Notes settlements	1	16								16
Tug Hill and XcL Midstream Acquisition	49,600	2,152,631								2,152,631
Distribution to noncontrolling interest								(5,279)		(5,279)
Dissolution of consolidated variable interest entity								(25,227)		(25,227)
Other				911						911
Balance at September 30, 2023	411,311	$	11,958,441	$	2,245,615	$	(2,724)	$	8,225	$	14,209,557

Balance at July 1, 2024	441,597	$	12,464,492	$	2,655,940	$	(2,598)	$	6,914	$	15,124,748
Comprehensive loss, net of tax:
Net (loss) income				(300,823)				3,391		(297,432)
Other postretirement benefits liability adjustment, net of tax: $13						28				28
Dividends ($0.1575 per share)				(94,031)						(94,031)
Share-based compensation plans	2,243	63,143								63,143
Equitrans Midstream Merger	152,428	5,548,608						144,894		5,693,502
Distribution to noncontrolling interest								(1,640)		(1,640)
Balance at September 30, 2024	596,268	$	18,076,243	$	2,261,086	$	(2,570)	$	153,559	$	20,488,318

Common shares authorized (in thousands): 640,000 and 1,280,000. Preferred shares authorized (in thousands): 3,000. There were no preferred shares issued or outstanding.

(a)Amounts included in accumulated other comprehensive loss are related to other postretirement benefits liability adjustments, net of tax, which are attributable to net actuarial losses and net prior service costs.

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)


	Common Stock
	Shares	Amount		Retained Earnings		Accumulated Other Comprehensive Loss (a)		Noncontrolling Interest in Consolidated Subsidiaries		Total Equity

	(Thousands, except per share amounts)
Balance at January 1, 2023	365,363	$	9,891,890	$	1,283,578	$	(2,994)	$	40,854	$	11,213,328
Comprehensive income, net of tax:
Net income (loss)				1,233,177				(80)		1,233,097
Other postretirement benefits liability adjustment, net of tax: $44						270				270
Dividends ($0.45 per share)				(162,567)						(162,567)
Share-based compensation plans	2,247	5,367								5,367
Convertible Notes settlements	7	98								98
Repurchase and retirement of common stock	(5,906)	(91,545)		(109,484)						(201,029)
Tug Hill and XcL Midstream Acquisition	49,600	2,152,631								2,152,631
Distribution to noncontrolling interest								(11,072)		(11,072)
Contribution from noncontrolling interest								3,750		3,750
Dissolution of consolidated variable interest entity								(25,227)		(25,227)
Other				911						911
Balance at September 30, 2023	411,311	$	11,958,441	$	2,245,615	$	(2,724)	$	8,225	$	14,209,557

Balance at January 1, 2024	419,896	$	12,093,986	$	2,681,898	$	(2,684)	$	7,617	$	14,780,817
Comprehensive loss, net of tax:
Net (loss) income				(187,818)				2,688		(185,130)
Other postretirement benefits liability adjustment, net of tax: $39						114				114
Dividends ($0.4725 per share)				(232,994)						(232,994)
Share-based compensation plans	3,952	54,751								54,751
Convertible Notes settlements	19,992	285,608								285,608
Net settlement of Capped Call Transactions		93,290								93,290
Equitrans Midstream Merger	152,428	5,548,608						144,894		5,693,502
Distribution to noncontrolling interest								(1,640)		(1,640)
Balance at September 30, 2024	596,268	$	18,076,243	$	2,261,086	$	(2,570)	$	153,559	$	20,488,318

Common shares authorized (in thousands): 640,000 and 1,280,000. Preferred shares authorized (in thousands): 3,000. There were no preferred shares issued or outstanding.

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

1. Financial Statements

Nature of Operations. EQT Corporation is an integrated natural gas production, gathering and transmission company with operations focused in the Appalachian Basin.

In this Quarterly Report on Form 10-Q, references to "EQT" refer to EQT Corporation and references to the "Company" refer collectively to EQT Corporation and its consolidated subsidiaries in each case unless otherwise noted or indicated.

Basis of Presentation. The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all information and notes required by GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of the Company as of September 30, 2024 and December 31, 2023, the results of its operations and equity for the three and nine month periods ended September 30, 2024 and 2023 and its cash flows for the nine month periods ended September 30, 2024 and 2023. Certain previously reported amounts have been reclassified to conform to the current period presentation. In addition, as discussed further in Note 2, certain prior period amounts have been recast to reflect the Company's change in reportable segments from one reportable segment to three reportable segments consisting of Production, Gathering and Transmission.

The Condensed Consolidated Balance Sheet at December 31, 2023 has been derived from the audited financial statements at that date. For further information, refer to the Consolidated Financial Statements and accompanying notes in the Company's Annual Report on Form 10-K for the year ended December 31, 2023.

Principles of Consolidation. The Condensed Consolidated Financial Statements include the accounts of EQT and all subsidiaries, ventures and partnerships in which EQT directly or indirectly holds a controlling interest. Intercompany accounts and transactions have been eliminated in consolidation.

Upon the closing of the Equitrans Midstream Merger (defined in Note 12), the Company acquired a controlling 60% interest in Eureka Midstream Holdings, LLC (Eureka Midstream Holdings) and an equity method investment in Mountain Valley Pipeline, LLC (the MVP Joint Venture).

Eureka Midstream Holdings is a joint venture that owns a gathering header pipeline system that is operated by a subsidiary of EQT. Because the Company is the primary beneficiary of Eureka Midstream Holdings, the Company consolidates Eureka Midstream Holdings and records noncontrolling interest in its Condensed Consolidated Financial Statements. See Note 7 for discussion of the revolving credit facility of Eureka Midstream, LLC (Eureka), a wholly-owned subsidiary of Eureka Midstream Holdings.

The MVP Joint Venture is a joint venture formed among a subsidiary of EQT and, as applicable, affiliates of each of NextEra Energy, Inc., Consolidated Edison, Inc., AltaGas Ltd. and RGC Resources, Inc. for purposes of constructing and operating the Mountain Valley Pipeline (the MVP) and the MVP Southgate project (MVP Southgate). See Note 8 for further discussion of the MVP Joint Venture, the MVP and MVP Southgate. Because the Company has the ability to exercise significant influence over the MVP Joint Venture but does not have the power to direct the activities that most significantly affect the MVP Joint Venture's economic performance, the Company applies the equity method of accounting to the MVP Joint Venture.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Supplemental Cash Flow Information. The following table summarizes net cash paid for interest and income taxes and non-cash activity included in the Statements of Condensed Consolidated Cash Flows.


	Nine Months Ended September 30,
	2024		2023

	(Thousands)
Cash paid during the period for:
Interest, net of amount capitalized	$	196,632	$	145,787
Income taxes, net	4,850		13,441

Non-cash activity during the period for:
Equity issued as consideration for acquisition (Notes 12 and 11)	$	5,548,608	$	2,152,631
Issuance of EQT common stock for Convertible Notes settlement (Note 7)	285,608		98
NEPA Non-Operated Asset Divestiture (Note 11)	155,241		—
Increase in right-of-use assets and lease liabilities, net	11,501		25,849
Increase in asset retirement costs and obligations	7,947		5,216
Capitalization of non-cash equity share-based compensation	5,273		4,587
Investments in nonconsolidated entities	17,598		—
Dissolution of consolidated variable interest entity	—		25,227

Common Stock. On July 18, 2024, following approval by its shareholders, EQT amended its Restated Articles of Incorporation to increase the authorized number of shares of EQT common stock from 640,000,000 shares to 1,280,000,000 shares.

Recently Issued Accounting Standards

In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures to improve reportable segment disclosure requirements, primarily through the requirement of enhanced disclosure of significant segment expenses. In addition, this ASU enhances interim disclosure requirements, clarifies circumstances in which an entity can disclose multiple segment measures of profit or loss and provides new segment disclosure requirements for entities with a single reportable segment. This ASU is effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-07 to have a material impact on its currently-presented financial statements and related disclosures.

In December 2023, the FASB issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures to improve its income tax disclosure requirements. Under this ASU, public business entities must annually (1) disclose specific categories in the rate reconciliation and (2) provide additional information for reconciling items that meet a quantitative threshold. This ASU is effective for fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-09 to have a material impact on its financial statements and related disclosures.

2. Financial Information by Business Segment

Prior to the completion of the Equitrans Midstream Merger, the Company's operations consisted of one reportable segment. Historically, the Company administered all properties as a whole rather than by discrete operating segments and measured financial performance as a single enterprise and not on an area-by-area basis.

As a result of the completion of the Equitrans Midstream Merger, the Company adjusted its internal reporting structure and the Company's chief operating decision maker changed the manner in which he allocates resources and measures financial performance to incorporate the gathering and transmission assets acquired by the Company in the Equitrans Midstream Merger. Hence, the Company's operations expanded to comprise three discrete operating segments reflective of its three lines of business consisting of Production, Gathering and Transmission. Accordingly, the manner in which the Company reports its operations has been changed retrospectively, with certain prior period amounts recast between Production and Gathering.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Certain amounts, including cash and cash equivalents, debt, income taxes and other amounts related to the Company's headquarters function as well as amounts related to the Company's energy transition initiatives, are managed on a consolidated basis and, as such, have not been allocated to the Company's reportable segments and are presented as "Other" along with intersegment eliminations. Water assets acquired in the Equitrans Midstream Merger primarily support the Company's production operations and, as such, have been included in the Company's Production segment.

Substantially all of the Company's operating revenues and assets are generated and located in the United States.

Profit and loss metric with reconciliation to net (loss) income attributable to EQT Corporation for the three months ended September 30, 2024


	Production		Gathering		Transmission		Other and intersegment eliminations		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,099,752	$	—	$	—	$	—	$	1,099,752
Gain (loss) on derivatives	72,489		(5,673)		—		—		66,816
Pipeline, net marketing services and other	5,826		276,829		87,384		(252,805)		117,234
Total operating revenues	1,178,067		271,156		87,384		(252,805)		1,283,802
Operating expenses:
Transportation and processing	693,670		—		—		(252,825)		440,845
Production	93,842		—		—		—		93,842
Operating and maintenance	—		30,712		9,806		—		40,518
Exploration	282		—		—		—		282
Selling, general and administrative (a)	62,952		11,366		5,492		8,660		88,470
Depreciation, depletion and amortization	530,745		37,773		17,109		3,672		589,299
Loss on sale/exchange of long-lived assets	9,708		—		409		—		10,117
Impairment and expiration of leases	12,095		—		—		—		12,095
Other operating expenses (b)	10,206		—		—		279,968		290,174
Total operating expenses	1,413,500		79,851		32,816		39,475		1,565,642
Operating (loss) income	$	(235,433)	$	191,305	$	54,568	$	(292,280)	$	(281,840)

Reconciliation of profit and loss metric to net (loss) income attributable to EQT Corporation
Loss (income) from investments	$	1,671	$	(597)	$	(35,616)	$	300	$	(34,242)
Other income	(3,488)		(128)		(75)		(269)		(3,960)
Loss on debt extinguishment	—		—		—		365		365
Interest expense, net	—		—		—		158,299		158,299
(Loss) income before income taxes	(233,616)		192,030		90,259		(450,975)		(402,302)
Income tax benefit	—		—		—		(104,870)		(104,870)
Net (loss) income	(233,616)		192,030		90,259		(346,105)		(297,432)
Less: Net income (loss) attributable to noncontrolling interests	—		3,687		—		(296)		3,391
Net (loss) income attributable to EQT Corporation	$	(233,616)	$	188,343	$	90,259	$	(345,809)	$	(300,823)

(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.

(b)Corporate other operating expenses consisted primarily of transaction costs related to the Equitrans Midstream Merger. See Note 12.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Profit and loss metric with reconciliation to net income attributable to EQT Corporation for the three months ended September 30, 2023


	Production		Gathering		Other and intersegment eliminations		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,001,883	$	—	$	—	$	1,001,883
Gain on derivatives	177,906		—		—		177,906
Pipeline, net marketing services and other	3,456		42,057		(39,200)		6,313
Total operating revenues	1,183,245		42,057		(39,200)		1,186,102
Operating expenses:
Transportation and processing	593,988		—		(39,200)		554,788
Production	62,858		—		—		62,858
Operating and maintenance	—		4,235		—		4,235
Exploration	447		—		—		447
Selling, general and administrative (a)	56,942		—		—		56,942
Depreciation, depletion and amortization	440,360		4,054		2,472		446,886
Loss on sale/exchange of long-lived assets	1,511		—		—		1,511
Impairment and expiration of leases	6,419		—		—		6,419
Other operating expenses (b)	(621)		—		36,830		36,209
Total operating expenses	1,161,904		8,289		102		1,170,295
Operating income (loss)	$	21,341	$	33,768	$	(39,302)	$	15,807

Reconciliation of profit and loss metric to net income attributable to EQT Corporation
Loss (income) from investments	$	424	$	(255)	$	377	$	546
Other income	—		—		(132)		(132)
Loss on debt extinguishment	—		—		1,089		1,089
Interest expense, net	—		—		60,427		60,427
Income (loss) before income taxes	20,917		34,023		(101,063)		(46,123)
Income tax benefit	—		—		(126,853)		(126,853)
Net income	20,917		34,023		25,790		80,730
Less: Net income (loss) attributable to noncontrolling interests	149		—		(674)		(525)
Net income attributable to EQT Corporation	$	20,768	$	34,023	$	26,464	$	81,255

(b)Corporate other operating expenses consisted primarily of transaction costs related to the Tug Hill and XcL Midstream Acquisition (defined in Note 11).

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Profit and loss metric with reconciliation to net (loss) income attributable to EQT Corporation for the nine months ended September 30, 2024


	Production		Gathering		Transmission		Other and intersegment eliminations		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	3,293,174	$	—	$	—	$	—	$	3,293,174
Gain (loss) on derivatives	240,333		(5,673)		—		—		234,660
Pipeline, net marketing services and other	2,757		415,491		87,384		(384,884)		120,748
Total operating revenues	3,536,264		409,818		87,384		(384,884)		3,648,582
Operating expenses:
Transportation and processing	1,914,010		—		—		(384,917)		1,529,093
Production	273,042		—		—		—		273,042
Operating and maintenance	—		56,018		9,806		—		65,824
Exploration	2,576		—		—		—		2,576
Selling, general and administrative (a)	180,767		11,366		5,492		31,105		228,730
Depreciation, depletion and amortization	1,470,966		45,282		17,109		8,674		1,542,031
(Gain) loss on sale/exchange of long-lived assets	(310,252)		(22)		409		—		(309,865)
Impairment and expiration of leases	58,963		—		—		—		58,963
Other operating expenses (b)	23,650		—		—		330,687		354,337
Total operating expenses	3,613,722		112,644		32,816		(14,451)		3,744,731
Operating (loss) income	$	(77,458)	$	297,174	$	54,568	$	(370,433)	$	(96,149)

Reconciliation of profit and loss metric to net (loss) income attributable to EQT Corporation
(Income) loss from investments	$	(371)	$	(2,109)	$	(35,616)	$	1,422	$	(36,674)
Other income	(17,638)		(5,153)		(75)		(730)		(23,596)
Loss on debt extinguishment	—		—		—		5,651		5,651
Interest expense, net	—		—		—		268,390		268,390
(Loss) income before income taxes	(59,449)		304,436		90,259		(645,166)		(309,920)
Income tax benefit	—		—		—		(124,790)		(124,790)
Net (loss) income	(59,449)		304,436		90,259		(520,376)		(185,130)
Less: Net income (loss) attributable to noncontrolling interests	—		3,687		—		(999)		2,688
Net (loss) income attributable to EQT Corporation	$	(59,449)	$	300,749	$	90,259	$	(519,377)	$	(187,818)

(b)Corporate other operating expenses consisted primarily of transaction costs related to the Equitrans Midstream Merger. See Note 12.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Profit and loss metric with reconciliation to net income (loss) attributable to EQT Corporation for the nine months ended September 30, 2023


	Production		Gathering		Other and intersegment eliminations		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	3,680,566	$	—	$	—	$	3,680,566
Gain on derivatives	1,167,144		—		—		1,167,144
Pipeline, net marketing services and other	9,675		95,753		(87,214)		18,214
Total operating revenues	4,857,385		95,753		(87,214)		4,865,924
Operating expenses:
Transportation and processing	1,680,009		—		(87,075)		1,592,934
Production	163,963		—		—		163,963
Operating and maintenance	—		6,108		—		6,108
Exploration	2,602		—		—		2,602
Selling, general and administrative (a)	168,999		—		—		168,999
Depreciation, depletion and amortization	1,214,882		8,077		7,296		1,230,255
Loss on sale/exchange of long-lived assets	17,814		—		—		17,814
Impairment and expiration of leases	22,290		—		—		22,290
Other operating expenses (b)	7,645		—		61,620		69,265
Total operating expenses	3,278,204		14,185		(18,159)		3,274,230
Operating income (loss)	$	1,579,181	$	81,568	$	(69,055)	$	1,591,694

Reconciliation of profit and loss metric to net income (loss) attributable to EQT Corporation
(Income) loss from investments	$	(2,675)	$	(4,004)	$	1,369	$	(5,310)
Other income	(395)		—		(474)		(869)
Gain on debt extinguishment	—		—		(55)		(55)
Interest expense, net	—		—		146,856		146,856
Income (loss) before income taxes	1,582,251		85,572		(216,751)		1,451,072
Income tax expense	—		—		217,975		217,975
Net income (loss)	1,582,251		85,572		(434,726)		1,233,097
Less: Net income (loss) attributable to noncontrolling interests	1,588		—		(1,668)		(80)
Net income (loss) attributable to EQT Corporation	$	1,580,663	$	85,572	$	(433,058)	$	1,233,177

(b)Corporate other operating expenses consisted primarily of transaction costs related to the Tug Hill and XcL Midstream Acquisition.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Assets by segment as of September 30, 2024


	Production		Gathering		Transmission		Other and intersegment eliminations		EQT Corporation

	(Thousands)
Investment in the MVP Joint Venture	$	—	$	—	$	3,358,346	$	—	$	3,358,346
Goodwill	—		—		1,289,759		888,477		2,178,236
Other segment assets (a)	22,890,299		8,187,601		2,962,486		368,621		34,409,007
Total assets	$	22,890,299	$	8,187,601	$	7,610,591	$	1,257,098	$	39,945,589

(a)Other segment assets in other and intersegment eliminations includes cash and cash equivalents.

Assets by segment as of September 30, 2023


	Production		Gathering		Other and intersegment eliminations		EQT Corporation

	(Thousands)



Total assets (a)	$	23,138,353	$	1,167,766	$	248,869	$	24,554,988

(a)Total assets in other and intersegment eliminations includes cash and cash equivalents.

The Company did not have an investment in the MVP Joint Venture or goodwill as of September 30, 2023.

Capital expenditures by segment


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands)
Capital expenditures:
Production (a)	$	454,772	$	435,646	$	1,539,904	$	1,366,669
Gathering (b)	79,597		6,941		111,644		11,521
Transmission	10,118		—		10,118		—
Other	13,402		1,998		21,345		8,546
Total capital expenditures	$	557,889	$	444,585	$	1,683,011	$	1,386,736

(a)Production capital expenditures included capital expenditures attributable to the noncontrolling interest in The Mineral Company LLC (a joint venture formed between a subsidiary of EQT and a third-party investor for the purpose of purchasing certain mineral rights in the Appalachian Basin) of approximately $8.5 million for the nine months ended September 30, 2023. The Mineral Company LLC was dissolved in the third quarter of 2023.

(b)Gathering capital expenditures included capital expenditures attributable to the noncontrolling interest in Eureka Midstream Holdings of approximately $1.6 million for both the three and nine months ended September 30, 2024. See Notes 1 and 12.

Intersegment contracts

On February 26, 2020, EQT and certain of its affiliates (such parties, collectively, the EQT Producer) entered into a gas gathering and compression agreement (the Consolidated GGA) with an affiliate of EQM Midstream Partners, LP (EQM), which became an indirect wholly-owned subsidiary of EQT upon the closing of the Equitrans Midstream Merger. Pursuant to the terms of the Consolidated GGA, among other things, the EQM affiliate agreed to provide gas gathering services to the EQT Producer, and the EQT Producer committed to an initial annual minimum volume commitment (MVC) of 3.0 Bcf per day and an acreage dedication in Pennsylvania and West Virginia. The Consolidated GGA is effective through December 31, 2035 and will renew annually thereafter unless terminated by the parties thereto.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The Consolidated GGA provides for cash bonus payments (the Henry Hub Cash Bonus) payable by the EQT Producer to the EQM affiliate during each quarter beginning with the first day of the quarter in which the MVP In-Service Date (as defined in the Consolidated GGA) occurs and ending on the earlier of 36 months thereafter or December 31, 2024. Such payments are conditioned upon the quarterly average of the NYMEX Henry Hub natural gas settlement price exceeding certain price thresholds. Upon commencement of long-term firm capacity obligations, the MVP In-Service Date occurred on July 1, 2024. See Note 8.

The EQT Producer's derivative liability and any gain or loss realized related to the Henry Hub Cash Bonus are included in the Company's Production segment; the EQM affiliate's derivative asset and any gain or loss realized related to the Henry Hub Cash Bonus are included in the Company's Gathering segment. All balances and gains or losses related to the Henry Hub Cash Bonus have been eliminated in consolidation. As of September 30, 2024 and December 31, 2023, the derivative related to the Henry Hub Cash Bonus had a fair value of approximately $15 million and $48 million, respectively. The fair value of the derivative asset and liability related to the Henry Hub Cash Bonus is based on significant inputs that are interpolated from observable market data and, as such, is a Level 2 fair value measurement. See Note 5 for a description of the fair value hierarchy.

3. Revenue from Contracts with Customers

Sales of natural gas, NGLs and oil. Under the Company's natural gas, natural gas liquids (NGLs) and oil sales contracts, the Company generally considers the delivery of each unit (million British thermal units (MMBtu) or barrel (Bbl)) to be a separate performance obligation that is satisfied upon delivery. These contracts typically require payment within 25 days of the end of the calendar month in which the commodity is delivered. A significant number of these contracts contain variable consideration because the payment terms refer to market prices at future delivery dates. In these situations, the Company has not identified a standalone selling price because the terms of the variable payments relate specifically to the Company's efforts to satisfy the performance obligations. Other contracts, such as fixed price contracts or contracts with a fixed differential to New York Mercantile Exchange (NYMEX) or index prices, contain fixed consideration. The fixed consideration is allocated to each performance obligation on a relative standalone selling price basis, which requires judgment from management. For these contracts, the Company generally concludes that the fixed price or fixed differentials in the contracts are representative of the standalone selling price.

Based on management's judgment, the performance obligations for the sale of natural gas, NGLs and oil are satisfied at a point in time because the customer obtains control and legal title of the asset when the natural gas, NGLs or oil is delivered to the designated sales point.

The sales of natural gas, NGLs and oil presented in the Statements of Condensed Consolidated Operations represent the Company's share of revenues net of royalties and exclude revenue interests owned by others. When selling natural gas, NGLs and oil on behalf of royalty or working interest owners, the Company acts as an agent and, thus, reports the revenue on a net basis.

Pipeline revenue. The Company recognizes revenue under gathering and transmission and storage contracts when it satisfies certain performance obligations.

The Company provides firm and interruptible gathering and transmission and storage services. Firm service contracts generally require the customer to pay a firm reservation fee, which is a fixed, monthly charge to reserve an agreed upon amount of pipeline or storage capacity regardless of whether the customer uses the capacity. Volumetric-based fees, which are charges based on the volume of gas gathered, transported or stored, can also be charged under firm contracts for each firm contracted volume gathered, transported or stored, as well as for volumes gathered, transported or stored in excess of the firm contracted volume so long as capacity exists. Interruptible service contracts require the customer to pay volumetric-based fees and generally do not guarantee access to the pipeline or storage facility.

Gathering and transmission and storage services contracts can be short-term or long-term in duration. Firm and interruptible gathering service contracts are invoiced on a one-month lag, with payment typically due within 21 days of the invoice date. Revenue for gathering services provided but not yet invoiced is estimated based on contract data, preliminary throughput and allocation measurements on a monthly basis. Firm and interruptible transmission and storage service contracts are invoiced at the end of each calendar month, with payment typically due within 10 days of the invoice date.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Under its firm service contracts, the Company has a stand-ready obligation to provide the firm service over the life of the contract. The performance obligation for revenue from firm reservation fees is satisfied over time as the pipeline capacity is made available to the customer. As such, the Company recognizes firm reservation fee revenue evenly over the contract period using a time-elapsed output method to measure progress. The performance obligation for revenue from volumetric-based fees is generally satisfied upon the Company's monthly invoicing to the customer for volumes gathered, transported or stored during the month. The amount invoiced generally corresponds directly to the value of the Company's performance to date as the customer obtains value as each volume is gathered, transported or stored.

For all of the Company's gathering and transmission and storage services contracts, the Company allocates the transaction price to each performance obligation based on the estimated relative standalone selling price. Any excess of consideration received over revenue recognized results in the deferral of those amounts until future periods based on a units-of-production or straight-line methodology as these methods align with the consumption of services provided to the customer. The units-of-production methodology requires the use of judgment to estimate future production volumes.

Certain of the Company's gathering service agreements are structured with MVCs, which specify minimum quantities that the customer will be charged regardless of whether such quantities are gathered. Revenue is recognized for MVCs when the performance obligation has been met, which is the earlier of when the gas is gathered or when the likelihood that the customer will be able to meet its MVC is remote. If a customer fails to meet its MVC for a specified period (thus not exercising all the contractual rights to gathering services within the specified period), the customer is obligated to pay a contractually-determined fee based on the shortfall between actual volume gathered and the MVC.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Disaggregated revenue information. The table below provides disaggregated information on the Company's revenues. Certain other revenue contracts are outside the scope of ASU 2014-09, Revenue from Contracts with Customers. These contracts are reported in pipeline, net marketing services and other revenues in the Statements of Condensed Consolidated Operations. Derivative contracts are also outside the scope of ASU 2014-09.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands)
Revenues from contracts with customers:
Production:
Sales of natural gas, NGLs and oil
Natural gas sales	$	938,911	$	859,512	$	2,791,190	$	3,337,600
NGLs sales	139,697		108,205		435,581		274,932
Oil sales	21,144		34,166		66,403		68,034
Sales of natural gas, NGLs and oil	1,099,752		1,001,883		3,293,174		3,680,566

Gathering:
Pipeline revenues
Firm reservation fee revenues (a)	136,752		—		136,752		—
Volumetric-based fee revenues	140,077		42,057		278,739		95,753
Total	276,829		42,057		415,491		95,753

Transmission:
Pipeline revenues
Firm reservation fee revenues	73,034		—		73,034		—
Volumetric-based fee revenues	14,226		—		14,226		—
Total	87,260		—		87,260		—

Other and intersegment eliminations	(252,805)		(39,200)		(384,884)		(87,214)
Total revenues from contracts with customers	$	1,211,036	$	1,004,740	$	3,411,041	$	3,689,105

Other sources of revenue:
Gain on derivatives	$	66,816	$	177,906	$	234,660	$	1,167,144
Net marketing services and other revenues	5,950		3,456		2,881		9,675
Total other sources of revenue	$	72,766	$	181,362	$	237,541	$	1,176,819

Total operating revenues	$	1,283,802	$	1,186,102	$	3,648,582	$	4,865,924

(a)Firm reservation fee revenues for the three and nine months ended September 30, 2024 included unbilled revenues supported by MVCs of approximately $1.8 million.

For contracts with customers where the Company's performance obligations had been satisfied and an unconditional right to consideration existed as of the balance sheet date, the Company recorded amounts due from contracts with customers of $443.3 million and $584.8 million in accounts receivable in the Condensed Consolidated Balance Sheets as of September 30, 2024 and December 31, 2023, respectively.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Summary of remaining performance obligations. The following table summarizes the transaction price allocated to the Company's remaining obligations on all contracts with fixed consideration as of September 30, 2024. The table excludes contracts that qualified for the exception to the relative standalone selling price method as of September 30, 2024. The MVP Joint Venture is accounted for as an equity method investment and, as such, its remaining performance obligations have been excluded from the table.


	2024 (a)		2025		2026		2027		2028		Thereafter		Total

	(Thousands)

Gathering firm reservation fees:
Third-party contracts	$	25,850	$	101,137	$	92,186	$	85,651	$	85,651	$	457,444	$	847,919
Affiliate contracts	22,445		87,075		80,698		80,362		76,670		1,188,383		1,535,633
Total Gathering firm reservation fees	48,295		188,212		172,884		166,013		162,321		1,645,827		2,383,552

Gathering revenues supported by MVCs:
Third-party contracts	21,036		82,257		89,078		80,765		77,014		250,652		600,802
Affiliate contracts	90,630		372,446		397,966		410,621		411,740		2,453,073		4,136,476
Total Gathering revenues supported by MVCs	111,666		454,703		487,044		491,386		488,754		2,703,725		4,737,278

Transmission firm reservation fees:
Third-party contracts	48,754		175,010		174,191		171,750		169,393		980,973		1,720,071
Affiliate contracts	57,415		227,116		225,588		225,588		225,260		1,752,347		2,713,314
Total Transmission firm reservation fees	106,169		402,126		399,779		397,338		394,653		2,733,320		4,433,385

Total	$	266,130	$	1,045,041	$	1,059,707	$	1,054,737	$	1,045,728	$	7,082,872	$	11,554,215

(a)October 1 through December 31.

As of September 30, 2024, the Company had no remaining performance obligations on its natural gas sales contracts with fixed consideration.

Based on total projected contractual revenues, the Company's firm gathering affiliate contracts and firm transmission and storage affiliate contracts had weighted average remaining terms of approximately 13 years and 11 years, respectively, as of September 30, 2024. Based on total projected contractual revenues, the Company's firm gathering third-party contracts and firm transmission and storage third-party contracts had weighted average remaining terms of approximately 12 years and 11 years, respectively, as of September 30, 2024.

4. Derivative Instruments

The Company's primary market risk exposure is the volatility of future prices for natural gas and NGLs, which can affect the Company's operating results. The Company uses derivative commodity instruments to hedge its cash flows from sales of produced natural gas and NGLs. The overall objective of the Company's hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices.

The derivative commodity instruments used by the Company are primarily swap, collar and option agreements. These agreements may result in payments to, or receipt of payments from, counterparties based on the differential between two prices for the commodity. The Company uses these agreements to hedge its NYMEX and basis exposure. The Company may also use other contractual agreements when executing its commodity hedging strategy. The Company typically enters into over the counter (OTC) derivative commodity instruments with financial institutions, and the creditworthiness of all counterparties is regularly monitored.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The Company does not designate any of its derivative instruments as cash flow hedges; therefore, all changes in fair value of the Company's derivative instruments are recognized in operating revenues in gain on derivatives in the Statements of Condensed Consolidated Operations. The Company recognizes all derivative instruments as either assets or liabilities at fair value on a gross basis. These derivative instruments are reported as either current assets or current liabilities due to their highly liquid nature. The Company can net settle its derivative instruments at any time.

Contracts that result in physical delivery of a commodity expected to be sold by the Company in the normal course of business are generally designated as normal sales and are exempt from derivative accounting. Contracts that result in the physical receipt or delivery of a commodity but are not designated or do not meet all of the criteria to qualify for the normal purchase and normal sale scope exception are subject to derivative accounting.

The Company's OTC derivative instruments generally require settlement in cash. The Company also enters into exchange traded derivative commodity instruments that are generally settled with offsetting positions. Settlements of derivative commodity instruments are reported as a component of cash flows from operating activities in the Statements of Condensed Consolidated Cash Flows.

With respect to the derivative commodity instruments held by the Company, the Company hedged portions of its expected sales of production and portions of its basis exposure covering approximately 2,574 Bcf of natural gas and 1,464 thousand barrels (Mbbl) of NGLs as of September 30, 2024 and 2,045 Bcf of natural gas and 1,049 Mbbl of NGLs as of December 31, 2023. The open positions at both September 30, 2024 and December 31, 2023 had maturities extending through December 2027.

Certain of the Company's OTC derivative instrument contracts provide that, if EQT's credit rating assigned by Moody's Investors Service, Inc. (Moody's), S&P Global Ratings (S&P) or Fitch Ratings Service (Fitch) is below the agreed-upon credit rating threshold (typically, below investment grade) and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the counterparty to such contract can require the Company to deposit collateral. Similarly, if such counterparty's credit rating assigned by Moody's, S&P or Fitch is below the agreed-upon credit rating threshold and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the Company can require the counterparty to deposit collateral with the Company. Such collateral can be up to 100% of the derivative liability. Investment grade refers to the quality of a company's credit as assessed by one or more credit rating agencies. To be considered investment grade, a company must be rated "Baa3" or higher by Moody's, "BBB–" or higher by S&P and "BBB–" or higher by Fitch. Anything below these ratings is considered non-investment grade. As of September 30, 2024, EQT's senior notes were rated "Baa3" by Moody's, "BBB–" by S&P and "BBB–" by Fitch.

When the net fair value of any of the Company's OTC derivative instrument contracts represents a liability to the Company that is in excess of the agreed-upon dollar threshold for the Company's then-applicable credit rating, the counterparty has the right to require the Company to remit funds as a margin deposit in an amount equal to the portion of the derivative liability that is in excess of the dollar threshold amount. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. As of September 30, 2024, none of the Company's OTC derivative instruments with credit rating risk-related contingent features were in a net liability position. As of December 31, 2023, the aggregate fair value of the Company's OTC derivative instruments with credit rating risk-related contingent features in a net liability position was $6.4 million, for which no deposits were required or recorded in the Condensed Consolidated Balance Sheet.

When the net fair value of any of the Company's OTC derivative instrument contracts represents an asset to the Company that is in excess of the agreed-upon dollar threshold for the counterparty's then-applicable credit rating, the Company has the right to require the counterparty to remit funds as a margin deposit in an amount equal to the portion of the derivative asset that is in excess of the dollar threshold amount. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. As of both September 30, 2024 and December 31, 2023, there were no such deposits recorded in the Condensed Consolidated Balance Sheets.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

When the Company enters into exchange traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good-faith deposits to guard against the risks associated with changing market conditions. The Company is required to make such deposits based on an established initial margin requirement and the net liability position, if any, of the fair value of the associated contracts. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. When the fair value of such contracts is in a net asset position, the broker may remit funds to the Company. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the contract. The margin requirements are subject to change at the exchanges' discretion. As of September 30, 2024 and December 31, 2023, there were $17.5 million and $13.0 million, respectively, of such deposits recorded as current assets in the Condensed Consolidated Balance Sheets.

The Company has netting agreements with financial institutions and its brokers that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities. The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.


	Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets		Derivative instruments subject to master netting agreements		Margin requirements with counterparties		Net derivative instruments

	(Thousands)
September 30, 2024
Asset derivative instruments, at fair value	$	251,657	$	(152,115)	$	—	$	99,542
Liability derivative instruments, at fair value	197,712		(152,115)		(17,488)		28,109

December 31, 2023
Asset derivative instruments, at fair value	$	978,634	$	(112,203)	$	—	$	866,431
Liability derivative instruments, at fair value	186,363		(112,203)		(13,017)		61,143

5. Fair Value Measurements

The Company records its financial instruments, which are principally derivative instruments, at fair value in the Condensed Consolidated Balance Sheets. The Company estimates the fair value of its financial instruments using quoted market prices when available. If quoted market prices are not available, the fair value is based on models that use market-based parameters, including forward curves, discount rates, volatilities and nonperformance risk, as inputs. Nonperformance risk considers the effect of the Company's credit standing on the fair value of liabilities and the effect of the counterparty's credit standing on the fair value of assets. The Company estimates nonperformance risk by analyzing publicly available market information, including a comparison of the yield on debt instruments with credit ratings similar to EQT's or the counterparty's credit rating and the yield on a risk-free instrument.

The Company has categorized its assets and liabilities recorded at fair value into a three-level fair value hierarchy based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). Assets and liabilities that use Level 2 inputs primarily include the Company's swap, collar and option agreements.

Exchange traded commodity swaps have Level 1 inputs. The fair value of the commodity swaps with Level 2 inputs is based on standard industry income approach models that use significant observable inputs, including, but not limited to, NYMEX natural gas forward curves, SOFR-based discount rates, basis forward curves and NGLs forward curves. The Company's collars and options are valued using standard industry income approach option models. The significant observable inputs used by the option pricing models include NYMEX forward curves, natural gas volatilities and SOFR-based discount rates.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The table below summarizes assets and liabilities measured at fair value on a recurring basis.


			Fair value measurements at reporting date using:
	Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets		Quoted prices in active markets for identical assets (Level 1)		Significant other observable inputs (Level 2)		Significant unobservable inputs (Level 3)

	(Thousands)
September 30, 2024
Asset derivative instruments, at fair value	$	251,657	$	41,772	$	209,885	$	—
Liability derivative instruments, at fair value	197,712		17,402		180,310		—

December 31, 2023
Asset derivative instruments, at fair value	$	978,634	$	66,302	$	912,332	$	—
Liability derivative instruments, at fair value	186,363		42,218		144,145		—

The carrying value of cash equivalents, accounts receivable and accounts payable approximates fair value due to their short-term maturities. The carrying value of borrowings under EQT's revolving credit facility, Eureka's revolving credit facility and the Term Loan Facility (defined in Note 7) approximates fair value as each facility's interest rate is based on prevailing market rates. The Company considers all of these fair values to be Level 1 fair value measurements.

The Company has an investment in a fund (the Investment Fund) that invests in companies developing technology and operating solutions for exploration and production companies. The Company values the Investment Fund using, as a practical expedient, the net asset value provided in the financial statements received from fund managers.

The Company estimates the fair value of its senior notes using established fair value methodology. Because not all of the Company's senior notes are actively traded, their fair value is a Level 2 fair value measurement. As of September 30, 2024 and December 31, 2023, the Company's senior notes had a fair value of approximately $11.2 billion and $4.9 billion, respectively, and a carrying value of approximately $11.0 billion and $4.5 billion, respectively, inclusive of any current portion. See Note 7 for further discussion of the Company's debt.

Upon the closing of the Equitrans Midstream Merger, EQT's note payable to EQM became an intercompany transaction on a consolidated basis and, as such, was effectively settled on July 22, 2024. See Note 12. As of December 31, 2023, the fair value of EQT's note payable to EQM was estimated using an income approach model with a market-based discount rate and was considered a Level 3 fair value measurement. As of December 31, 2023, EQT's note payable to EQM had a fair value and carrying value of approximately $91 million and $88 million, respectively, inclusive of any current portion.

The Company recognizes transfers between Levels as of the actual date of the event or change in circumstances that caused the transfer. There were no transfers between Levels 1, 2 and 3 during the periods presented.

See Note 2 for a discussion of the fair value measurement of the Henry Hub Cash Bonus (which became an intercompany derivative asset and liability upon the closing of the Equitrans Midstream Merger). See Note 11 for a discussion of the fair value measurement of the NEPA Non-Operated Asset Divestiture (defined therein). See Note 12 for a discussion of the fair value measurement of the Equitrans Midstream Merger. See Note 1 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, 2023 for a discussion of the fair value measurement and any subsequent impairments of the Company's oil and gas properties and other long-lived assets, including impairment and expiration of leases.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

6. Income Taxes

For the nine months ended September 30, 2024 and 2023, the Company calculated the provision for income taxes by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the nine months ended September 30, 2024.

For the nine months ended September 30, 2024 and 2023, the Company recorded income tax (benefit) expense at an effective tax rate of 40.3% and 15.0%, respectively. The Company's effective tax rate for the nine months ended September 30, 2024 was higher compared to the U.S. federal statutory rate primarily as a result of recognition of tax benefits related to higher losses on the Company's state tax-paying entities and the utilization of some its capital loss carryforwards with the capital gain generated from the NEPA Non-Operated Asset Divestiture, which resulted in the release of the associated valuation allowance. The Company's effective tax rate for the nine months ended September 30, 2023 was lower compared to the U.S. federal statutory rate due primarily to the release of valuation allowances limiting certain state deferred tax assets and net state deferred tax benefits related to a rate reduction from a Pennsylvania tax law change enacted in July 2022 and the Tug Hill and XcL Midstream Acquisition.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

7. Debt

The table below summarizes the Company's outstanding debt.


	September 30, 2024				December 31, 2023
	Principal Value		Carrying Value (a)		Principal Value		Carrying Value (a)

	(Thousands)
EQT's revolving credit facility maturing July 23, 2029	$	1,967,000	$	1,967,000	$	—	$	—
Eureka's revolving credit facility maturing November 13, 2025	330,000		330,000		—		—
Term Loan Facility due June 30, 2026 (b)	500,000		497,970		1,250,000		1,244,265
Debentures and senior notes:
EQT's 6.125% notes due February 1, 2025 (b)	—		—		601,521		600,389
EQM's 6.000% notes due July 1, 2025	400,000		400,150		—		—
EQT's 1.75% convertible notes due May 1, 2026 (c)	—		—		290,177		286,185
EQT's 3.125% notes due May 15, 2026	392,915		390,889		392,915		389,978
EQT's 7.75% debentures due July 15, 2026	115,000		114,088		115,000		113,716
EQM's 4.125% notes due December 1, 2026	500,000		487,340		—		—
EQM's 7.500% notes due June 1, 2027	500,000		512,554		—		—
EQM's 6.500% notes due July 1, 2027	900,000		917,091		—		—
EQT's 3.90% notes due October 1, 2027	1,169,503		1,166,252		1,169,503		1,165,439
EQT's 5.700% notes due April 1, 2028	500,000		492,074		500,000		490,376
EQM's 5.500% notes due July 15, 2028	850,000		846,328		—		—
EQT's 5.00% notes due January 15, 2029	318,494		315,619		318,494		315,121
EQM's 4.50% notes due January 15, 2029	800,000		764,360		—		—
EQM's 6.375% notes due April 1, 2029	600,000		609,177		—		—
EQT's 7.000% notes due February 1, 2030 (b)	674,800		671,486		674,800		671,020
EQM's 7.500% notes due June 1, 2030	500,000		537,317		—		—
EQM's 4.75% notes due January 15, 2031	1,100,000		1,042,951		—		—
EQT's 3.625% notes due May 15, 2031	435,165		430,649		435,165		430,141
EQT's 5.750% notes due February 1, 2034	750,000		742,598		—		—
EQM's 6.500% notes due July 15, 2048	550,000		557,655		—		—
EQT's note payable to EQM (d)	—		—		88,483		88,483
Total debt	13,852,877		13,793,548		5,836,058		5,795,113
Less: Current portion of debt (e)	400,000		400,150		296,424		292,432
Long-term debt	$	13,452,877	$	13,393,398	$	5,539,634	$	5,502,681

(a)For EQT's revolving credit facility, Eureka's revolving credit facility and, as of December 31, 2023, EQT's note payable to EQM, the principal value represents the carrying value. For all other debt, the principal value less the unamortized debt issuance costs and debt discounts and, for EQM's senior notes, the unamortized fair value adjustments recorded with Equitrans Midstream Merger purchase price accounting represents the carrying value.

(b)Interest rates for the Term Loan Facility and EQT's 7.000% senior notes fluctuate based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Prior to EQT's redemption of all of its outstanding 6.125% senior notes, interest rates for EQT's 6.125% senior notes fluctuated based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Interest rates for the Company's other outstanding debt do not fluctuate.

(c)As of December 31, 2023, the fair value of EQT's 1.75% convertible notes was $768.6 million and was a Level 2 fair value measurement. See Note 5.

(d)As a result of the Equitrans Midstream Merger, EQT's note payable to EQM has been eliminated in consolidation.

(e)As of September 30, 2024, the current portion of debt included EQM's 6.000% senior notes. As of December 31, 2023, the current portion of debt included EQT's 1.75% convertible notes and a portion of EQT's note payable to EQM.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Debt Repayments. The Company repaid, redeemed or repurchased the following debt during the nine months ended September 30, 2024.


Debt Tranche	Principal		Premiums		Accrued but Unpaid Interest		Total Cost

	(Thousands)
EQM's 4.00% notes due August 1, 2024 (a)	$	300,000	$	—	$	6,000	$	306,000
EQT's 6.125% notes due February 1, 2025	601,521		1,178		13,612		616,311
Term Loan Facility due June 30, 2026	750,000		—		332		750,332
EQT's 1.75% convertible notes due May 1, 2026	583		—		—		583
Total	$	1,652,104	$	1,178	$	19,944	$	1,673,226

(a)EQM's 4.00% senior notes, which were consolidated by the Company as a result of the Equitrans Midstream Merger, were redeemed at maturity.

EQT's Revolving Credit Facility. EQT has a $3.5 billion revolving credit facility. On July 22, 2024, EQT entered into a Fourth Amended and Restated Credit Agreement (the Fourth A&R Credit Agreement) with PNC Bank National Association, as administrative agent, swing line lender and L/C issuer, and the other lenders party thereto, amending and restating the Third Amended and Restated Credit Agreement, dated June 28, 2022 (the Credit Agreement), under which such lenders agreed to make to EQT unsecured revolving loans in an aggregate principal amount of up to $3.5 billion. The Fourth A&R Credit Agreement, among other things, (i) extends the maturity date of the commitments and loans under the Credit Agreement to July 23, 2029 and provides, at EQT's option, two one-year extensions thereafter, subject to satisfaction of certain conditions, and (ii) allows for additional commitment increases up to $1 billion, subject to the agreement of EQT and new or existing lenders. EQT can obtain Base Rate Loans (as defined in the Fourth A&R Credit Agreement) or Term SOFR Rate Loans (as defined in the Fourth A&R Credit Agreement). Base Rate Loans are denominated in dollars and bear interest at a Base Rate (as defined in the Fourth A&R Credit Agreement) plus a margin ranging from 12.5 basis points to 100 basis points determined on the basis of EQT's credit ratings. Term SOFR Rate Loans bear interest at a Term SOFR Rate (as defined in the Fourth A&R Credit Agreement) plus an additional 10 basis point credit spread adjustment plus a margin ranging from 112.5 basis points to 200 basis points determined on the basis of EQT's credit ratings.

As of September 30, 2024, the Company had approximately $1 million of letters of credit outstanding under EQT's revolving credit facility and no letters of credit outstanding under Eureka's revolving credit facility. As of December 31, 2023, the Company had approximately $15 million of letters of credit outstanding under EQT's revolving credit facility.

During the three months ended September 30, 2024 and 2023, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $2,301 million and $158 million, respectively, and the average daily balance was approximately $1,608 million and $28 million, respectively. During the nine months ended September 30, 2024 and 2023, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $2,301 million and $158 million, respectively, and the average daily balance was approximately $551 million and $9 million, respectively. For each of the three and nine month periods ended September 30, 2024 and 2023, interest under EQT's revolving credit facility was incurred at a weighted average annual interest rate of 6.9%.

Eureka's Revolving Credit Facility. Upon the closing of the Equitrans Midstream Merger, the Company acquired a controlling interest in Eureka Midstream Holdings. See Notes 1 and 12. Eureka, a wholly-owned subsidiary of Eureka Midstream Holdings, has a $400 million senior secured revolving credit facility with Sumitomo Mitsui Banking Corporation, as administrative agent, the lenders party thereto from time to time and any other persons party thereto from time to time.

For the period beginning on July 22, 2024 and ending on September 30, 2024, under Eureka's revolving credit facility, both the maximum amount of outstanding borrowings and average daily balance was $330 million, and interest was incurred at a weighted average annual interest rate of 8.1%.

Eureka's revolving credit facility contains negative covenants that, among other things, limit restricted payments, incurrence of debt, dispositions, mergers and other fundamental changes and transactions with affiliates, in each case and as applicable, subject to certain specified exceptions. In addition, Eureka's revolving credit facility contains certain specified events of default, including insolvency, nonpayment of scheduled principal or interest obligations, loss and failure to replace certain material contracts, change of control and cross-default provisions related to the acceleration or default of certain other financial obligations.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

EQM's revolving credit facility. Immediately following the closing of the Equitrans Midstream Merger, on July 22, 2024, EQM repaid outstanding obligations under that certain Third Amended and Restated Credit Agreement, dated October 31, 2018, by and among EQM, Wells Fargo Bank, National Association, as administrative agent, swing line lender and L/C issuer, and the other financial institutions from time to time party thereto for principal of $705 million and interest and fees of $4.5 million using cash on hand and cash contributions from EQT funded by borrowings under EQT's revolving credit facility, and, thereafter, EQM terminated its revolving credit facility.

Term Loan Facility. On November 9, 2022, EQT entered into a Credit Agreement (as amended on December 23, 2022, April 25, 2023, January 16, 2024 and July 22, 2024, the Term Loan Agreement) with PNC Bank, National Association, as administrative agent, and the other lenders party thereto, under which such lenders agreed to make to EQT unsecured term loans in a single draw in an aggregate principal amount of up to $1.25 billion (the Term Loan Facility) to partly fund the Tug Hill and XcL Midstream Acquisition. On August 21, 2023, EQT borrowed $1.25 billion under the Term Loan Facility, receiving net proceeds of $1,242.9 million.

On January 16, 2024, EQT entered into a third amendment to the Term Loan Agreement to, among other things, extend the maturity date of the Term Loan Agreement from June 30, 2025 to June 30, 2026. The third amendment to the Term Loan Agreement became effective on January 19, 2024 upon EQT's prepayment of $750 million principal amount of the term loans outstanding under the Term Loan Facility (funded with the net proceeds from the issuance of EQT's 5.750% senior notes and cash on hand) and the satisfaction of other closing conditions. On July 22, 2024, EQT entered into a fourth amendment to the Term Loan Agreement to, among other things, make certain conforming changes to the Term Loan Agreement in alignment with the Fourth A&R Credit Agreement. Pursuant to the Term Loan Agreement, EQT may voluntarily prepay, in whole or in part, borrowings under the Term Loan Facility without premium or penalty but subject to reimbursement of funding losses with respect to prepayment of loans that bear interest based on the Term SOFR Rate (as defined in the Term Loan Agreement). Borrowings under the Term Loan Facility that are repaid may not be re-borrowed.

At EQT's election, the term loans outstanding under the Term Loan Facility bear interest at a Term SOFR Rate plus the SOFR Adjustment or Base Rate (both terms defined in the Term Loan Agreement), each plus a margin based on EQT's credit ratings. For both the three and nine months ended September 30, 2024, interest under the Term Loan Facility was incurred at a weighted average annual interest rate of 6.9%. For the period beginning on August 21, 2023 and ending on September 30, 2023, interest under the Term Loan Facility was incurred at a weighted average annual interest rate of 7.0%.

EQM's Senior Notes. Upon the closing of the Equitrans Midstream Merger, EQM became an indirect wholly-owned subsidiary of EQT, and EQM's outstanding senior notes were consolidated by the Company.

The indentures governing EQM's senior notes contain certain restrictive financial and operating covenants, including covenants that restrict, among other things, EQM's ability to incur, as applicable, indebtedness, incur liens, enter into sale and leaseback transactions, complete acquisitions, merge, sell assets and perform certain other corporate actions. Certain of EQM's senior notes also include an offer to repurchase provision applicable upon the occurrence of certain change of control events specified in the applicable indentures.

As of September 30, 2024, aggregate maturities for EQM's senior notes are zero for the three months ended December 31, 2024, $400 million in 2025, $500 million in 2026, $1,400 million in 2027, $850 million in 2028, $1,400 million in 2029 and $2,150 million thereafter.

EQT's 5.750% Senior Notes. On January 19, 2024, EQT issued $750 million aggregate principal amount of 5.750% senior notes due February 1, 2034. The Company used net proceeds of $742.0 million, composed of the principal amount of $750 million net of capitalized debt issuance costs and underwriters' discount of $8.0 million, and cash on hand to prepay $750 million principal amount of the term loans outstanding under the Term Loan Facility. The covenants of the 5.750% senior notes are consistent with EQT's existing senior unsecured notes.

EQT's 1.75% Convertible Notes. In April 2020, EQT issued $500 million aggregate principal amount of 1.75% convertible senior notes (the Convertible Notes). The effective interest rate for the Convertible Notes was 2.4%.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

On January 2, 2024, in accordance with the indenture governing the Convertible Notes (the Convertible Notes Indenture), EQT issued an irrevocable notice of redemption for all of the outstanding Convertible Notes and announced that EQT would redeem any of the Convertible Notes outstanding on January 17, 2024 in cash for 100% of the principal amount, plus accrued and unpaid interest on such Convertible Notes to, but excluding, such redemption date (the Redemption Price).

Pursuant to the Convertible Notes Indenture, between January 2, 2024 and the conversion deadline of 5:00 p.m., New York City time, on January 12, 2024, certain holders of the Convertible Notes exercised their right to convert their Convertible Notes prior to the redemption and validly surrendered an aggregate principal amount of $289.6 million of Convertible Notes. Based on a conversion rate of 69.0364 shares of EQT common stock per $1,000 principal amount of Convertible Notes, EQT issued to such holders an aggregate 19,992,482 shares of EQT common stock. Settlement of such Convertible Note conversion right exercises net of unamortized deferred issuance costs increased shareholder's equity by $285.6 million.

The remaining $0.6 million in outstanding principal amount of Convertible Notes was redeemed on January 17, 2024 in cash for the Redemption Price.

Inclusive of January 2024 settlements of Convertible Notes conversion right exercises that were exercised in December 2023, during January 2024, EQT settled $290.2 million aggregate principal amount of Convertible Notes conversion right exercises by issuing an aggregate 20,036,639 shares of EQT common stock to the converting holders at an average conversion price of $38.03.

Settlement and Termination of Capped Call Transactions. In connection with, but separate from, the issuance of the Convertible Notes, in 2020, EQT entered into capped call transactions (the Capped Call Transactions) with certain financial institutions (the Capped Call Counterparties) to reduce the potential dilution to EQT common stock upon any conversion of Convertible Notes at maturity and/or offset any cash payments that the Company is required to make in excess of the principal amount of such converted notes. The Capped Call Transactions had an initial strike price of $15.00 per share of EQT common stock and an initial cap price of $18.75 per share of EQT common stock, each of which were subject to certain customary adjustments, including adjustments as a result of EQT paying dividends on its common stock, and were set to expire in April 2026. The Company recorded the cost to purchase the Capped Call Transactions of $32.5 million as a reduction to shareholders' equity.

On January 18, 2024, EQT entered into separate termination agreements with each of the Capped Call Counterparties, pursuant to which the Capped Call Counterparties paid EQT an aggregate $93.3 million (the Termination Payments), and the Capped Call Transactions were terminated. EQT received the Termination Payments on January 22, 2024. The Termination Payments were recorded as an increase to shareholders' equity.

8. Investment in the MVP Joint Venture

The MVP Joint Venture. Upon the closing of the Equitrans Midstream Merger, the Company acquired an equity method investment in the MVP Joint Venture.

The MVP. The Company owned a 49.2% interest in the MVP as of September 30, 2024 and is the operator of the MVP. The MVP is a 303-mile long, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that spans from the Company's transmission and storage system in Wetzel County, West Virginia to Pittsylvania County, Virginia. Following receipt of authorization from the Federal Energy Regulatory Commission (the FERC), the MVP entered into service on June 14, 2024 and became available for interruptible or short-term firm transportation service. On July 1, 2024, the MVP commenced long-term firm capacity obligations. Estimated total project cost of the MVP is approximately $8.1 billion, excluding allowance for funds used during construction.

As of September 30, 2024, the Company had a negative basis difference between the carrying value of its equity method investment and its proportionate share of the MVP's net assets, which are composed of fixed assets. The basis difference is accreted over the life of the fixed assets and presented in income from investments in the Company's Statements of Condensed Consolidated Operations.

In September 2024, the MVP Joint Venture issued a capital call notice for the funding of the MVP project to the Company for $15.2 million, which was paid in October 2024. The capital contributions payable, which is presented in other current liabilities, and corresponding increase to the investment asset are included in the Condensed Consolidated Balance Sheet as of September 30, 2024.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

MVP Southgate. As of September 30, 2024, the Company owned a 47.2% interest in MVP Southgate. MVP Southgate is a contemplated interstate pipeline that was approved by the FERC and was initially designed to extend approximately 75 miles from the MVP in Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina using 24-inch and 16-inch diameter pipe.

In December 2023, the MVP Joint Venture entered into precedent agreements with Public Service Company of North Carolina, Inc. and Duke Energy Carolinas, LLC. The precedent agreements contemplate an amended project and, among other things, describe certain conditions precedent to the parties' respective obligations regarding MVP Southgate. As amended, the natural gas interstate pipeline would extend approximately 31 miles from the terminus of the MVP in Pittsylvania County, Virginia to planned new delivery points in Rockingham County, North Carolina using 30-inch diameter pipe and have a targeted capacity of 550,000 dekatherms per day. Completion of the MVP Southgate pipeline is targeted for June 2028. The Company expects to operate the MVP Southgate pipeline.

Pursuant to the MVP Joint Venture's limited liability company agreement and upon the closing of the Equitrans Midstream Merger, the Company is obligated to provide performance assurances with respect to MVP Southgate that may take the form of a guarantee from EQM (provided that, in accordance with the requirements of the MVP Joint Venture's limited liability company agreement, EQM's debt is assigned an investment grade credit rating), a letter of credit or cash collateral. Upon receipt of the FERC's initial release to begin construction of the MVP Southgate project, the Company will be obligated to provide performance assurance in an amount equal to 33% of its share of MVP Southgate's remaining capital commitments.

9. (Loss) Income Per Share

The table below provides the computation for basic and diluted (loss) income per share.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands, except per share amounts)
Net (loss) income attributable to EQT Corporation – Basic (loss) income available to shareholders	$	(300,823)	$	81,255	$	(187,818)	$	1,233,177
Add back: Interest expense on Convertible Notes, net of tax (a)	—		2,042		—		6,117
Diluted (loss) income available to shareholders	$	(300,823)	$	83,297	$	(187,818)	$	1,239,294

Weighted average common stock outstanding – Basic	559,603		383,359		480,354		368,936
Options, restricted stock, performance awards and stock appreciation rights (a)	—		4,398		—		4,606
Convertible Notes (a)	—		28,433		—		28,317
Weighted average common stock outstanding – Diluted	559,603		416,190		480,354		401,859

(Loss) income per share of common stock attributable to EQT Corporation:
Basic	$	(0.54)	$	0.21	$	(0.39)	$	3.34
Diluted	$	(0.54)	$	0.20	$	(0.39)	$	3.08

(a)In periods when the Company reports a net loss, all options, restricted stock, performance awards and stock appreciation awards, as applicable, are excluded from the calculation of diluted weighted average shares outstanding because of their anti-dilutive effect on loss per share. As a result, for the three and nine months ended September 30, 2024, all such securities of 7.6 million and 6.0 million, respectively, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share.

In addition, prior to EQT's redemption of the Convertible Notes, the Company used the if-converted method to calculate the impact of the Convertible Notes on diluted (loss) income per share. For the nine months ended September 30, 2024, such if-converted securities of approximately 0.5 million as well as the related add back of interest expense on the Convertible Notes, net of tax, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

10. Share-based Compensation

In 2024, the Management Development and Compensation Committee of the Company's Board of Directors (the Compensation Committee) adopted the 2024 Incentive Performance Share Unit Program (2024 Incentive PSU Program) under the 2020 Long-Term Incentive Plan. During the nine months ended September 30, 2024, a total of 371,500 share units were granted under the 2024 Incentive PSU Program. The payout of the share units will vary between zero and 200% of the number of outstanding units contingent upon the Company's absolute total shareholder return and total shareholder return relative to a predefined peer group over the period of January 1, 2024 through December 31, 2026.

During the nine months ended September 30, 2024, the Compensation Committee granted 995,620 restricted stock unit equity awards that follow a three-year graded vesting schedule commencing with the date of grant, assuming continued employment through each vesting date. The share total includes the Company's "equity-for-all" program, instituted in 2021, pursuant to which the Company grants equity awards to all permanent employees.

In conjunction with the Equitrans Midstream Merger, the Company assumed all outstanding and unvested share-based compensation awards of Equitrans Midstream Corporation (Equitrans Midstream) and converted those assumed awards into 5,175,814 restricted stock unit equity awards that maintained the assumed awards' prior vesting schedules, assuming continued employment through each vesting date.

11. Acquisitions and Divestitures

Tug Hill and XcL Midstream Acquisition. On August 22, 2023, the Company completed its acquisition (the Tug Hill and XcL Midstream Acquisition) of the upstream assets from THQ Appalachia I, LLC and the gathering and processing assets from THQ-XcL Holdings I, LLC through the acquisition of all of the issued and outstanding membership interests of each of THQ Appalachia I Midco, LLC and THQ-XcL Holdings I Midco, LLC. The purchase price for the Tug Hill and XcL Midstream Acquisition consisted of 49,599,796 shares of EQT common stock and approximately $2.4 billion in cash, subject to customary post-closing adjustments.

The Company accounted for the Tug Hill and XcL Midstream Acquisition as a business combination using the acquisition method. The Company completed the purchase price allocation for the Tug Hill and XcL Midstream Acquisition during the first quarter of 2024. The purchase accounting adjustments recorded in 2024 were not material.

NEPA Gathering System Acquisition. The Company operates and has historically owned a 50% interest in gathering assets located in Northeast Pennsylvania (collectively, the NEPA Gathering System). On April 11, 2024, the Company completed its acquisition of a minority equity partner's 33.75% interest in the NEPA Gathering System for a purchase price of approximately $205 million (the NEPA Gathering System Acquisition), subject to customary post-closing adjustments. The NEPA Gathering System Acquisition was accounted for as an asset acquisition and, as such, its purchase price was allocated to property, plant and equipment.

NEPA Non-Operated Asset Divestiture. On May 31, 2024, the Company completed the divestiture (the NEPA Non-Operated Asset Divestiture) of an undivided 40% interest in the Company's non-operated natural gas assets in Northeast Pennsylvania with a carrying amount of approximately $522 million to Equinor USA Onshore Properties Inc. and its affiliates (collectively, the Equinor Parties). The carrying value was composed of approximately $549 million of property, plant and equipment, approximately $7 million of other current liabilities and approximately $20 million of other liabilities and credits. In exchange, as consideration, the Company received from the Equinor Parties cash of $500 million, subject to customary post-closing purchase price adjustments, certain upstream assets and the remaining 16.25% equity interest in the NEPA Gathering System. The total fair value of consideration received, net of liabilities assumed, was approximately $842 million, subject to customary post-closing purchase price adjustments, and included $413 million of property, plant and equipment.

As a result of the NEPA Non-Operated Asset Divestiture, for the nine months ended September 30, 2024, the Company recognized a gain of approximately $312 million in loss (gain) on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations, inclusive of an $8 million loss recognized for the three months ended September 30, 2024. The gain was calculated as the carrying value of divested assets less the fair value of consideration received, net of liabilities assumed and divestiture costs incurred of approximately $8 million. Cash proceeds from the NEPA Non-Operated Asset Divestiture were used to partly fund EQT's redemption of its 6.125% senior notes.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

The fair values of the natural gas properties received as consideration for the NEPA Non-Operated Asset Divestiture were measured using discounted cash flow valuation techniques based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include future commodity prices, projections of estimated quantities of reserves, estimated future rates of production, projected reserve recovery factors, timing and amount of future development and operating costs and a weighted average cost of capital.

The fair value of the undeveloped properties received as consideration for the NEPA Non-Operated Asset Divestiture were measured using the guideline transaction method based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include future development plans from a market participant perspective.

The fair value of the interest in the NEPA Gathering System received as consideration for the NEPA Non-Operated Asset Divestiture was measured using the cost approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include replacement cost for similar assets, relative age of the assets and potential economic or functional obsolescence.

See Note 5 for a description of the fair value hierarchy.

In addition, subsequent to the completion of the NEPA Non-Operated Asset Divestiture, the Company and the Equinor Parties entered into a gas buy-back agreement with respect to the assets received by the Company as consideration for the NEPA Non-Operated Asset Divestiture, whereby the Equinor Parties agreed to purchase a specified amount of natural gas from the Company through the first quarter of 2028.

Remaining NEPA Non-Operated Assets Divestiture. On October 29, 2024, the Company entered into an agreement with the Equinor Parties, pursuant to which the Company agreed to sell to the Equinor Parties the Company's remaining, undivided 60% interest in the Company's non-operated natural gas assets in Northeast Pennsylvania. In exchange, the Company will receive from the Equinor Parties $1.25 billion of cash (the Remaining NEPA Non-Operated Assets Divestiture). The Company intends to use the proceeds from the Remaining NEPA Non-Operated Assets Divestiture for repayment of the Company's debt. The Remaining NEPA Non-Operated Assets Divestiture is subject to customary closing adjustments, required regulatory approvals and clearances.

12. Equitrans Midstream Merger

On July 22, 2024, the Company completed the Equitrans Midstream Merger pursuant to the agreement and plan of merger dated March 10, 2024 (the Merger Agreement), by and among EQT, Humpty Merger Sub Inc., an indirect wholly-owned subsidiary of EQT (Merger Sub), Humpty Merger Sub LLC, an indirect wholly-owned subsidiary of EQT (LLC Sub), and Equitrans Midstream.

Upon the terms and subject to the conditions set forth in the Merger Agreement, Merger Sub merged with and into Equitrans Midstream (the First Merger), with Equitrans Midstream surviving as an indirect wholly-owned subsidiary of EQT (the First Step Surviving Corporation), and, as the second step in a single integrated transaction with the First Merger, the First Step Surviving Corporation merged with and into LLC Sub (the Second Merger and, together with the First Merger, the Equitrans Midstream Merger), with LLC Sub surviving the Second Merger as an indirect wholly-owned subsidiary of EQT.

Upon the closing of the Equitrans Midstream Merger, each share of common stock, no par value, of Equitrans Midstream (Equitrans Midstream common stock) that was issued and outstanding immediately prior to the effective time of the First Merger (other than shares of Equitrans Midstream common stock owned by Equitrans Midstream or its subsidiaries or by the Company) was converted into the right to receive, without interest, 0.3504 shares of EQT common stock, which totaled 152,427,848 shares of EQT common stock with an aggregate value of $5.5 billion, based on an EQT common stock share price of $35.88. In addition, in connection with the closing of the Equitrans Midstream Merger, the Company paid an aggregate of $79.5 million of equity consideration to employees of Equitrans Midstream who did not continue with the Company following the Equitrans Midstream Merger closing date.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Immediately prior to the completion of the Equitrans Midstream Merger, on July 22, 2024, using borrowings under EQT's revolving credit facility, the Company paid $685.3 million to effect the purchase and redemption of all of the issued and outstanding Series A Perpetual Convertible Preferred Shares, no par value, of Equitrans Midstream (the Equitrans Midstream preferred stock).

Immediately following the closing of the Equitrans Midstream Merger, on July 22, 2024, EQM repaid all of its outstanding obligations under EQM's revolving credit facility using cash on hand and cash contributions from EQT, and, thereafter, EQM terminated its revolving credit facility. See Note 7.

Upon completion of the Equitrans Midstream Merger, the pre-existing contractual relationships between the Company, as producer, and Equitrans Midstream, as gathering and transmission services provider, are treated as intercompany transactions on a consolidated basis and, as such, were effectively settled on July 22, 2024. Likewise, upon completion of the Equitrans Midstream Merger, EQT's note payable to EQM became an intercompany transaction on a consolidated basis and, as such, was effectively settled on July 22, 2024.

For the three and nine months ended September 30, 2024, the Company recognized $274.6 million and $298.7 million, respectively, of transaction costs related to the Equitrans Midstream Merger within other operating expenses in the Statements of Condensed Consolidated Operations.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Allocation of Purchase Price. The Equitrans Midstream Merger was accounted for as a business combination using the acquisition method. The table below summarizes the preliminary purchase price and estimated fair values of assets acquired and liabilities assumed as of July 22, 2024 with the excess of purchase price over estimated fair value of the identified net assets recognized as goodwill. Certain information necessary to complete the purchase price allocation is not yet available, including, but not limited to, final appraisals of assets acquired and liabilities assumed and final income tax computations. The Company expects to complete the purchase price allocation once it has received all necessary information, at which time the value of the assets acquired and liabilities assumed will be revised if necessary.


	Preliminary Purchase Price Allocation

	(Thousands)
Consideration:
Equity	$	5,548,608
Cash (paid in lieu of fractional shares)	29
Redemption of Equitrans Midstream preferred stock	685,337
Settlement of pre-existing relationships	(237,662)
Total consideration	$	5,996,312

Fair value of assets acquired:
Cash and cash equivalents	$	58,767
Accounts receivable, net	85,308
Income tax receivable	2,192
Prepaid expenses and other	22,048
Property, plant and equipment	9,387,823
Investment in the MVP Joint Venture	3,222,311
Net intangible assets	250,000
Other assets	240,248
Noncontrolling interest in consolidated subsidiaries	(144,894)
Amount attributable to assets acquired	$	13,123,803

Fair value of liabilities assumed:
Current portion of debt	$	699,837
Accounts payable	65,761
Accrued interest	47,996
Other current liabilities	76,563
Revolving credit facility borrowings	1,035,000
Senior notes	6,273,941
Deferred income taxes	961,894
Other liabilities and credits	144,735
Amount attributable to liabilities assumed	$	9,305,727

Goodwill	$	2,178,236

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

The fair value of Equitrans Midstream's property, plant and equipment, which primarily includes gathering systems, transmission and storage systems and water infrastructure assets, and Equitrans Midstream's equity method investment in the MVP Joint Venture was measured using a combination of a cost and income approach based on inputs that are not observable in the market and, as such, are Level 3 fair value measurements. Significant inputs to the valuation of Equitrans Midstream's property, plant and equipment and investment in the MVP Joint Venture include replacement costs for similar assets, relative age of the assets, any potential economic or functional obsolescence associated with the assets, future revenue estimates and future operating cost assumptions and estimated weighted average costs of capital.

The fair value of the noncontrolling interest in Eureka Midstream Holdings was calculated using the noncontrolling interest ownership percentage and the enterprise value of Eureka Midstream Holdings, which was measured using a combination of a cost and income approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs to the valuation of the noncontrolling interest in Eureka Midstream Holdings include replacement costs for similar assets, relative age of the assets, any potential economic or functional obsolescence associated with the assets, future revenue estimates, future operating cost assumptions and estimated weighted average cost of capital.

As part of the preliminary purchase price allocation, the Company identified intangible assets related to certain of Equitrans Midstream's transmission services contracts. The fair value of the identified intangible assets was determined using the income approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs to the valuation of the identified intangible assets include future revenue estimates, future cost assumptions, estimated contract renewals, a discount rate assumption and an estimated required rate of return on the assets. The identified intangible assets are amortized over their useful life of 15 years on a straight-line basis, which reflects the pattern in which the Company expects to consume the economic benefits of the assets.

The fair value of EQM's senior notes was measured using established fair value methodology. Because not all of EQM's senior notes are actively traded, their fair value is a Level 2 fair value measurement. The difference between the fair value and principal amount of the assumed senior notes is amortized over the remaining life of the debt. The unamortized amount is presented as a reduction of debt in the Condensed Consolidated Balance Sheet. Because the carrying value of borrowings under EQM's revolving credit facility and Eureka's revolving credit facility approximated their respective fair value (as each facility's interest rate is based on prevailing market rates), the Company considers their fair values to be Level 1 fair value measurements.

Goodwill is attributable to the Company's qualitative assumptions of long-term value that the Equitrans Midstream Merger creates for EQT shareholders. Of the total goodwill, the Company attributed $1.3 billion to synergies expected from the vertical integration of the business, including from the elimination of contracted transportation and processing costs with Equitrans Midstream as the Company is unable to recognize intangible assets related to its significant long-term customer contracts with Equitrans Midstream as such contracts became intercompany transactions upon the closing of the Equitrans Midstream Merger. In addition, the Company attributed $0.9 billion of total goodwill to additional deferred tax liabilities that arose from the differences between the preliminary purchase price allocation based on fair value and tax basis that carried over from Equitrans Midstream to the Company. The Company allocated all of the goodwill from the Equitrans Midstream Merger to the Company's Transmission segment. Differences between the preliminary purchase price allocation and the final purchase price allocation may change the amount of goodwill recognized.

In conjunction with the Equitrans Midstream Merger, as of the Equitrans Midstream Merger closing date, the Company had unamortized carryover tax basis of $647.2 million of tax deductible goodwill.

See Note 5 for a description of the fair value hierarchy.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Post-Acquisition Operating Results. The table below summarizes amounts contributed by the assets acquired in the Equitrans Midstream Merger, inclusive of intercompany eliminations, to the Company's consolidated results for the period beginning on July 22, 2024 and ending on September 30, 2024.


	July 22, 2024 through September 30, 2024

	(Thousands)
Loss on derivatives	$	(5,673)
Pipeline, net marketing services and other	110,403
Total operating revenues	$	104,730

Net loss	$	(159,313)
Less: Net income attributable to noncontrolling interests	3,687
Net loss attributable to EQT Corporation	$	(163,000)

Unaudited Pro Forma Information. The table below summarizes the Company's results as though the Equitrans Midstream Merger had been completed on January 1, 2023. Certain historical amounts were reclassified to conform to the Company's current financial presentation of operations. Such unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Equitrans Midstream Merger occurred on January 1, 2023 nor are they indicative of future consolidated results of operations.


	Nine Months Ended September 30,
	2024		2023

	(Thousands, except per share amounts)
Pro forma operating revenues:
Pro forma sales of natural gas, NGLs and oil	$	3,293,174	$	3,680,566
Pro forma gain on derivatives	201,228		1,221,557
Pro forma pipeline, net marketing services and other	454,136		456,082
Pro forma total operating revenues	$	3,948,538	$	5,358,205

Pro forma net income	$	19,543	$	1,677,891
Less: Pro forma net income attributable to noncontrolling interests	17,696		21,891
Pro forma net income attributable to EQT Corporation	$	1,847	$	1,656,000

Pro forma income per share of common stock attributable to EQT Corporation:
Pro forma net income attributable to EQT Corporation – Basic	$	0.00	$	4.49
Pro forma net income attributable to EQT Corporation – Diluted	$	0.00	$	4.14

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

13. Commitments and Contingencies

Purchase Obligations

The following table summarizes the Company's commitments to pay demand charges under long-term contracts and binding precedent agreements with various pipelines and charges for processing capacity. The table presents the year or years in which such commitments are to be paid as of September 30, 2024 and December 31, 2023.


	As of September 30, 2024		As of December 31, 2023

	(Billions)
2024 (a)	$	0.2	$	1.8
2025	0.8		1.8
2026	0.7		1.7
2027	0.7		1.7
2028	0.6		1.4
Thereafter	4.2		13.6
Total	$	7.2	$	22.0

(a)As of September 30, 2024, the noted amount represented commitments payable for the three months ended December 31, 2024; as of December 31, 2023, the noted amount represented commitments payable for the year ended December 31, 2024.

The following table summarizes the Company's commitments to pay for services related to its operations, including electric hydraulic fracturing services, and purchase equipment, materials and sand. The table presents the year or years in which such commitments are to be paid as of September 30, 2024 and December 31, 2023.


	As of September 30, 2024		As of December 31, 2023

	(Millions)
2024 (a)	$	60.7	$	228.8
2025	194.6		164.5
2026	148.4		138.0
2027	88.2		111.0
2028	37.9		72.9
Thereafter	—		107.9
Total	$	529.8	$	823.1

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Legal and Regulatory Proceedings

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company. While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings.

The Company evaluates its legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrues a loss for such matters when the Company believes that it is probable a liability has been incurred and the amount of the loss can be reasonably estimated. In such cases, if some amount within a range of loss appears to be a better estimate than any other amount within the range, that amount is accrued; however, when no amount within the range is a better estimate than any other amount, the minimum amount in the range is accrued. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event the Company determines that (i) it is probable a liability has been incurred but the amount of the loss cannot be reasonably estimated, or (ii) it less likely than probable but is reasonably possible that a liability has been incurred, then the Company is required to disclose the matter in its Annual Report on Form 10-K with any update thereto in this Quarterly Report on Form 10-Q, as applicable, although the Company is not required to accrue such loss.

When able, the Company determines an estimate of reasonably possible losses or ranges of reasonably possible losses, whether in excess of any related accrued loss or where there is no accrued loss, for legal proceedings. In instances where such estimates can be made, any such estimates are based on the Company's analysis of currently available information and are subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained.

The ultimate outcome of the matters described below is inherently uncertain. Furthermore, due to the inherent subjectivity of the assessments and unpredictability of outcomes of legal proceedings, any amounts accrued or estimated as possible losses may not represent the ultimate loss to the Company from the legal proceedings in question and the Company's exposure and ultimate losses may be higher, and possibly significantly so, than the amounts accrued or estimated.

Securities Class Action Litigation. On December 6, 2019, an amended putative class action complaint was filed in the United States District Court for the Western District of Pennsylvania by Cambridge Retirement System, Government of Guam Retirement Fund, Northeast Carpenters Annuity Fund, and Northeast Carpenters Pension Fund, on behalf of themselves and all those similarly situated, against EQT, and certain former executives and current and former board members of EQT (the Securities Class Action). The complaint alleges that certain statements made by EQT regarding its merger with Rice Energy Inc. in 2017 were materially false and violated various federal securities laws. Pursuant to the complaint, the plaintiffs seek compensatory or rescissory damages in an unspecified amount for all damages allegedly sustained by the class as a result of alleged negative impacts to EQT's stock price in 2018 and 2019.

Additionally, following the filing of the Securities Class Action complaint, several other lawsuits were filed in the United States District Court for the Western District of Pennsylvania and the Court of Common Pleas of Allegheny County, Pennsylvania by certain shareholders of EQT against EQT and certain former executives and current and former board members of EQT asserting substantially the same allegations as those raised in the Securities Class Action. These matters are currently pending, the majority of which have been stayed pending a ruling on dispositive motions in the Securities Class Action.

Following the commencement of the Securities Class Action, the parties engaged in fact and expert discovery. In June 2024, the discovery phase of the Securities Class Action was completed. On June 27, 2024, the parties to the Securities Class Action participated in a mediation (the Mediation), which did not result in resolution. A trial date for the Securities Class Action has not been determined.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

In the second quarter of 2024, the Company recorded an accrual for estimated loss contingencies associated with the Securities Class Action in an amount equal to the settlement offer the Company tendered at the Mediation. Due to the inherent subjectivity of the assessments and unpredictability of outcomes of legal proceedings, the amount accrued for estimated losses associated with the Securities Class Action may not represent the ultimate loss to the Company, and the Company's exposure and ultimate losses may be higher, and possibly significantly so, than the amounts accrued or estimated. The amount accrued for such estimated losses is based on the Company's analysis of currently available information and is subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained. While the parties have completed discovery, various motions, including dispositive motions, have not yet been decided, the matters present meaningful legal uncertainties, and predicting the outcome depends on making assumptions about future decisions of courts and the behavior of other parties for which the Company does not currently have sufficient information. Given these uncertainties, the Company is unable at this time to reasonably estimate the range of possible additional losses above the amount accrued. The Company disputes the claims asserted in the Securities Class Action and related litigation and believes it has meritorious defenses, but unpredictability is inherent in litigation and the Company cannot predict the outcomes with any certainty.

See Note 11 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, 2023 for additional discussion of the Company's commitments and contingencies, including certain other pending legal and regulatory proceedings and other contingent matters. As of September 30, 2024, except as disclosed herein, there have been no material changes to such matters disclosed therein.

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Management's Discussion and Analysis of Financial Condition and Results of Operations

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of financial condition and results of operations should be read in conjunction with the Condensed Consolidated Financial Statements and the notes thereto included in this report. Unless the context otherwise indicates, all references in this report to "EQT" are to EQT Corporation and all references in this report to the "Company," "we," "us," or "our" are to EQT Corporation and its consolidated subsidiaries, collectively. For certain industry specific terms used in this Quarterly Report on Form 10-Q, please see "Glossary of Commonly Used Terms, Abbreviations and Measurements" in our Annual Report on Form 10-K for the year ended December 31, 2023.

CAUTIONARY STATEMENTS

This Quarterly Report on Form 10-Q contains certain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and Section 27A of the Securities Act of 1933, as amended (the Securities Act). Statements that do not relate strictly to historical or current facts are forward-looking and are usually identified by the use of words such as "anticipate," "estimate," "could," "would," "will," "may," "forecast," "approximate," "expect," "project," "intend," "plan," "believe" and other words of similar meaning, or the negative thereof. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10-Q include the matters discussed in the section "Trends and Uncertainties" and expectations of our plans, strategies, objectives and growth and anticipated financial and operational performance, including guidance regarding our strategy to develop our reserves; drilling plans and programs, including availability of capital to complete these plans and programs; total resource potential and drilling inventory duration; projected production and sales volume, including liquified natural gas (LNG) volumes and sales; natural gas prices; changes in basis and the impact of commodity prices on our business; potential future impairments of our assets; projected well costs and capital expenditures; infrastructure programs; the cost, capacity and timing of obtaining regulatory approvals; our ability to successfully implement and execute our operational, organizational, technological and environmental, social and governance (ESG) initiatives, and achieve the anticipated results of such initiatives; projected gathering and compression rates; potential divestitures, acquisitions or other strategic transactions, the timing thereof and our ability to achieve the intended operational, financial and strategic benefits from any such transactions or from any recently completed strategic transactions, including the Equitrans Midstream Merger (defined and discussed in Note 12 to the Condensed Consolidated Financial Statements); the amount and timing of any repayments, redemptions or repurchases of our common stock, outstanding debt securities or other debt instruments; our ability to retire our debt and the timing of such retirements, if any; the projected amount and timing of dividends; projected cash flows and free cash flow, and the timing thereof; liquidity and financing requirements, including funding sources and availability; our ability to maintain or improve our credit ratings, leverage levels and financial profile; our hedging strategy and projected margin posting obligations; the effects of litigation, government regulation and tax position; and the expected impact of changes to tax laws.

The forward-looking statements included in this Quarterly Report on Form 10-Q involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. We have based these forward-looking statements on current expectations and assumptions about future events, taking into account all information currently known by us. While we consider these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks and uncertainties, many of which are difficult to predict and beyond our control. These risks and uncertainties include, but are not limited to, volatility of commodity prices; the costs and results of drilling and operations; uncertainties about estimates of reserves, identification of drilling locations and the ability to add proved reserves in the future; the assumptions underlying production forecasts; the quality of technical data; our ability to appropriately allocate capital and other resources among our strategic opportunities; access to and cost of capital; our hedging and other financial contracts; inherent hazards and risks normally incidental to drilling for, producing, transporting and storing natural gas, natural gas liquids (NGLs) and oil; operational risks and hazards incidental to the gathering, transmission and storage of natural gas as well as unforeseen interruptions; cyber security risks and acts of sabotage; availability and cost of drilling rigs, completion services, equipment, supplies, personnel, oilfield services and sand and water required to execute our exploration and development plans, including as a result of inflationary pressures; risks associated with operating primarily in the Appalachian Basin; the ability to obtain environmental and other permits and the timing thereof; construction, business, economic, competitive, regulatory, judicial, environmental, political and legal uncertainties related to the development and construction by us or our joint ventures of pipeline and storage facilities and transmission assets and the optimization of such assets; our ability to renew or replace expiring gathering, transmission or storage contracts at favorable rates on a long-term basis or at all; risks relating to our joint venture arrangements; government regulation or action, including regulations pertaining to methane and other greenhouse gas emissions; negative public perception of the fossil fuels industry; increased consumer demand for alternatives to natural gas; environmental and weather risks, including the possible impacts of climate change; risks related to our ability to integrate the operations of Equitrans Midstream Corporation

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Management's Discussion and Analysis of Financial Condition and Results of Operations

(Equitrans Midstream) in a successful manner and in the expected time period and the possibility that any of the anticipated benefits and projected synergies of the Equitrans Midstream Merger will not be realized or will not be realized within the expected time period; and disruptions to our business due to recently completed acquisitions and other significant transactions, including the Equitrans Midstream Merger. These and other risks and uncertainties are described under the "Risk Factors" section in this Quarterly Report on Form 10-Q and under the "Risk Factors" section and elsewhere in our Annual Report on Form 10-K for the year ended December 31, 2023, and may be updated by other documents we subsequently file from time to time with the Securities and Exchange Commission (the SEC).

Any forward-looking statement speaks only as of the date on which such statement is made, and, except as required by law, we do not intend to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise.

Recent Events

On July 22, 2024, we completed the Equitrans Midstream Merger. As a result of the Equitrans Midstream Merger, we acquired over 2,000 miles of pipeline infrastructure that have extensive overlap and connectivity in our core area of operations, and we became the first large-scale, integrated natural gas producer in the United States. Refer to Note 12 to the Condensed Consolidated Financial Statements.

During the second quarter of 2024, we divested a portion of our non-operated assets in Northeast Pennsylvania (the NEPA Non-Operated Asset Divestiture), as discussed in Note 11 to the Condensed Consolidated Financial Statements. On October 29, 2024, we entered into an agreement to divest the remaining interest in our non-operated assets in Northeast Pennsylvania in exchange for $1.25 billion of cash (the Remaining NEPA Non-Operated Assets Divestiture). We intend to use the proceeds from the Remaining NEPA Non-Operated Assets Divestiture for repayment of our debt. The Remaining NEPA Non-Operated Assets Divestiture is subject to customary closing adjustments, required regulatory approvals and clearances.

Trends and Uncertainties

The Mountain Valley Pipeline

Following receipt of authorization from the Federal Energy Regulatory Commission (the FERC), the Mountain Valley Pipeline (the MVP) entered into service on June 14, 2024. Upon commencement of long-term firm capacity obligations, the MVP In-Service Date (defined in Note 8 to the Condensed Consolidated Financial Statements) occurred on July 1, 2024. Our Production segment is committed to an initial 1.29 billion cubic feet (Bcf) per day of firm capacity on the MVP through June 30, 2044. Accordingly, as a result of the occurrence of the MVP In-Service Date, we expect our Production segment's future (i) transmission expense to increase as a result of the additional contracted capacity and (ii) gathering expense to decrease pursuant to the terms of the Consolidated GGA (defined in Note 2 to the Condensed Consolidated Financial Statements).

The MVP Joint Venture (defined in Note 1 to the Condensed Consolidated Financial Statements) has continued to make restoration efforts with respect to the MVP. Estimated total project cost of the MVP is approximately $8.1 billion, excluding allowance for funds used during construction. Of this amount, $100.4 million was contributed by us following our closing of the Equitrans Midstream Merger, including the $15.2 million payable as of September 30, 2024, which was paid in October 2024.

Curtailments and Commodity Prices

On March 4, 2024, we announced our decision to strategically curtail approximately 1.0 Bcf per day of gross production (the Strategic Curtailment) beginning on February 24, 2024 in response to the low natural gas price environment resulting from warm winter weather and elevated storage inventories. The Strategic Curtailment resulted in total decreased sales volume of 82 billion cubic feet of natural gas equivalents (Bcfe) during the period beginning on February 24, 2024 and ending on June 19, 2024 and 25 Bcfe during the period beginning July 4, 2024 and ending on September 30, 2024. In response to market fundamentals, we expect to continue to strategically curtail our production. Our sales volume guidance assumes 10 to 15 Bcfe of curtailments during the fourth quarter of 2024.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Continued low natural gas prices may result in further adjustments to our 2024 planned development schedule or the development schedule of non-operated wells in which we have a working interest. Further, we cannot control or otherwise influence the development schedule of non-operated wells in which we have a working interest. Certain operators of wells in which we have a non-operating working interest also curtailed production in 2024. For the three months ended September 30, 2024, we estimate that our total expected sales volume was negatively impacted by approximately 35 Bcfe of curtailments, including our Strategic Curtailment of 25 Bcfe and curtailments by certain operators of wells in which we have a non-operating working interest. For the nine months ended September 30, 2024, we estimate that our total expected sales volume was negatively impacted by approximately 125 to 130 Bcfe of curtailments, including our Strategic Curtailment of 107 Bcfe and curtailments by certain operators of wells in which we have a non-operating working interest. Adjustments to our 2024 planned development schedule or the development schedule of non-operated wells in which we have a working interest, including due to declines in natural gas prices, the pace of well completions, access to sand and water to conduct drilling operations, access to sufficient pipeline takeaway capacity, unscheduled downtime at processing facilities or otherwise, could impact our future sales volume, operating revenues and expenses, per unit metrics and capital expenditures.

The annual inflation rate in the United States remains elevated compared to the rate of inflation over the prior five years. Inflationary pressures have multiple impacts on our business, including increasing our operating expenses and our cost of capital. While the prices for certain of the raw materials and services we use in our operations have generally decreased from the peak prices experienced during 2022, we will not fully realize the benefit of such reduced prices until we enter into new contracts for such materials and services, and inflationary pressures may cause prices to fluctuate. Additionally, certain of our commitments for demand charges under our existing long-term contracts and processing capacity are subject to consumer price index adjustments. Although we believe our scale and supply chain contracting strategy of using multi-year sand and frac crew contracts allows us to maximize capital and operating efficiencies, future increases in the inflation rate will negatively impact our long-term contracts with consumer price index adjustments.

We expect commodity prices to be volatile through 2024 due to macroeconomic uncertainty and geopolitical tensions, including developments pertaining to Russia's invasion of Ukraine and conflicts in the Middle East. Our revenue, profitability, liquidity and financial position will continue to be impacted in the future by the market prices for natural gas and, to a lesser extent, NGLs and oil.

Consolidated Results of Operations

Net loss attributable to EQT Corporation for the three months ended September 30, 2024 was $300.8 million, $0.54 per diluted share, compared to net income attributable to EQT Corporation of $81.3 million, $0.20 per diluted share, for the same period in 2023. The change was attributable primarily to increased other operating expenses, increased depreciation, depletion and amortization, a lower gain on derivatives and increased net interest expense, partly offset by decreased transportation and processing expense and increased cash operating revenues, including pipeline revenues, which increased as a result of our operation of assets acquired in the Equitrans Midstream Merger.

Net loss attributable to EQT Corporation for the nine months ended September 30, 2024 was $187.8 million, $0.39 per diluted share, compared to net income attributable to EQT Corporation of $1,233.2 million, $3.08 per diluted share, for the same period in 2023. The change was attributable primarily to lower gain on derivatives, decreased sales of natural gas, NGLs and oil, increased depreciation, depletion and amortization expense, increased other operating expenses, increased net interest expense and increased production expense, partly offset by recognition of an income tax benefit in 2024 compared to an income tax expense in 2023, the gain on the NEPA Non-Operated Asset Divestiture and increased pipeline revenues, which increased as a result of our operation of assets acquired in the Equitrans Midstream Merger.

Results of operations for the three and nine months ended September 30, 2024 include the results of our operation of assets acquired in the Equitrans Midstream Merger, which closed on July 22, 2024. See Note 12 to the Condensed Consolidated Financial Statements.

Results of operations for the nine months ended September 30, 2024 include the results of our operation of assets received as consideration for the NEPA Non-Operated Asset Divestiture, which closed on May 31, 2024. Such assets received included the remaining 16.25% equity interest in the NEPA Gathering System (defined in Note 11 to the Condensed Consolidated Financial Statements) (which was the sole remaining minority interest following our acquisition of a 33.75% equity interest in the NEPA Gathering System Acquisition (defined in Note 11 to the Condensed Consolidated Financial Statements) on April 11, 2024), resulting in our 100% ownership of the NEPA Gathering System. See Note 11 to the Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

In addition, results of operations for the nine months ended September 30, 2024 include the results of our operation of assets acquired in the Tug Hill and XcL Midstream Acquisition (defined in Note 11 to the Condensed Consolidated Financial Statements), which closed on August 22, 2023.

See "Average Realized Price Reconciliation" for a discussion and calculation of our average realized price, which is based on Production adjusted operating revenues, a non-GAAP supplemental financial measure that has been reconciled from total operating revenues in "Non-GAAP Financial Measures Reconciliation."

See "Business Segment Results of Operations" for a discussion of segment operating revenues and expenses and "Unallocated and Other Income Statement Items" for a discussion of other, unallocated income statement items.

See "Investing Activities" under "Capital Resources and Liquidity" for a discussion of capital expenditures, including by business segment.

Average Realized Price Reconciliation

The following table presents detailed natural gas and liquids operational information to assist in the understanding of our consolidated operations, including the calculation of our average realized price ($/Mcfe), which is based on Production adjusted operating revenues, a non-GAAP supplemental financial measure. Production adjusted operating revenues is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Production adjusted operating revenues should not be considered as an alternative to total operating revenues. See "Non-GAAP Financial Measures Reconciliation" for a reconciliation of Production adjusted operating revenues from total operating revenues, the most directly comparable financial measure calculated in accordance with United States generally accepted accounting principles (GAAP).

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)	547,225		491,472		1,520,574		1,374,527
NYMEX price ($/MMBtu)	$	2.15	$	2.55	$	2.12	$	2.68
Btu uplift	0.12		0.13		0.12		0.14
Natural gas price ($/Mcf)	$	2.27	$	2.68	$	2.24	$	2.82

Basis ($/Mcf) (a)	$	(0.56)	$	(0.93)	$	(0.40)	$	(0.39)
Cash settled basis swaps ($/Mcf)	(0.09)		0.12		(0.10)		(0.08)
Average differential, including cash settled basis swaps ($/Mcf)	$	(0.65)	$	(0.81)	$	(0.50)	$	(0.47)
Average adjusted price ($/Mcf)	$	1.62	$	1.87	$	1.74	$	2.35
Cash settled derivatives ($/Mcf)	0.61		0.27		0.75		0.37
Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.23	$	2.14	$	2.49	$	2.72
Natural gas sales, including cash settled derivatives	$	1,222,498	$	1,053,146	$	3,786,058	$	3,741,247

LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)	22,253		16,629		63,393		41,805
Sales volume (Mbbl)	3,710		2,772		10,566		6,968
NGLs price ($/Bbl)	$	35.20	$	35.42	$	38.18	$	35.34
Cash settled derivatives ($/Bbl)	(0.11)		(1.10)		(0.20)		(1.54)
Average NGLs price, including cash settled derivatives ($/Bbl)	$	35.09	$	34.32	$	37.98	$	33.80
NGLs sales, including cash settled derivatives	$	130,140	$	95,120	$	401,232	$	235,509
Ethane:
Sales volume (MMcfe) (b)	9,864		11,528		32,416		29,198
Sales volume (Mbbl)	1,644		1,921		5,403		4,866
Ethane price ($/Bbl)	$	5.56	$	5.23	$	5.97	$	5.90
Ethane sales	$	9,135	$	10,039	$	32,237	$	28,699
Oil:
Sales volume (MMcfe) (b)	2,072		3,071		6,593		6,814
Sales volume (Mbbl)	345		512		1,099		1,136
Oil price ($/Bbl)	$	61.25	$	66.75	$	60.43	$	59.91
Oil sales	$	21,144	$	34,166	$	66,403	$	68,034

Total liquids sales volume (MMcfe) (b)	34,189		31,228		102,402		77,817
Total liquids sales volume (Mbbl)	5,699		5,205		17,068		12,970
Total liquids sales	$	160,419	$	139,325	$	499,872	$	332,242

TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,382,917	$	1,192,471	$	4,285,930	$	4,073,489
Total sales volume (MMcfe)	581,414		522,700		1,622,976		1,452,344
Average realized price ($/Mcfe)	$	2.38	$	2.28	$	2.64	$	2.80

(a)Basis represents the difference between the ultimate sales price for natural gas, including the effects of delivered price benefit or deficit associated with our firm transportation agreements, and the New York Mercantile Exchange (NYMEX) natural gas price.

(b)NGLs, ethane and oil were converted to thousand cubic feet of natural gas equivalents (Mcfe) at a rate of six Mcfe per barrel.

(c)Also referred to in this report as Production adjusted operating revenues, a non-GAAP supplemental financial measure.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Non-GAAP Financial Measures Reconciliation

The table below reconciles Production adjusted operating revenues, a non-GAAP supplemental financial measure, from total operating revenues, the most comparable financial measure calculated in accordance with GAAP. See Note 2 to the Condensed Consolidated Financial Statements for a reconciliation of total operating revenues to EQT Corporation operating revenues as reported in the Statements of Condensed Consolidated Operations.

Production adjusted operating revenues (also referred to in this report as total natural gas and liquids sales, including cash settled derivatives) is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Production adjusted operating revenues is defined as total operating revenues, less the revenue impact of changes in the fair value of derivative instruments prior to settlement and pipeline, net marketing services and other revenues. We believe that Production adjusted operating revenues provides useful information to investors regarding our financial condition and results of operations because it helps facilitate comparisons of operating performance and earnings trends across periods. Production adjusted operating revenues reflects only the impact of settled derivative contracts; thus, the measure excludes the often-volatile revenue impact of changes in the fair value of derivative instruments prior to settlement. The measure also excludes pipeline, net marketing services and other revenues, which consists of costs of, and recoveries on, pipeline capacity releases and other revenues, because it is unrelated to the revenue from our natural gas and liquids production.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Thousands, unless otherwise noted)
Total operating revenues	$	1,283,802	$	1,186,102	$	3,648,582	$	4,865,924
(Deduct) add:
Gain on derivatives	(66,816)		(177,906)		(234,660)		(1,167,144)
Net cash settlements received on derivatives	288,136		255,804		1,037,321		625,051
Premiums paid for derivatives that settled during the period	(4,971)		(65,216)		(44,565)		(232,128)
Pipeline, net marketing services and other	(117,234)		(6,313)		(120,748)		(18,214)
Production adjusted operating revenues, a non-GAAP financial measure	$	1,382,917	$	1,192,471	$	4,285,930	$	4,073,489

Total sales volume (MMcfe)	581,414		522,700		1,622,976		1,452,344
Average realized price ($/Mcfe)	$	2.38	$	2.28	$	2.64	$	2.80

Business Segment Results of Operations

Operating segments are revenue-producing components of an entity for which separate financial information is produced internally and reviewed by the chief operating decision maker to allocate resources and measure financial performance.

Prior to the completion of the Equitrans Midstream Merger, we reported our results of operations as a single consolidated segment. As a result of the completion of the Equitrans Midstream Merger, we adjusted our internal reporting structure and our chief operating decision maker changed the manner in which he allocates resources and measures financial performance to incorporate the gathering and transmission assets we acquired in the Equitrans Midstream Merger. Hence, our operations expanded to comprise three discrete segments reflective of our three lines of business of Production, Gathering and Transmission. Accordingly, the manner in which we report our operations has been changed retrospectively, with certain prior period amounts recast between Production and Gathering.

The following sections summarize operating income and certain operational measures by our three reportable segments. We believe this information is useful to investors for evaluating our financial condition, results of operations and trends and uncertainties of our segments. See Note 2 to the Condensed Consolidated Financial Statements for financial information by business segment.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Certain amounts, including cash and cash equivalents, debt, income taxes and other amounts related to our headquarters function as well as amounts related to our energy transition initiatives, are managed on a consolidated basis and, as such, have not been allocated to our reportable segments. Changes to these amounts are discussed under "Other Income Statement Items."

PRODUCTION

Three Months Ended September 30, 2024 Compared to Three Months Ended September 30, 2023


	Three Months Ended September 30,
	2024		2023		Change		% Change

	(Thousands, unless otherwise noted)
Total sales volume (MMcfe)	581,414		522,700		58,714		11.2
Average daily sales volume (MMcfe/d)	6,320		5,682		638		11.2

Operating revenues:
Sales of natural gas, NGLs and oil	$	1,099,752	$	1,001,883	$	97,869	9.8
Gain on derivatives	72,489		177,906		(105,417)		(59.3)
Pipeline, net marketing services and other	5,826		3,456		2,370		68.6
Total operating revenues	1,178,067		1,183,245		(5,178)		(0.4)
Operating expenses:
Gathering	115,599		328,549		(212,950)		(64.8)
Transmission	250,757		166,572		84,185		50.5
Processing	74,489		59,667		14,822		24.8
Transportation and processing to affiliate	252,825		39,200		213,625		545.0
Lease operating expense (LOE)	54,199		40,083		14,116		35.2
Production taxes	39,643		22,775		16,868		74.1
Exploration	282		447		(165)		(36.9)
Selling, general and administrative (a)	62,952		56,942		6,010		10.6
Production depletion	529,785		439,613		90,172		20.5
Other depreciation and depletion	960		747		213		28.5
Loss on sale/exchange of long-lived assets	9,708		1,511		8,197		542.5
Impairment and expiration of leases	12,095		6,419		5,676		88.4
Other operating expenses	10,206		(621)		10,827		(1,743.5)
Total operating expenses	1,413,500		1,161,904		251,596		21.7
Operating (loss) income	$	(235,433)	$	21,341	$	(256,774)	(1,203.2)

Per Unit ($/Mcfe):
Gathering	$	0.20	$	0.63	$	(0.43)	(68.3)
Transmission	0.43		0.32		0.11		34.4
Processing	0.13		0.11		0.02		18.2
Transportation and processing to affiliate	0.43		0.07		0.36		514.3
LOE	0.09		0.08		0.01		12.5
Production taxes	0.07		0.04		0.03		75.0

Selling, general and administrative	0.11		0.11		—		—
Production depletion	0.91		0.84		0.07		8.3

(a)Prior period selling, general and administrative expense was not recast as the necessary information is not available and the cost to develop such information would be excessive.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Sales volume. Sales volume increased for the three months ended September 30, 2024 compared to the same period in 2023 primarily as a result of sales volume increases of 31 Bcfe from the assets acquired in the Tug Hill and XcL Midstream Acquisition and increases from wells turned-in-line, partly offset by sales volume decreases of 25 Bcfe due to the Strategic Curtailment and decreases of 12 Bcfe due to the NEPA Non-Operated Asset Divestiture.

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil increased for the three months ended September 30, 2024 compared to the same period in 2023 due to increased sales volume and higher average realized price.

Average realized price increased for the three months ended September 30, 2024 compared to the same period in 2023 due to favorable cash settled NYMEX derivatives and favorable average differential, partly offset by lower NYMEX price. The following table presents the composition of net cash settlements received on derivatives.


	Three Months Ended September 30,
	2024		2023

	(Thousands)
Net cash settlements received on NYMEX natural gas hedge positions	$	339,283	$	199,042
Net cash settlements (paid) received on basis and liquids hedge positions	(51,147)		56,762
Net cash settlements received on derivatives	$	288,136	$	255,804

Net cash settlements received on derivatives are included in average realized price but may not be included in operating revenues.

For the three months ended September 30, 2024 and 2023, we paid premiums of $5.0 million and $65.2 million, respectively, for derivatives that settled during the period.

Gain on derivatives. For the three months ended September 30, 2024 and 2023, we recognized a gain on derivatives of $72.5 million and $177.9 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices.

Gathering. Gathering expense decreased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to our Gathering segment's ownership of the gathering assets acquired in the Equitrans Midstream Merger, our Transmission segment's ownership of the transmission and storage assets acquired in the Equitrans Midstream Merger and our Gathering segment's ownership of the additional interest in the NEPA Gathering System acquired in the NEPA Gathering System Acquisition and as consideration for the NEPA Non-Operated Asset Divestiture.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to additional contracted capacity, including on the MVP, which commenced long-term firm capacity obligations on July 1, 2024.

Processing. Processing expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to increased volumes from the development of liquids-rich areas and increased processing expense from the liquids-rich assets acquired in the Tug Hill and XcL Midstream Acquisition.

Transportation and processing to affiliate. Affiliate transportation and processing expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to our Gathering segment's ownership of the gathering assets acquired in the Equitrans Midstream Merger, our Transmission segment's ownership of the transmission and storage assets acquired in the Equitrans Midstream Merger and our Gathering segment's ownership of the additional interest in the NEPA Gathering System acquired in the NEPA Gathering System Acquisition and as consideration for the NEPA Non-Operated Asset Divestiture. In addition, affiliate transportation and processing expense increased on a per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due to our Gathering segment's ownership of the gathering assets acquired in the Tug Hill and XcL Midstream Acquisition during the third quarter of 2023.

LOE. LOE increased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to increased LOE from the water assets acquired in the Equitrans Midstream Merger and the assets acquired in the Tug Hill and XcL Midstream Acquisition.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Production taxes. Production taxes increased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to increased West Virginia property tax expense from the assets acquired in the Tug Hill and XcL Midstream Acquisition as well as increased severance tax expense from increased sales volume.

Selling, general and administrative. Selling, general and administrative expense increased on an absolute basis for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to higher personnel costs due to increased workforce headcount, including as a result of the Equitrans Midstream Merger.

Depreciation and depletion. Production depletion expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2024 compared to the same period in 2023 due to increased sales volume and higher annual depletion rate.

Loss (gain) on sale/exchange of long-lived assets. During the three months ended September 30, 2024, we recognized a loss on the NEPA Non-Operated Asset Divestiture of approximately $8.0 million. See Note 11 to the Condensed Consolidated Financial Statements.

Impairment and expiration of leases. During the three months ended September 30, 2024 and 2023, we recognized impairment and expiration of leases related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses increased for the three months ended September 30, 2024 compared to the same period in 2023 due primarily to increased legal and environmental reserves.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Nine Months Ended September 30, 2024 Compared to Nine Months Ended September 30, 2023


	Nine Months Ended September 30,
	2024		2023		Change		% Change

	(Thousands, unless otherwise noted)
Total sales volume (MMcfe)	1,622,976		1,452,344		170,632		11.7
Average daily sales volume (MMcfe/d)	5,923		5,320		603		11.3

Operating revenues:
Sales of natural gas, NGLs and oil	$	3,293,174	$	3,680,566	$	(387,392)	(10.5)
Gain on derivatives	240,333		1,167,144		(926,811)		(79.4)
Pipeline, net marketing services and other	2,757		9,675		(6,918)		(71.5)
Total operating revenues	3,536,264		4,857,385		(1,321,121)		(27.2)
Operating expenses:
Gathering	721,891		954,304		(232,413)		(24.4)
Transmission	597,578		473,651		123,927		26.2
Processing	209,624		164,979		44,645		27.1
Transportation and processing to affiliate	384,917		87,075		297,842		342.1
LOE	144,956		102,226		42,730		41.8
Production taxes	128,086		61,737		66,349		107.5
Exploration	2,576		2,602		(26)		(1.0)
Selling, general and administrative (a)	180,767		168,999		11,768		7.0
Production depletion	1,468,644		1,212,498		256,146		21.1
Other depreciation and depletion	2,322		2,384		(62)		(2.6)
(Gain) loss on sale/exchange of long-lived assets	(310,252)		17,814		(328,066)		(1,841.6)
Impairment and expiration of leases	58,963		22,290		36,673		164.5
Other operating expenses	23,650		7,645		16,005		209.4
Total operating expenses	3,613,722		3,278,204		335,518		10.2
Operating (loss) income	$	(77,458)	$	1,579,181	$	(1,656,639)	(104.9)

Per Unit ($/Mcfe):
Gathering	$	0.44	$	0.66	$	(0.22)	(33.3)
Transmission	0.37		0.33		0.04		12.1
Processing	0.13		0.11		0.02		18.2
Transportation and processing to affiliate	0.24		0.06		0.18		300.0
LOE	0.09		0.07		0.02		28.6
Production taxes	0.08		0.04		0.04		100.0

Selling, general and administrative	0.11		0.12		(0.01)		(8.3)
Production depletion	0.90		0.83		0.07		8.4

(a)Prior period selling, general and administrative expense was not recast as the necessary information is not available and the cost to develop such information would be excessive.

Sales volume. Sales volume increased for the nine months ended September 30, 2024 compared to the same period in 2023 primarily as a result of sales volume increases of 155 Bcfe from the assets acquired in the Tug Hill and XcL Midstream Acquisition and increases from wells turned-in-line, partly offset by sales volume decreases of 107 Bcfe due to the Strategic Curtailment and decreases of 17 Bcfe due to the NEPA Non-Operated Asset Divestiture.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil decreased for the nine months ended September 30, 2024 compared to the same period in 2023 due to lower average realized price, partly offset by increased sales volume.

Average realized price decreased for the nine months ended September 30, 2024 compared to the same period in 2023 due to lower NYMEX price and lower East Coast basis spreads, partly offset by favorable cash settled NYMEX derivatives and higher NGLs price. The following table presents the composition of net cash settlements received on derivatives.


	Nine Months Ended September 30,
	2024		2023

	(Thousands)
Net cash settlements received on NYMEX natural gas hedge positions	$	1,195,411	$	738,047
Net cash settlements paid on basis and liquids hedge positions	(158,090)		(112,996)
Net cash settlements received on derivatives	$	1,037,321	$	625,051

Net cash settlements received on derivatives are included in average realized price but may not be included in operating revenues.

For the nine months ended September 30, 2024 and 2023, we paid premiums of $44.6 million and $232.1 million, respectively, for derivatives that settled during the period.

Gain on derivatives. For the nine months ended September 30, 2024, we recognized a gain on derivatives of $240.3 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices. For the nine months ended September 30, 2023, we recognized a gain on derivatives of $1,167.1 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices, partly offset by a loss on our Production segment's derivative liability related to the Henry Hub Cash Bonus (defined in Note 2 to the Condensed Consolidated Financial Statements).

Gathering. Gathering expense decreased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to our Gathering segment's ownership of the gathering assets acquired in the Equitrans Midstream Merger, our Transmission segment's ownership of the transmission and storage assets acquired in the Equitrans Midstream Merger and our Gathering segment's ownership of the additional interest in the NEPA Gathering System acquired in the NEPA Gathering System Acquisition and as consideration for the NEPA Non-Operated Asset Divestiture.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to additional contracted capacity, including on the MVP, which commenced long-term firm capacity obligations on July 1, 2024, as well as credits received in 2023 from the Texas Eastern Transmission pipeline.

Processing. Processing expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to increased processing expense from the liquids-rich assets acquired in the Tug Hill and XcL Midstream Acquisition.

Transportation and processing to affiliate. Affiliate transportation and processing expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to our Gathering segment's ownership of the gathering assets acquired in the Equitrans Midstream Merger, our Transmission segment's ownership of the transmission and storage assets acquired in the Equitrans Midstream Merger and our Gathering segment's ownership of the additional interest in the NEPA Gathering System acquired in the NEPA Gathering System Acquisition and as consideration for the NEPA Non-Operated Asset Divestiture. In addition, affiliate transportation and processing expense also increased on a per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due to our Gathering segment's ownership of the gathering assets acquired in the Tug Hill and XcL Midstream Acquisition during the third quarter of 2023.

LOE. LOE increased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to increased LOE from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Production taxes. Production taxes increased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to increased West Virginia property tax expense from the assets acquired in the Tug Hill and XcL Midstream Acquisition and higher price as well as increased severance tax expense from increased sales volume.

Selling, general and administrative. Selling, general and administrative expense increased on an absolute basis for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to higher personnel costs due to increased workforce headcount, including as a result of the Equitrans Midstream Merger, and higher legal and professional services costs.

Depreciation and depletion. Production depletion expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2024 compared to the same period in 2023 due to increased sales volume and higher annual depletion rate.

Loss (gain) on sale/exchange of long-lived assets. During the nine months ended September 30, 2024, we recognized a gain on the NEPA Non-Operated Asset Divestiture of approximately $312 million. See Note 11 to the Condensed Consolidated Financial Statements. During the nine months ended September 30, 2023, we recognized a loss on exchange of long-lived assets of $17.8 million related to acreage trade agreements where the carrying value of the acres traded exceeded the fair value of the acres received.

Impairment and expiration of leases. During the nine months ended September 30, 2024 and 2023, we recognized impairment and expiration of leases related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses increased for the nine months ended September 30, 2024 compared to the same period in 2023 due primarily to increased rig release expense and increased legal and environmental reserves.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

GATHERING

Three Months Ended September 30, 2024 Compared to Three Months Ended September 30, 2023


	Three Months Ended September 30,
	2024		2023		Change		% Change

	(Thousands, unless otherwise noted)
Gathered volume (British thermal unit (BBtu)/d):
Firm capacity	5,450		—		5,450		100
Volumetric-based services	4,293		666		3,627		545
Total gathered volume	9,743		666		9,077		1,363

Operating revenues:
Loss on derivatives	$	(5,673)	$	—	$	(5,673)	100
Firm reservation fee revenues (a)	136,752		—		136,752		100
Volumetric-based fee revenues (b)	140,077		42,057		98,020		233
Total operating revenues	271,156		42,057		229,099		545
Operating expenses:
Operating and maintenance	30,712		4,235		26,477		625
Selling, general and administrative (c)	11,366		—		11,366		100
Depreciation	37,773		4,054		33,719		832
Total operating expenses	79,851		8,289		71,562		863
Operating income	$	191,305	$	33,768	$	157,537	467

(a)Firm reservation fee revenues for the three months ended September 30, 2024 included unbilled revenues supported by minimum volume commitments (MVCs) of approximately $1.8 million.

(b)For agreements structured with MVCs, includes volumes up to the contractual MVC; volumes in excess of the contractual MVC are reported under volumetric-based services.

(c)Prior period selling, general and administrative expense was not recast as the necessary information is not available and the cost to develop such information would be excessive.

Gathering revenues and expenses increased for the three months ended September 30, 2024 compared to the same period in 2023 primarily from the gathering assets acquired in the Equitrans Midstream Merger during the third quarter of 2024 and in the Tug Hill and XcL Midstream Acquisition during the third quarter of 2023. Prior to the close of the Equitrans Midstream Merger, we did not own gathering assets that provided firm gathering services.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Nine Months Ended September 30, 2024 Compared to Nine Months Ended September 30, 2023


	Nine Months Ended September 30,
	2024		2023		Change		% Change

	(Thousands, unless otherwise noted)
Gathered volume (BBtu/d):
Firm capacity	5,450		—		5,450		100
Volumetric-based services	4,059		654		3,405		521
Total gathered volume	9,509		654		8,855		1,354

Operating revenues:
Loss on derivatives	$	(5,673)	$	—	$	(5,673)	100
Firm reservation fee revenues (a)	136,752		—		136,752		100
Volumetric-based fee revenues (b)	278,739		95,753		182,986		191
Total operating revenues	409,818		95,753		314,065		328
Operating expenses:
Operating and maintenance	56,018		6,108		49,910		817
Selling, general and administrative (c)	11,366		—		11,366		100
Depreciation	45,282		8,077		37,205		461
Gain on sale/exchange of long-lived assets	(22)		—		(22)		100
Total operating expenses	112,644		14,185		98,459		694
Operating income	$	297,174	$	81,568	$	215,606	264

(a)Firm reservation fee revenues for the nine months ended September 30, 2024 included unbilled revenues supported by MVCs of approximately $1.8 million.

(b)For agreements structured with MVCs, includes volumes up to the contractual MVC; volumes in excess of the contractual MVC are reported under volumetric-based services.

(c)Prior period selling, general and administrative expense was not recast as the necessary information is not available and the cost to develop such information would be excessive.

Gathering revenues and expenses increased for the nine months ended September 30, 2024 compared to the same period in 2023 primarily from the gathering assets acquired in the Equitrans Midstream Merger during the third quarter of 2024 and in the Tug Hill and XcL Midstream Acquisition during the third quarter of 2023. Prior to the close of the Equitrans Midstream Merger, we did not own gathering assets that provided firm gathering services.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

TRANSMISSION

Prior to the close of the Equitrans Midstream Merger on July 22, 2024, we did not have transmission or storage assets.

Three Months Ended September 30, 2024 Compared to Three Months Ended September 30, 2023


	Three Months Ended September 30, 2024

	(Thousands, unless otherwise noted)
Transmission pipeline throughput (BBtu/d):
Firm capacity (a)	3,595
Interruptible capacity	12
Total transmission pipeline throughput	3,607

Average contracted firm transmission reservation commitments (BBtu/d)	4,454

Operating revenues:
Firm reservation fee revenues	$	73,034
Volumetric-based fee revenues:	14,226
Other revenues	124
Total operating revenues	87,384
Operating expenses:
Operating and maintenance	9,806
Selling, general and administrative	5,492
Depreciation	13,900
Amortization of intangible assets	3,209
Loss on sale/exchange of long-lived assets	409
Total operating expenses	32,816
Operating income	$	54,568

(a)Includes all volumes associated with firm capacity contracts, including volumes in excess of firm capacity.

Other Income Statement Items

Other operating expenses. Corporate other operating expenses increased for both the three and nine months ended September 30, 2024 compared to the same periods in 2023 due primarily to transaction costs related to the Equitrans Midstream Merger of $274.6 million and $298.7 million for the three and nine months ended September 30, 2024, respectively, partly offset by lower transaction costs related to the Tug Hill and XcL Midstream Acquisition. In addition, during the nine months ended September 30, 2024, litigation reserves increased compared to the same period in 2023.

Total transaction costs related to the Equitrans Midstream Merger recognized during the three months ended September 30, 2024 included severance and other termination benefits and stock-based compensation costs of $161.0 million, of which $58.6 million was cash and $102.4 million was non-cash.

(Income) loss from investments. Income from investments increased for both the three and nine months ended September 30, 2024 compared to the same period in 2023 due primarily to equity earnings from our investment in the MVP Joint Venture, partly offset by a decrease in the fair value of our investment in the Investment Fund (defined in Note 5 to the Condensed Consolidated Financial Statements).

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Other income. Other income increased during the three months ended September 30, 2024 due to dividends received from our investment in the Investment Fund. During the nine months ended September 30, 2024, we received proceeds from insurance claim recoveries of $19.1 million related to the assets acquired in the Tug Hill and XcL Midstream Acquisition.

Loss (gain) on debt extinguishment. During the nine months ended September 30, 2024, we recognized a loss on debt extinguishment of $5.7 million primarily as a result of our prepayment of a portion of the Term Loan Facility (defined in Note 7 to the Condensed Consolidated Financial Statements) as well as our redemption of EQT's 6.125% senior notes.

Interest expense, net. Interest expense, net increased for the three months ended September 30, 2024 compared to the same periods in 2023 due primarily to interest expense on EQM Midstream Partners, LP's (EQM) senior notes (which we consolidate as a result of the Equitrans Midstream Merger), increased interest expense on our borrowings under EQT's revolving credit facility, interest expense on EQT's 5.750% senior notes issued in January 2024 and lower interest income earned on cash on hand, partly offset by decreased interest expense from our repayment and repurchase of certain of our senior notes, decreased interest expense on the Term Loan Facility due to our partial prepayment in January 2024 as well as higher capitalized interest from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

Interest expense, net increased for the nine months ended September 30, 2024 compared to the same periods in 2023 due primarily to interest expense on EQM's senior notes, lower interest income earned on cash on hand, interest expense on EQT's 5.750% senior notes issued in January 2024, increased interest expense on our borrowings under EQT's revolving credit facility and increased interest expense on our borrowings under the Term Loan Facility, partly offset by decreased interest expense from our repayment and repurchase of certain of our senior notes as well as higher capitalized interest from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

See Note 7 to the Condensed Consolidated Financial Statements.

Income tax (benefit) expense. See Note 6 to the Condensed Consolidated Financial Statements.

Net income (loss) attributable to noncontrolling interests. During the three and nine months ended September 30, 2024, we recognized net income attributable to noncontrolling interests of Eureka Midstream Holdings, LLC (Eureka Midstream Holdings), a consolidated joint venture in which we acquired an equity interest as a result of the Equitrans Midstream Merger. See Note 1 to the Condensed Consolidated Financial Statements.

Capital Resources and Liquidity

Although we cannot provide any assurance, we believe cash flows from operating activities and availability under EQT's revolving credit facility should be sufficient to meet our cash requirements inclusive of, but not limited to, normal operating needs, debt service obligations, planned capital expenditures and commitments for at least the next twelve months and, based on current expectations, for the long term.

Planned Capital Expenditures and Sales Volume. Following the completion of the Equitrans Midstream Merger, we revised our estimated total capital expenditures for the fourth quarter of 2024 to $630 million to $730 million. We expect to fund our capital expenditures with cash generated from operations and, if required, borrowings under EQT's revolving credit facility. Because we are the operator of a high percentage of our developed acreage, the amount and timing of certain of our capital expenditures is largely discretionary. We could choose to defer a portion of our planned 2024 capital expenditures depending on a variety of factors, including prevailing and anticipated prices for natural gas, NGLs and oil; the availability of necessary equipment, infrastructure and capital; the receipt and timing of required regulatory permits and approvals; and drilling, completion and acquisition costs. In addition, our gathering and transmission businesses are capital intensive, requiring significant investment to develop new facilities and maintain and upgrade existing operations.

We expect our sales volume, including expected curtailments, to be 555 Bcfe to 605 Bcfe for the fourth quarter of 2024.

Material Cash Requirements. We have contractual commitments under our debt agreements, including interest payments and principal repayments. As a result of the Equitrans Midstream Merger, EQM became an indirect wholly-owned subsidiary of EQT. See Note 7 to the Condensed Consolidated Financial Statements for further discussion of EQM's senior notes.

In addition, we expect to make total capital contributions to the MVP Joint Venture in the fourth quarter of 2024 of approximately $70 million to $80 million.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Operating Activities. Net cash provided by operating activities was $2,071 million for the nine months ended September 30, 2024 compared to $2,554 million for the same period in 2023. The decrease was due primarily to higher cash operating expenses (including increased transaction costs related to the Equitrans Midstream Merger), unfavorable timing of working capital payments, lower cash operating revenues and higher net interest expense, partly offset by higher net cash settlements received on derivatives and lower net premiums paid on derivatives.

Our cash flows from operating activities are affected by movements in the market price for commodities. We are unable to predict such movements outside of the current market view as reflected in forward strip pricing. For a discussion of potential commodity market risks, refer to "Risk Factors – Natural gas, NGLs and oil price volatility, or a prolonged period of low natural gas, NGLs and oil prices, may have an adverse effect on our revenue, profitability, future rate of growth, liquidity and financial position" in our Annual Report on Form 10-K for the year ended December 31, 2023.

Investing Activities. Net cash used in investing activities was $2,162 million for the nine months ended September 30, 2024 compared to $3,774 million for the same period in 2023. The decrease was attributable primarily to lower cash paid for the Equitrans Midstream Merger and the NEPA Gathering System Acquisition in 2024 compared to cash paid for the Tug Hill and XcL Midstream Acquisition in 2023 as well as the proceeds received from the NEPA Non-Operated Asset Divestiture, partly offset by increased capital expenditures.

The following tables summarize our capital expenditures.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023

	(Millions)
Production:
Reserve development (a)	$	371	$	355	$	1,283	$	1,147
Land and lease (b)	37		41		105		101
Other production infrastructure	16		17		57		49
Capitalized interest, capitalized overhead and other	31		23		95		70
Total Production	455		436		1,540		1,367
Gathering (c)	80		7		112		12
Transmission	10		—		10		—
Other corporate items	13		2		21		8
Total capital expenditures	558		445		1,683		1,387
Add (deduct): Non-cash items (d)	11		59		(21)		99
Total cash capital expenditures	$	569	$	504	$	1,662	$	1,486

(a)Capital expenditures for reserve development included capital expenditures for water infrastructure of $28.9 million and $7.7 million for the three months ended September 30, 2024 and 2023, respectively, and $58.7 million and $26.4 million for the nine months ended September 30, 2024 and 2023, respectively.

(b)Capital expenditures for land and lease included capital expenditures attributable to noncontrolling interest in The Mineral Company LLC of approximately $8.5 million for the nine months ended September 30, 2023. The Mineral Company LLC was dissolved in the third quarter of 2023.

(c)Gathering capital expenditures included capital expenditures attributable to noncontrolling interest in Eureka Midstream Holdings of approximately $1.6 million for both the three and nine months ended September 30, 2024.

(d)Represents the net impact of non-cash capital expenditures, including the effect of timing of receivables from working interest partners, accrued capital expenditures, transfers to or from inventory as assets are completed or assigned to a project and capitalized share-based compensation costs. The impact of accrued capital expenditures includes the current period estimate, net of the reversal of the prior period accrual.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Financing Activities. Net cash provided by financing activities was $100 million for the nine months ended September 30, 2024 compared to net cash used in financing activities of $174 million for the same period in 2023. For the nine months ended September 30, 2024, the primary sources of financing cash flows were our net borrowings under EQT's revolving credit facility, proceeds from the issuance of EQT's 5.750% senior notes and proceeds from the net settlement of the Capped Call Transactions (defined in Note 7 to the Condensed Consolidated Financial Statements), and the primary uses of financing cash flows were our repayment and retirement of debt, repayment of EQM's revolving credit facility and payment of dividends. For the nine months ended September 30, 2023, the primary source of financing cash flows was proceeds from the Term Loan Facility borrowings, and the primary uses of financing cash flows were our repayment and retirement of debt, repurchase and retirement of EQT common stock and payment of dividends.

See Note 7 to the Condensed Consolidated Financial Statements for further discussion of our debt and borrowings under EQT's revolving credit facility and the Term Loan Facility. See Notes 1 and 7 to the Condensed Consolidated Financial Statements for discussion of borrowings under the revolving credit facility of Eureka Midstream, LLC (Eureka), a wholly-owned subsidiary of Eureka Midstream Holdings.

On October 10, 2024, our Board of Directors declared a quarterly cash dividend of $0.1575 per share of EQT common stock, payable on December 2, 2024, to shareholders of record at the close of business on November 6, 2024.

Depending on our actual and anticipated sources and uses of liquidity, prevailing market conditions and other factors, we may from time to time seek to redeem or repurchase our outstanding debt or equity securities through tender offers or other cash purchases in the open market or privately negotiated transactions. The amounts involved in any such transactions may be material. See Note 7 to the Condensed Consolidated Financial Statements for discussion of redemptions and repurchases of debt.

Security Ratings and Financing Triggers

Our credit ratings and rating outlooks are subject to revision or withdrawal at any time by the assigning rating agency, and each rating should be evaluated independently from any other rating. We cannot ensure that a rating will remain in effect for any given period of time or that a rating will not be lowered or withdrawn by a rating agency if, in the rating agency's judgment, circumstances so warrant. See Note 4 to the Condensed Consolidated Financial Statements for a description of what is deemed investment grade.

The table below reflects the credit ratings and rating outlooks assigned to EQT's debt instruments as of September 30, 2024.

Rating agency

Senior notes

Outlook

Moody's Investor Service (Moody's)

Baa3

Negative

Standard and Poor's Ratings Service (S&P)

BBB–

Negative

Fitch Ratings Service (Fitch)

BBB–

Stable

The table below reflects the credit ratings and rating outlooks assigned to EQM's debt instruments as of September 30, 2024.

Rating agency

Senior notes

Outlook

Moody's Investor Service (Moody's)

Ba2

Stable

Standard and Poor's Ratings Service (S&P)

BBB–

Negative

Fitch Ratings Service (Fitch)

BB+

Stable

Changes in credit ratings may affect our access to the capital markets, the cost of short-term debt through interest rates and fees under EQT's and Eureka's revolving credit facilities, the interest rate on the Term Loan Facility, the interest rate on EQT's senior notes with adjustable rates, the rates available on new long-term debt, our pool of investors and funding sources, the borrowing costs and margin deposit requirements on our over the counter (OTC) derivative instruments and credit assurance requirements, including collateral, in support of our midstream service contracts, joint venture arrangements or construction contracts. Margin deposits on our OTC derivative instruments are also subject to factors other than credit rating, such as natural gas prices and credit thresholds set forth in the agreements between us and our hedging counterparties.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Our debt agreements and other financial obligations contain various provisions that, if not complied with, could result in default or event of default under EQT's revolving credit facility, Eureka's revolving credit facility and the Term Loan Facility, mandatory partial or full repayment of amounts outstanding, reduced loan capacity or other similar actions. The most significant covenants and events of default under our debt agreements relate to maintenance of a debt-to-total capitalization ratio, limitations on transactions with affiliates, insolvency events, nonpayment of scheduled principal or interest payments, acceleration of other financial obligations and change of control provisions. EQT's revolving credit facility and the Term Loan Facility contain financial covenants that require us to have a total debt to total capitalization ratio no greater than 65%. As of September 30, 2024, we were in compliance with all EQT, Eureka and EQM debt provisions and covenants under our debt agreements.

See Note 7 to the Condensed Consolidated Financial Statements for a discussion of borrowings under EQT's revolving credit facility, Eureka's revolving credit facility and the Term Loan Facility.

Commodity Risk Management

The substantial majority of our commodity risk management program is related to hedging sales of our produced natural gas. The overall objective of our hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices. The derivative commodity instruments that we use are primarily swap, collar and option agreements. The following table summarizes the approximate volume and prices of our NYMEX hedge positions as of October 25, 2024. The difference between the fixed price and NYMEX price is included in average differential presented in our price reconciliation in "Average Realized Price Reconciliation." The fixed price natural gas sales agreements can be physically or financially settled.


	Q4 2024 (a)		Q1 2025		Q2 2025		Q3 2025		Q4 2025
Hedged Volume (MMDth)	377		332		336		281		281
Hedged Volume (MMDth/d)	4.1		3.7		3.7		3.1		3.1



Swaps – Short
Volume (MMDth)	304		250		290		281		95
Avg. Price ($/Dth)	$	3.18	$	3.49	$	3.11	$	3.26	$	3.27
Calls – Long
Volume (MMDth)	13		—		—		—		—
Avg. Strike ($/Dth)	$	3.20	$	—	$	—	$	—	$	—
Calls – Short
Volume (MMDth)	91		188		46		—		137
Avg. Strike ($/Dth)	$	4.23	$	4.19	$	3.48	$	—	$	5.49
Puts – Long
Volume (MMDth)	73		82		46		—		186
Avg. Strike ($/Dth)	$	3.54	$	3.19	$	2.83	$	—	$	3.30






Option Premiums
Cash Settlement of Deferred Premiums (millions)	$	—	$	—	$	—	$	—	$	(45)

(a)October 1 through December 31.

We have also entered into derivative instruments to hedge basis. We may use other contractual agreements to implement our commodity hedging strategy from time to time.

See "Quantitative and Qualitative Disclosures About Market Risk" and Note 4 to the Condensed Consolidated Financial Statements for further discussion of our hedging program.

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EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Commitments and Contingencies

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts claimed may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We evaluate our legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrue a liability for such matters when we believe that a loss is probable and the amount of the loss can be reasonably estimated. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event we determine that (i) a loss is probable but the amount of the loss cannot be reasonably estimated, or (ii) a loss is less likely than probable but is reasonably possible, then we are required to disclose the matter in our Annual Report on Form 10-K with any update thereto in this Quarterly Report on Form 10-Q, as applicable, although we are not required to accrue such loss.

When able, we determine an estimate of reasonably possible losses or ranges of reasonably possible losses, whether in excess of any related accrued liability or where there is no accrued liability, for legal proceedings. In instances where such estimates can be made, any such estimates are based on our analysis of currently available information and are subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained.

See Note 13 to the Condensed Consolidated Financial Statements herein and Note 11 to the Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2023 for discussions of our commitments and contingencies, including certain pending legal and regulatory proceedings and other contingent matters.

Additionally, in the normal course of business, we are subject to various other pending and threatened legal proceedings in which claims for monetary damages or other relief are asserted. We do not anticipate, at the present time, that the ultimate aggregate liability, if any, arising out of such other legal proceedings will have a material adverse effect on our financial position, results of operations or liquidity.

Critical Accounting Estimates

Our critical accounting estimates, including a discussion regarding the estimation uncertainty and the impact that our critical accounting estimates have had, or are reasonably likely to have, on our financial condition or results of operations, are described in the "Management's Discussion and Analysis of Financial Condition and Results of Operations" section of our Annual Report on Form 10-K for the year ended December 31, 2023 and have been updated below. The application of our critical accounting estimates may require us to make judgments and estimates about the amounts reflected in the Condensed Consolidated Financial Statements. We use historical experience and all available information to make these estimates and judgments. Different amounts could be reported using different assumptions and estimates.

Goodwill. Goodwill is the cost of an acquisition less the fair value of the identifiable net assets of the acquired business.

Goodwill is evaluated for impairment at least annually or whenever events or changes in circumstances indicate that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. We use a combination of an income and market approach to estimate the fair value of our reporting units.

We believe goodwill is a "critical accounting estimate" because the valuation of a reporting unit involves significant judgment and is sensitive to changes in assumptions, including changes in our stock price, weighted-average cost of capital, terminal growth rates and industry multiples. Changes to assumptions could materially affect the estimated fair value of our reporting units and the resulting conclusion on impairment could materially affect our results of operations and financial position. In addition, future assumptions and estimates may materially differ from current assumptions and estimates.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk and Derivative Instruments. Our primary market risk exposure is the volatility of future prices for natural gas and NGLs. Due to the volatility of commodity prices, we are unable to predict future potential movements in the market prices for natural gas and NGLs at our ultimate sales points and, thus, cannot predict the ultimate impact of prices on our operations. Prolonged low, or significant, extended declines in, natural gas and NGLs prices could adversely affect, among other things, our development plans, which would decrease the pace of development and the level of our proved reserves and, similarly, could adversely affect timing of development of additional reserves and production that is accessible by our pipeline and storage assets and limit growth in, or may reduce the demand for, and usage of, our gathering or transmission and storage services. Price declines and sustained periods of low natural gas and NGLs prices could also have an adverse effect on the creditworthiness of our gathering and transmission and storage customers and related ability to pay firm reservation fees under long-term contracts. Increases in natural gas and NGLs prices may be accompanied by, or result in, increased well drilling costs, increased production taxes, increased LOE, increased volatility in seasonal gas price spreads for our storage assets and increased end-user conservation or conversion to alternative fuels. In addition, to the extent we have hedged our production at prices below the current market price, we will not benefit fully from an increase in the price of natural gas, and, depending on our then-current credit ratings and the terms of our hedging contracts, we may be required to post additional margin with our hedging counterparties.

The overall objective of our hedging program is to protect our cash flows from undue exposure to the risk of changing commodity prices. Our use of derivatives is further described in Note 4 to the Condensed Consolidated Financial Statements and "Commodity Risk Management" under "Capital Resources and Liquidity" in Item 2. Our OTC derivative commodity instruments are placed primarily with financial institutions and the creditworthiness of those institutions is regularly monitored. We primarily enter into derivative instruments to hedge forecasted sales of production. We also enter into derivative instruments to hedge basis. Our use of derivative instruments is implemented under a set of policies approved by our management-level Hedge and Financial Risk Committee and is reviewed by our Board of Directors.

For derivative commodity instruments used to hedge our forecasted sales of production, which are at, for the most part, NYMEX natural gas prices, we set policy limits relative to the expected production and sales levels that are exposed to price risk. We have an insignificant amount of financial natural gas derivative commodity instruments for trading purposes.

The derivative commodity instruments we use are primarily swap, collar and option agreements. These agreements may require payments to, or receipt of payments from, counterparties based on the differential between two prices for the commodity. We use these agreements to hedge our NYMEX and basis exposure. We may also use other contractual agreements when executing our commodity hedging strategy.

We monitor price and production levels on a continuous basis and adjust quantities hedged as warranted.

A hypothetical decrease of 10% in the NYMEX natural gas price on September 30, 2024 and December 31, 2023 would increase the fair value of our natural gas derivative commodity instruments by approximately $440 million and $204 million, respectively. A hypothetical increase of 10% in the NYMEX natural gas price on September 30, 2024 and December 31, 2023 would decrease the fair value of our natural gas derivative commodity instruments by approximately $434 million and $482 million, respectively. For purposes of this analysis, we applied the 10% change in the NYMEX natural gas price on September 30, 2024 and December 31, 2023 to our natural gas derivative commodity instruments as of September 30, 2024 and December 31, 2023 to calculate the hypothetical change in fair value. The change in fair value was determined using a method similar to our normal process for determining derivative commodity instrument fair value described in Note 5 to the Condensed Consolidated Financial Statements.

The above analysis of our derivative commodity instruments does not include the offsetting impact that the same hypothetical price movement may have on our physical sales of natural gas. The portfolio of derivative commodity instruments held to hedge our forecasted produced natural gas approximates a portion of our expected physical sales of natural gas; therefore, an adverse impact to the fair value of the portfolio of derivative commodity instruments held to hedge our forecasted production associated with the hypothetical changes in commodity prices referenced above should be offset by a favorable impact on our physical sales of natural gas, assuming that the derivative commodity instruments are not closed in advance of their expected term and the derivative commodity instruments continue to function effectively as hedges of the underlying risk.

If the underlying physical transactions or positions are liquidated prior to the maturity of the derivative commodity instruments, a loss on the financial instruments may occur or the derivative commodity instruments might be worthless as determined by the prevailing market value on their termination or maturity date, whichever comes first.

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Interest Rate Risk. Changes in market interest rates affect the amount of interest we earn on cash, cash equivalents and short-term investments and the interest rate we pay on borrowings under EQT's revolving credit facility, Eureka's revolving credit facility and the Term Loan Facility. In addition, changes in Eureka's Consolidated Leverage Ratio (defined in that certain Credit Agreement, dated May 13, 2021, among Eureka, Sumitomo Mitsui Banking Corporation, as administrative agent, the lenders party thereto from time to time and any other persons party thereto from time to time, as amended, governing Eureka's revolving credit facility (the Eureka Credit Agreement)) as a result on Eureka's liquidity needs, operating results or distributions to its member affect the interest rate Eureka pays on borrowings under its revolving credit facility. None of the interest we pay on our senior notes fluctuates based on changes to market interest rates. A 1% increase in interest rates for the borrowings under EQT's revolving credit facility, Eureka's revolving credit facility and the Term Loan Facility during the nine months ended September 30, 2024 would have increased interest expense by approximately $9.7 million.

Interest rates for EQT's revolving credit facility, the Term Loan Facility and EQT's 7.000% senior notes fluctuate based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Prior to EQT's redemption of all of EQT's outstanding 6.125% senior notes, interest rates for EQT's 6.125% senior notes fluctuated based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Interest rates for our other outstanding senior notes do not fluctuate based on changes to the credit ratings assigned to our senior notes by Moody's, S&P and Fitch. For a discussion of credit rating downgrade risk, see "Risk Factors – Our operations have substantial capital requirements, and we may not be able to obtain needed capital or financing on satisfactory terms" in our Annual Report on Form 10-K for the year ended December 31, 2023. Changes in interest rates affect the fair value of our fixed rate debt. See Note 7 to the Condensed Consolidated Financial Statements for further discussion of our debt and Note 5 to the Condensed Consolidated Financial Statements for a discussion of fair value measurements, including the fair value measurement of our debt.

Other Market Risks. We are exposed to credit loss in the event of nonperformance by counterparties to our derivative contracts. This credit exposure is limited to derivative contracts with a positive fair value, which may change as market prices change. Our OTC derivative instruments are primarily with financial institutions and, thus, are subject to events that would impact those companies individually as well as the financial industry as a whole. We use various processes and analyses to monitor and evaluate our credit risk exposures, including monitoring current market conditions and counterparty credit fundamentals. Credit exposure is controlled through credit approvals and limits based on counterparty credit fundamentals. To manage the level of credit risk, we enter into transactions primarily with financial counterparties that are of investment grade, enter into netting agreements whenever possible and may obtain collateral or other security.

Approximately 54%, or $210 million, of our OTC derivative contracts outstanding at September 30, 2024 had a positive fair value. Approximately 86%, or $912 million, of our OTC derivative contracts outstanding at December 31, 2023 had a positive fair value.

As of September 30, 2024, we were not in default under any derivative contracts and had no knowledge of default by any counterparty to our derivative contracts. During the three months ended September 30, 2024, we made no adjustments to the fair value of our derivative contracts due to credit related concerns outside of the normal non-performance risk adjustment included in our established fair value procedure. We monitor market conditions that may impact the fair value of our derivative contracts.

We are exposed to the risk of nonperformance by credit customers on physical sales of natural gas, NGLs and oil. Revenues and related accounts receivable from our operations are generated primarily from the sale of our produced natural gas, NGLs and oil to marketers, utilities and industrial customers located in the Appalachian Basin and in markets that are accessible through our transportation portfolio, which includes markets in the Gulf Coast, Midwest and Northeast United States and Canada. We also contract with certain processors to market a portion of our NGLs on our behalf.

As of September 30, 2024, no one lender of the large group of financial institutions in the syndicate for either EQT's revolving credit facility or the Term Loan Facility held more than 10% of the financial commitments thereunder. In addition, as of September 30, 2024, no one lender of the large group of financial institutions in the syndicate for Eureka's revolving credit facility held more than 13% of the financial commitments thereunder. The large syndicate group and relatively low percentage of participation by each lender are expected to limit our exposure to disruption or consolidation in the banking industry.

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Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our principal executive officer and our principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act), as of the end of the period covered by this report. Based on that evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report.

Changes in Internal Control over Financial Reporting

Under guidelines established by the SEC, companies are permitted to exclude acquisitions from their assessment of internal control over financial reporting during the first year of an acquisition while integrating the acquired company. During the third quarter of 2024, we completed the Equitrans Midstream Merger and began integrating the acquired assets into our internal control over financial reporting. We will continue to evaluate and monitor our internal control over financial reporting and will continue to evaluate the operating effectiveness of related key controls.

Except as noted above, there were no changes in our internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred during the third quarter of 2024 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Environmental Proceedings

Pratt Storage Field Matter, Morgan Township, Pennsylvania. On October 31, 2018, a gas explosion occurred in Morgan Township, Greene County, Pennsylvania (the Pratt Incident). Following the explosion, the Pennsylvania Department of Environmental Protection (PADEP), the Pennsylvania Public Utilities Commission and the Pipeline and Hazardous Materials Safety Administration of the Department of Transportation (PHMSA) began investigating the Pratt Incident. In October 2019, the PADEP notified Equitrans Midstream that it was required to submit an investigation report pursuant to the state's gas migration regulations due to the Pratt Incident's proximity to Equitrans, L.P.'s (a subsidiary of Equitrans Midstream) Pratt Storage Field assets. Equitrans Midstream, while disputing the applicability of the regulations, submitted a report to the PADEP in May 2020. In September 2020, the PADEP responded to Equitrans Midstream's investigation report with a request for additional information. Equitrans Midstream responded to the September 2020 request. Over the next several months, Equitrans Midstream provided responses to the PADEP's continuing information requests. The PADEP issued a final report and closed its investigation in August 2022, and we do not expect further inquiry from the PADEP on this matter.

On October 23, 2023, Equitrans, L.P. received permission from the FERC to plug and abandon the well in the Pratt Storage Field that was the subject of the PADEP's investigation of the Pratt Incident. On October 22, 2024, Equitrans, L.P. received from the FERC an extension until January 31, 2025 to complete plugging and abandonment of the well. Additionally, Equitrans Midstream is continuing to defend in a civil litigation related to the Pratt Incident.

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On October 30, 2023, Equitrans, L.P. received a criminal complaint from the State Attorney General's Office charging Equitrans, L.P. with violations of the Clean Streams Law (the Pratt Complaint). As a result of the Equitrans Midstream Merger, we indirectly assumed Equitrans Midstream's and Equitrans, L.P.'s defense against the Pratt Complaint and matters related to the Pratt Incident. We intend to fully assert Equitrans Midstream's and Equitrans, L.P.'s rights and defenses to the claims raised in the Pratt Complaint. The Pratt Complaint carries the possibility of a monetary sanction, that if imposed could result in a fine in excess of $300,000; however, we expect that the resolution of this matter will not have a material adverse impact on our financial condition, results of operations or liquidity.

Rager Mountain Storage Field Venting, Jackson Township, Pennsylvania. On November 6, 2022, Equitrans Midstream became aware of natural gas venting from one of the storage wells, well 2244, at Equitrans, L.P.'s Rager Mountain natural gas storage facility (the Rager Mountain Facility), located in Jackson Township, a remote section of Cambria County, Pennsylvania. Venting at the Rager Mountain Facility was halted on November 19, 2022. Since the time of the incident, the PADEP has concluded its investigation and PHMSA and other investigators are continuing to conduct civil and criminal investigations of the incident, and Equitrans Midstream has been cooperating in such investigations. On December 7, 2022, Equitrans Midstream and Equitrans, L.P. each separately received an order from the PADEP alleging, in connection with earth disturbance activities undertaken to halt the venting of natural gas from well 2244, (i) in the case of the order received by Equitrans Midstream, violations of Pennsylvania's Clean Streams Law and requiring certain remedial actions and (ii) in the case of the order received by Equitrans, L.P., violations of Pennsylvania's 2012 Oil and Gas Act, Clean Streams Law and Solid Waste Management Act and requiring certain remedial actions. On December 8, 2022, the PADEP submitted a compliance order to Equitrans, L.P. relating to certain alleged violations of law with respect to wells at the Rager Mountain Facility and the venting of natural gas, including from well 2244. The December 8, 2022 order also prohibited Equitrans, L.P. from injecting natural gas into the storage wells at the Rager Mountain Facility. Equitrans Midstream and Equitrans, L.P. disputed aspects of the applicable orders, and on January 5, 2023, Equitrans Midstream and Equitrans, L.P., as applicable, appealed each of the orders to the Commonwealth of Pennsylvania Environmental Hearing Board. Equitrans, L.P. and the PADEP entered into a Stipulation of Settlement on April 12, 2023 that, among other things, resulted in the PADEP rescinding its December 8, 2022 order and Equitrans, L.P. withdrawing its appeal of such order.

On October 5, 2023, Equitrans, L.P. received a notice of violation (NOV) from the PADEP's Bureau of Air Quality Management for the release of uncontrolled hydrocarbons to the atmosphere during the Rager Mountain Facility incident. On April 8, 2024, the PADEP's Bureau of Air Quality Management executed a Consent Assessment of Civil Penalty that settled the October 5, 2023 NOV and included an agreed upon civil penalty of $350,000, which was paid in full by Equitrans Midstream on April 15, 2024.

On April 4, 2024, (i) Equitrans, L.P. and the PADEP entered into a Stipulation of Settlement, that, among other things, resulted in the PADEP deeming the December 8, 2022 orders to Equitrans Midstream and Equitrans, L.P. administratively closed and (ii) the PADEP issued a Civil Penalty Assessment (CPA) in the amount of $764,000, of which $549,500 was reimbursement of PADEP's expenses. The CPA closed the outstanding NOVs issued by the PADEP's Office of Oil and Gas Management related to the Rager Mountain Facility incident. Equitrans Midstream paid the civil penalty pursuant to the CPA in full on April 8, 2024.

On December 29, 2022, the PHMSA issued Equitrans Midstream a Notice of Proposed Safety Order that included proposed remedial requirements related to the Rager Mountain Facility incident, including, but not limited to, completing a root cause analysis, and subsequently, on May 26, 2023, the PHMSA issued a consent order to Equitrans Midstream requiring the completion of a root cause analysis and a remedial work plan and providing that Equitrans Midstream may not resume injection operations at the Rager Mountain Facility until authorized by the PHMSA. In August 2023, Equitrans Midstream submitted a root cause analysis to the PHMSA and later submitted a remedial work plan and injection plan seeking authority to resume injections at the Rager Mountain Facility using all wells in the facility except three, which remained disconnected from the storage field. On October 2, 2023, the PHMSA approved Equitrans Midstream's injection plan and Equitrans Midstream restarted injections at the Rager Mountain Facility on October 5, 2023, subject to certain pressure restrictions and other requirements in the PHMSA consent agreement. On November 16, 2023, the PHMSA issued a letter to Equitrans Midstream approving Equitrans Midstream's request to remove all pressure restrictions at the Rager Mountain Facility. On May 30, 2024, the PHMSA approved resuming operations for one of the three remaining wells excluded from the injection plan.

As a result of the Equitrans Midstream Merger, we indirectly assumed Equitrans Midstream's and Equitrans, L.P.'s defense and responses to matters related to the Rager Mountain Facility incident. We plan to continue working with the PHMSA, pursuant to the consent order between PHSMA and Equitrans Midstream, regarding the remaining two disconnected wells at the Rager Mountain Facility. If additional penalties are pursued and ultimately imposed related to the Rager Mountain Facility incident, the penalties, individually and/or in the aggregate, may exceed $300,000; however, we expect that the resolution of this matter will not have a material adverse impact on our financial condition, results of operations or liquidity.

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Item 1A. Risk Factors

There are no material changes to the risk factors previously disclosed in the "Risk Factors" section of our Annual Report on Form 10-K for the year ended December 31, 2023 other than those listed below.

Risks Related to Gathering Segment and Transmission Segment Operations

We are subject to numerous operational risks and hazards incidental to the gathering, transmission and storage of natural gas, as well as unforeseen interruptions.

Our business operations are subject to the inherent hazards and risks normally incidental to the gathering, transmission and storage of natural gas. These operating risks, some of which we have experienced and/or could experience in the future, include but are not limited to:

•aging infrastructure and mechanical or structural problems;

•security risks, including cybersecurity;

•pollution and other environmental risks;

•operator error;

•failure of equipment, facilities or new technology;

•damage to pipelines, wells and storage assets, facilities, equipment, environmental controls and surrounding properties, and pipeline blockages or other operational interruptions, caused or exacerbated by natural phenomena, weather conditions, acts of sabotage, vandalism and terrorism;

•inadvertent damage from construction, vehicles, and farm and utility equipment;

•uncontrolled releases of natural gas and other hydrocarbons or of fresh, mixed or produced water, or other hazardous materials;

•leaks, migrations or losses of natural gas as a result of issues regarding pipeline and/or storage equipment or facilities and, including with respect to storage assets, as a result of undefined boundaries, geologic anomalies, limitations in then-applied industry-standard testing methodologies, operational practices (including as a result of regulatory requirements), natural pressure migration and wellbore migration or other factors relevant to such storage assets;

•ruptures, fires, leaks and explosions; and

•other hazards that could also result in personal injury and loss of life, pollution to the environment and suspension of operations.

Any such events, certain of which we have experienced, and any of which we may experience in the future, could result in loss of human life, personal injuries, significant damage to property, environmental pollution, impairment or interruption, which could be significant, to our operations, regulatory investigations and penalties or other sanctions and substantial losses to us and could have a material adverse effect on our business, financial condition, results of operations, and liquidity, particularly if the event is not fully covered by insurance. The location of certain segments of our systems in or near populated areas, including residential areas, commercial business centers and industrial sites, could increase the damages resulting from these risks. Accidents or other operating risks have resulted, and in the future could result, in loss of service available to our customers. Customer impacts arising from service interruptions on segments of our systems and/or our assets have included and/or may include, without limitation and as applicable, curtailments, limitations on our ability to satisfy customer contractual requirements, obligations to provide reservation charge credits to customers and solicitation of our existing customers by third parties for potential new projects that would compete directly with our existing services. Such circumstances could adversely impact our ability to retain customers and negatively impact our business, financial condition, results of operations, and liquidity.

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Expanding our business by constructing new midstream assets subjects us to construction, business, economic, competitive, regulatory, judicial, environmental, political and legal uncertainties that are beyond our control.

The development and construction by us or our joint ventures of pipeline and storage facilities and the optimization of such assets involve numerous construction, business, economic, competitive, regulatory, judicial, environmental, political and legal uncertainties that are beyond our control, require the expenditure of significant amounts of capital and expose us to risks. Those risks include, but are not limited to: (i) physical construction conditions, such as topographical, or unknown or unanticipated geological, conditions and impediments; (ii) construction site access logistics; (iii) crew availability and productivity and ability to adhere to construction workforce drawdown plans; (iv) adverse weather conditions; (v) project opposition, including delays caused by landowners, advocacy groups or activists opposed to our projects and/or the natural gas industry through lawsuits or intervention in regulatory proceedings; (vi) environmental protocols and evolving regulatory or legal requirements and related impacts therefrom, including additional costs of compliance; (vii) the application of time of year or other regulatory restrictions affecting construction, (viii) failure to meet customer contractual requirements; (ix) environmental hazards; (x) vandalism; (xi) the lack of available skilled labor, equipment and materials (or escalating costs in respect thereof, including as a result of inflation); (xii) issues regarding availability of or access to connecting infrastructure; and (xiii) the inability to obtain necessary rights-of-way or approvals and permits from regulatory agencies on a timely basis or at all (and maintain such rights-of-way, approvals and permits once obtained, including by reason of judicial hostility or activism). Risks inherent in the construction of these types of projects, such as unanticipated geological conditions, challenging terrain in certain of our construction areas and severe or continuous adverse weather conditions, have adversely affected, and in the future could adversely affect, project timing, completion and cost, as well as increase the risk of loss of human life, personal injuries, significant damage to property or environmental pollution. Most notably, certain of these risks have been realized in the construction of the MVP project, including construction-related risks and adverse weather conditions, and such risks or other risks may be realized in the future which may further adversely affect the timing and/or cost of the MVP and the MVP Southgate project.

Given such risks and uncertainties, our midstream projects or those of our joint ventures may not be completed on schedule, within budgeted cost or at all. As a further example, public participation, including by pipeline infrastructure opponents, in the review and permitting process of projects, through litigation or otherwise, has previously introduced, and in the future can introduce, uncertainty and adversely affect project timing, completion and cost. See also Item 1A., "Risk Factors – The regulatory approval process for the construction of new transmission assets is very challenging, and, as demonstrated with the MVP pipeline, has resulted in significantly increased costs and delayed targeted in-service dates, and decisions by regulatory and/or judicial authorities in pending or potential proceedings relevant to the development of midstream assets, particularly any litigation instituted in the Fourth Circuit, such as regarding the MVP Southgate project and/or expansions or extensions of the MVP, are likely to impact our or the MVP Joint Venture's ability to obtain or maintain in effect all approvals and authorizations, including as may be necessary to complete certain projects in a timely manner or at all, or our ability to achieve the expected investment returns on the projects." Further, civil protests regarding environmental justice and social issues or challenges in project permitting processes related to such issues, including proposed construction and location of infrastructure associated with fossil fuels, poses an increased risk and may lead to increased litigation, legislative and regulatory initiatives and review at federal, state, tribal and local levels of government or permitting delays that can prevent or delay the construction of such infrastructure and realization of associated revenues.

Additionally, construction expenditures on projects generally occur over an extended period, yet we will not receive revenues from, or realize any material increases in cash flow as a result of, the relevant project until it is placed into service. Moreover, our cash flow from a project may be delayed or may not meet our expectations, including as a result of taxes which could potentially be calculated based on excess expenditures, inclusive of maintenance, incurred during extended court-driven construction delays. Furthermore, we may construct facilities to capture anticipated future growth in production and/or demand in a region in which such growth does not materialize or is delayed beyond our expectations. As a result, new facilities may not be able to attract enough throughput to achieve our expected investment return. Such issues in respect of the construction of midstream assets could adversely affect our business, financial condition, results of operations and liquidity.

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The regulatory approval process for the construction of new transmission assets is very challenging, and, as demonstrated with the MVP pipeline, has resulted in significantly increased costs and delayed targeted in-service dates, and decisions by regulatory and/or judicial authorities in pending or potential proceedings relevant to the development of midstream assets, particularly any litigation instituted in the Fourth Circuit, such as regarding the MVP Southgate project and/or expansions or extensions of the MVP, are likely to impact our or the MVP Joint Venture's ability to obtain or maintain in effect all approvals and authorizations, including as may be necessary to complete certain projects in a timely manner or at all, or our ability to achieve the expected investment returns on the projects.

Certain of our projects require regulatory approval from federal, state and/or local authorities prior to and/or in the course of construction, including any extensions from, expansions of or additions to our and the MVP Joint Venture's gathering, transmission and storage systems, as applicable. The approval process for certain projects has become increasingly slower and more difficult, due in part to federal, state and local concerns related to exploration and production, transmission and gathering activities and associated environmental impacts, and the increasingly negative public perception regarding, and opposition to, the oil and gas industry, including major pipeline projects like the MVP and MVP Southgate. Further, regulatory approvals and authorizations, even when obtained, have increasingly been subject to judicial challenge by activists requesting that issued approvals and authorizations be stayed and vacated.

Accordingly, authorizations needed for our or the MVP Joint Venture's projects, including any expansion of the MVP project and the MVP Southgate project or other extensions, may not be granted or, if granted, such authorizations may include burdensome or expensive conditions or may later be stayed or revoked or vacated, as was repeatedly the case with the construction of the MVP project, particularly in respect of litigation in the Fourth Circuit. Significant delays in the regulatory approval process for projects, as well as stays and losses of critical authorizations and permits, should they be experienced, have the potential to significantly increase costs, delay targeted in-service dates and/or affect operations for projects (among other adverse effects), as has happened with the MVP and the originally contemplated MVP Southgate projects and could occur in the future in the case of authorizations required for our or the MVP Joint Venture's current or future projects, including in respect of developing expansions or extensions, such as expansion of the MVP project and the MVP Southgate project.

Any such adverse developments and uncertainties could adversely affect our ability, and/or, as applicable, the ability for the MVP Joint Venture and its owners, including us, to achieve expected investment returns, adversely affect our willingness or ability and/or that of our joint venture partners to continue to pursue projects, and/or cause impairments, including to our equity investment in the MVP Joint Venture.

We have experienced and may further experience increased opposition with respect to our and the MVP Joint Venture's projects from activists in the form of lawsuits, intervention in regulatory proceedings and otherwise, which could result in adverse impacts to our business, financial condition, results of operations and liquidity. In particular, opponents were successful in past challenges with respect to the MVP project and certain challenges with respect to MVP project authorizations remain outstanding. Opposition is ongoing regarding the MVP Southgate project and is expected for future projects, including any expansions of the MVP. If ongoing or future challenges are successful, it could result in significant, adverse impacts to our business, financial condition, results of operations and liquidity. Such opposition has made it increasingly difficult to complete projects and place them in service and, following any in-service, may also affect operations or affect extensions and/or expansions of projects. Further, such opposition and/or adverse court rulings and regulatory determinations may have the effect of increasing the timeframe on necessary agency action to address actual or perceived concerns in prior adverse court rulings, or may have the effect of increasing the risk that at a future point joint venture partners may elect not to continue to pursue or fund a project, which could, absent additional project sponsors, significantly imperil the ability to complete the project. See also Item 1A., "Risk Factors – We have entered into joint ventures, and may in the future enter into additional or modify existing joint ventures, that might restrict our operational and corporate flexibility and divert our management's time and our resources. In addition, we exercise no control over joint venture partners and it may be difficult or impossible for us to cause these joint ventures or partners to take actions that we believe would be in our or the joint venture's best interests and these joint ventures are subject to many of the same risks to which we are subject." Challenges to our projects could adversely affect our business (including by increasing the possibility of investor activism), financial condition, results of operations, and liquidity.

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Increased competition from other companies that provide gathering, transmission and storage of natural gas, or from alternative fuel or energy sources, could negatively impact demand for our services, which could adversely affect our financial results.

Our ability to renew or replace existing contracts or add new contracts at rates sufficient to maintain or grow our Gathering segment and Transmission segment revenues and cash flows could be adversely affected by the activities of our midstream competitors. Our midstream systems compete primarily with other interstate and intrastate pipelines and storage facilities in the gathering, transmission and storage of natural gas. Some of our competitors have greater financial resources and may be better positioned to compete, including if the midstream industry moves towards greater consolidation. Some of these competitors may expand or construct gathering systems, transmission and storage systems that would create additional competition for the services we provide to our customers. In addition, certain of our customers have developed or acquired their own gathering infrastructure, and may acquire or develop gathering, transmission or storage infrastructure in the future, which could have a negative impact on the demand for our services depending on the location of such systems relative to our assets and our producer customers' drilling plans, commodity prices, existing contracts and other factors.

The policies of the FERC promoting competition in natural gas markets continue to have the effect of increasing the natural gas transmission and storage options for our customer base. As a result, in the future we could experience "turnback" of firm capacity as existing agreements expire. If we are unable to remarket this capacity or can remarket it only at substantially discounted rates compared to previous contracts, we may have to bear the costs associated with the turned back capacity. Increased competition could reduce the volumes of natural gas transported or stored on our systems or, in cases where we do not have long-term firm contracts, could force us to lower our transmission or storage rates.

Further, natural gas as a fuel competes with other forms of energy available to end-users, including coal, liquid fuels and, increasingly, renewable and alternative energy. Increases, whether driven by legislation, regulation or consumer preferences, in the availability and demand for renewable and alternative energy at the expense of natural gas (or increases in the demand for other sources of energy relative to natural gas based on price and other factors) could adversely affect our producer customers and lead to a reduction in demand for our natural gas gathering, transmission and storage services.

In addition, competition, including from renewable and alternative energy, could intensify the negative impact of factors that decrease demand for natural gas in the markets served by our systems, such as adverse economic conditions, weather, higher fuel costs and taxes or other governmental or regulatory actions that directly or indirectly increase the cost or limit the use of natural gas.

All of these competitive pressures could make it more difficult for us to retain our existing customers and/or attract new customers and/or additional volumes from existing customers as we seek to maintain and expand our business, which could have a material adverse effect on our business, financial condition, results of operations, and liquidity.

We may not be able to renew or replace expiring gathering, transmission or storage contracts at favorable rates, on a long-term basis or at all, and disagreements have occurred and may arise with contractual counterparties on the interpretation of existing or future contractual terms.

One of our exposures to market risk occurs at the time our existing gathering, transmission and storage contracts expire and are subject to renegotiation and renewal. As these contracts expire, we may have to negotiate extensions or renewals with existing customers or enter into new contracts with existing customers or other customers. We may be unable to do so on favorable commercial terms, if at all. Further, we also may be unable to maintain the economic structure of a particular contract with an existing customer or the overall mix of our contract portfolio. The extension or renewal of existing contracts and entry into new contracts depends on a number of factors beyond our control, including, but not limited to: (i) the level of existing and new competition to provide services to our markets; (ii) macroeconomic factors affecting natural gas economics for our current and potential customers; (iii) the balance of supply and demand, on a short-term, seasonal and long-term basis, in our markets; (iv) the extent to which the customers in our markets are willing to contract on a long-term basis or require capacity on our systems; (v) customers' existing and future downstream commitments; and (vi) the effects of federal, state or local regulations on the contracting practices of our customers and us. Additionally, disagreements may arise with contractual counterparties on the interpretation of contractual provisions, including during the negotiation, for example, of contract amendments required to be entered into upon the occurrence of specified events.

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Any failure to extend or replace a significant portion of our existing contracts or to extend or replace our significant contracts, or extending or replacing contracts at unfavorable or lower rates or with lower or no associated firm reservation fee revenues, or other disadvantageous terms relative to the prior contract structure, or disagreements or disputes on the interpretation of existing or future contractual terms, could have a material adverse effect on our business, financial condition, results of operations, and liquidity.

We may not be able to increase our customer throughput and resulting revenue due to competition and other factors, which could limit our ability to grow our Gathering segment and Transmission segment.

Our ability to increase our customer-subscribed capacity and throughput and resulting revenue is subject to numerous factors beyond our control, including competition from producers' existing contractual obligations to competitors, the location of our assets relative to those of competitors for existing or potential producer customers (or such producer customers' own midstream assets), takeaway capacity constraints out of the Appalachian Basin, commodity prices, producers' optionality in utilizing our (relative to third-party) systems to fill downstream commitments, and the extent to which we have available capacity when and where shippers require it. To the extent that we lack available capacity on our systems for volumes, or we cannot economically increase capacity, we may not be able to compete effectively with third-party systems for additional natural gas production in our areas of operation and capacity constraints, as well as commodity prices, may, as has occurred in the past, adversely affect the degree to which natural gas production occurs in the Appalachian Basin, and relatedly the degree to which our systems are utilized.

Our efforts to attract new customers or larger commitments from existing customers may be adversely affected by our desire to provide services pursuant to long-term firm contracts and contracts with MVCs. Our potential customers may prefer to obtain services under other forms of contractual arrangements which could require volumetric exposure or potentially direct commodity exposure, and we may not be willing to agree to such other forms of contractual arrangements.

If third-party pipelines and other facilities interconnected to our pipelines and facilities become unavailable to transport or process natural gas or do not accept deliveries of natural gas from us, our business, financial condition, results of operations, and liquidity could be adversely affected.

We depend on third-party pipelines and other facilities that provide receipt and delivery options to and from our transmission and storage systems. For example, our storage system and the MVP Joint Venture's transmission system interconnect, as applicable, with the following third-party interstate pipelines: Transcontinental Gas Pipe Line Company, LLC, East Tennessee Natural Gas, Texas Eastern, Eastern Gas Transmission, Columbia Gas Transmission, Tennessee Gas Pipeline Company, Rockies Express Pipeline LLC, National Fuel Gas Supply Corporation and ET Rover Pipeline, LLC, as well as multiple distribution companies. Similarly, our gathering systems have multiple delivery interconnects to multiple interstate pipelines. In the event that our or the MVP Joint Venture's access to such systems is impaired (or any third-party refuses to accept our or any of the MVP Joint Venture's deliveries), our or the MVP Joint Venture's operations could be adversely affected, resulting in adverse economic impact to us or the MVP Joint Venture.

Because we do not own these third-party pipelines or facilities, their continuing operation and access requirements are not within our control. If these or any other pipeline connections or facilities were to become unavailable for current or future volumes of natural gas due to repairs, damage to the facility, lack of capacity or any other reason, our or the MVP Joint Venture's ability to operate efficiently and ship natural gas to end markets could be restricted, as has occurred in the past. Any temporary or permanent interruption at any key pipeline interconnect or facility could have a material adverse effect on our business, financial condition, results of operations, and liquidity.

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A substantial majority of the services we provide on our transmission and storage system are subject to long-term, fixed-price "negotiated rate" contracts that are subject to limited or no adjustment, even if our cost to perform such services exceeds the revenues received from such contracts, and, as a result, our costs could exceed our revenues received under such contracts, we could be unable to achieve the expected investment return under such contracts, and/or our business, financial condition, results of operations, and liquidity could be adversely affected.

It is possible that costs to perform services under "negotiated rate" contracts could exceed the negotiated rates we have agreed to with our customers. If this occurs, it could decrease the cash flow realized by our systems and, therefore, could have a material adverse effect on our business, financial condition, results of operations, and liquidity. Under FERC policy, a regulated service provider and a customer may mutually agree to a "negotiated rate," and that contract must be filed with and accepted by the FERC. As of December 31, 2023, approximately 97% of the contracted firm transmission capacity on our system was subscribed under such "negotiated rate" contracts. Unless the parties to these "negotiated rate" contracts agree otherwise, the contracts generally may not be adjusted to account for increased costs that could be caused by inflation, greenhouse gas emission cost (such as carbon taxes, fees, or assessments) or other factors relating to the specific facilities being used to perform the services.

We have entered into joint ventures, and may in the future enter into additional or modify existing joint ventures, that might restrict our operational and corporate flexibility and divert our management's time and our resources. In addition, we exercise no control over joint venture partners and it may be difficult or impossible for us to cause these joint ventures or partners to take actions that we believe would be in our or the joint venture's best interests and these joint ventures are subject to many of the same risks to which we are subject.

We have entered into several joint ventures primarily pertaining to the construction and operation of certain midstream infrastructure, including the MVP Joint Venture and Eureka Midstream Holdings, and may in the future enter into additional joint venture arrangements with third parties, including in respect of any expansion of the MVP. Joint venture arrangements may restrict our operational and corporate flexibility. Joint venture arrangements and dynamics can also divert management and operating resources in a manner that is disproportionate to our ownership percentage in such ventures. Because we do not control all of the decisions of our joint ventures or joint venture partners, it may be difficult or impossible for us to cause these joint ventures or partners to take actions that we believe would be in our or the joint venture's best interests. Moreover, joint venture arrangements involve various risks and uncertainties, such as committing that we fund operating and/or capital expenditures, the timing and amount of which we may not control, and our joint venture partners may not act in a manner that we believe would be in our or the joint venture's best interests, may elect not to support further pursuit of projects, and/or may not satisfy their financial obligations to the joint venture. The loss of joint venture partner support in further pursuing or funding a project may, and would in the case of the MVP project, significantly adversely affect the ability to complete the project. In addition, such joint ventures are subject to many of the same risks to which we are subject.

Significant portions of our assets have been in service for several decades. There could be unknown events or conditions, or increased maintenance or repair expenses and downtime, associated with our assets that could have a material adverse effect on our business, financial condition, results of operations, and liquidity.

Significant portions of our transmission and storage system have been in service for several decades. The age and condition of these systems has contributed to, and could result in, adverse events, or increased maintenance or repair expenditures, and downtime associated with increased maintenance and repair activities, as applicable. Any such adverse events or any significant increase in maintenance and repair expenditures or downtime, or related loss of revenue, due to the age or condition of our systems could adversely affect our business, financial condition, results of operations, and liquidity. See also Item 1A., "Risk Factors – We and our joint ventures may incur significant costs and liabilities as a result of performance of our pipeline and storage integrity management programs and compliance with increasingly stringent safety regulation."

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We do not own all of the land on which our pipelines and facilities are located, which could disrupt our operations and future development.

We do not own all of the land on which our pipelines, storage systems and facilities have been constructed, and we have been, and in the future could be, subject to more onerous terms, and/or increased costs or delays, in attempting (or by virtue of the need to attempt) to acquire or to maintain use rights to land. Although many of these rights are perpetual in nature, we occasionally obtain the rights to construct and operate our pipelines and other facilities on land owned by third parties and governmental agencies for a specific period of time or in a manner in which certain facts could give rise to the presumption of the abandonment of the pipeline or other facilities. As has been the case in the past, if we were to be unsuccessful in negotiating or renegotiating rights-of-way or easements, we might have to institute condemnation proceedings on our FERC-regulated assets, the potential for which may have a negative effect on the timing and/or terms of FERC action on a project's certification application and/or the timing of any authorized activities, or relocate our facilities for non-regulated assets. The FERC has announced a policy that would presumptively stay the effectiveness of certain future construction certificates, which may limit when we are able to exercise condemnation authority. It is possible that the U.S. Congress may amend Section 7 of the NGA to codify the FERC's presumptive stay or otherwise limit, modify, or remove the ability to utilize condemnation. It is also possible that a court may limit, modify or remove an operator's ability to utilize condemnation under Section 7 of the NGA. A loss of rights-of-way, lease or easements or a relocation of our non-regulated assets could have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to pay dividends to our shareholders. Additionally, even when we own an interest in the land on which our pipelines, storage systems and facilities have been constructed, agreements with correlative rights owners have caused us to, and in the future may require that we, relocate pipelines and facilities or shut in storage systems and facilities to facilitate the development of the correlative rights owners' estate, or pay the correlative rights owners the lost value of their estate if they are not willing to accommodate development.

Our and the MVP Joint Venture's natural gas gathering, transmission and storage services, as applicable, are subject to extensive regulation by federal, state and local regulatory authorities. Changes in or additional regulatory measures adopted by such authorities, and related litigation, could have a material adverse effect on our business, financial condition, results of operations, and liquidity.

Our and the MVP Joint Venture's interstate natural gas transmission and storage operations, as applicable, are regulated by the FERC under the NGA and the Natural Gas Policy Act of 1978 (NGPA) and the regulations, rules and policies promulgated under those and other statutes. Our and the MVP Joint Venture's FERC-regulated operations are pursuant to tariffs approved by the FERC that establish rates (other than market-based rate authority), cost recovery mechanisms and terms and conditions of service to our customers. The FERC's authority extends to a variety of matters relevant to our operations.

Pursuant to the NGA, existing interstate transmission and storage rates, terms and conditions of service, and contracts may be challenged by complaint and are subject to prospective change by the FERC. Additionally, rate increases, changes to terms and conditions of service and contracts proposed by a regulated interstate pipeline may be protested and such actions can be delayed and may ultimately be rejected by the FERC. As of the filing of this Quarterly Report on Form 10-Q, we and the MVP Joint Venture currently hold authority from the FERC to charge and collect (i) "recourse rates," which are the maximum rates an interstate pipeline may charge for its services under its tariff, (ii) "discount rates," which are rates below the "recourse rates" and above a minimum level, (iii) "negotiated rates," which involve rates that may be above or below the "recourse rates," provided that the affected customers are willing to agree to such rates and that the FERC has approved the negotiated rate agreement, and (iv) market-based rates for some of our storage services from which we derive a small portion of our revenues. As of December 31, 2023, approximately 97% of our contracted firm transmission capacity was subscribed to by customers under negotiated rate agreements under our tariff, rather than recourse, discount or market-based rate contracts. There can be no guarantee that we or the MVP Joint Venture will be allowed to continue to operate under such rates or rate structures for the remainder of those assets' operating lives. Customers, the FERC or other interested stakeholders, such as state regulatory agencies, may challenge our or the MVP Joint Venture's rates offered to customers or the terms and conditions of service included in our tariffs. Neither we nor the MVP Joint Venture have an agreement in place that would prohibit customers from challenging our or the MVP Joint Venture's rates or tariffs. Any successful challenge against rates charged for our or the MVP Joint Venture's transmission and storage services, as applicable, could have a material adverse effect on our business, financial condition, results of operations, and liquidity.

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Any changes to the FERC's policies regarding the natural gas industry may have an impact on us, including the FERC's approach to pro-competitive policies as it considers matters such as interstate pipeline rates and rules and policies that may affect rights of access to natural gas transmission capacity and transmission and storage facilities. The FERC and U.S. Congress may continue to evaluate changes in the NGA or new or modified FERC regulations or policies that may impact our or the MVP Joint Venture's operations and affect our or the MVP Joint Venture's ability to construct new facilities and the timing and cost of such new facilities, as well as the rates charged to our or the MVP Joint Venture's customers and the services provided.

Our and the MVP Joint Venture's significant construction projects generally require review by multiple governmental agencies, including state and local agencies, whose cooperation is important in completing the regulatory process on schedule. Any agency's delay in the issuance of, or refusal to issue, authorizations or permits, issuance of such authorizations or permits with unanticipated conditions, or the loss of a previously-issued authorization or permit, for one or more of these projects may mean that we will not be able to pursue these projects or that they will be constructed in a manner or with capital requirements that we did not anticipate (as has been the case with our MVP project). Such delays, refusals, losses of permits, or resulting modifications to projects, certain of which we have experienced with respect to the MVP project and the originally contemplated MVP Southgate project, could materially and negatively impact the revenues and costs expected from these projects or cause us or our joint venture partners to abandon planned projects.

Failure to comply with applicable provisions of the NGA, the NGPA, federal pipeline safety laws and certain other laws, as well as with the regulations, rules, orders, restrictions and conditions associated with these laws, could result in the imposition of administrative and criminal remedies and civil penalties. For example, the FERC is authorized to impose civil penalties of up to approximately $1.5 million (adjusted periodically for inflation) per violation, per day for violations of the NGA, the NGPA or the rules, regulations, restrictions, conditions and orders promulgated under those statutes.

In addition, future federal, state or local legislation or regulations under which we or the MVP Joint Venture will operate may have a material adverse effect on our business, financial condition, results of operations, and liquidity.

We and our joint ventures may incur significant costs and liabilities as a result of performance of our pipeline and storage integrity management programs and compliance with increasingly stringent safety regulation.

The U.S. Department of Transportation, acting through PHMSA, and certain state agencies certificated by PHMSA, have adopted regulations requiring pipeline operators to develop an integrity management program for transmission pipelines located where a leak or rupture could impact high population sensitive areas (also known as High Consequence Areas) and newly defined Moderate Consequence Areas, and an integrity management program for storage wells, unless the operator effectively demonstrates by a prescriptive risk assessment that these operational assets have mitigated risks that could affect these predefined areas, as applicable. The regulations require operators, including us, to perform ongoing assessments of pipeline and storage integrity; identify and characterize applicable threats to pipeline segments and storage wells that could impact population sensitive areas; confirm maximum allowable operating pressures; maintain and improve processes for data collection, integration and analysis; repair and remediate facilities as necessary; and implement preventive and mitigating actions. In addition to population sensitive areas, PHMSA has recently adopted regulations extending existing design, operation and maintenance, and reporting requirements to onshore gathering pipelines in rural areas. Finally, new PHMSA regulations require operators of certain transmission pipelines to assess their integrity management and maintenance practices, comply with enhanced corrosion control and mitigation timelines, and follow new requirements for pipeline inspections following an extreme weather event or natural disaster.

The cost and financial impact of compliance will vary and depend on factors such as the number and extent of maintenance determined to be necessary as a result of the application of our integrity management programs, and such costs and financial impact could have a material adverse effect on us. Further, our pipeline and storage integrity management programs depend in part on inspection tools and methodologies developed, maintained, enhanced and applied, and certain testing conducted, by certain third parties, many of which are widely utilized within the natural gas industry. Advances in these tools and methodologies could identify potential and/or additional integrity issues for our assets. Consequently, we may incur additional costs and expenses to remediate those newly identified or potential issues, and we may not have the ability to timely comply with applicable laws and regulations. Additionally, pipeline and storage safety laws and regulations are subject to change and failures to comply with pipeline and storage safety laws and regulations, including changes in such laws and regulations or interpretations thereof that result in more stringent or costly safety standards, could have a material adverse effect on us.

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We may, and joint ventures of which we are the operator could, as is the case with the MVP Joint Venture, become subject to consent orders and agreements relating to integrity matters. Failure to comply with any such consent order or agreements could have adverse effects on our business.

Risks Related to the Equitrans Midstream Merger

We incurred significant indebtedness as a result of the Equitrans Midstream Merger, and any future indebtedness, as well as the restrictions under our and our subsidiaries' debt agreements, could adversely affect our operating flexibility, business, financial condition, results of operations, and liquidity.

As a result of the Equitrans Midstream Merger, we incurred additional indebtedness under EQT's revolving credit facility, and the outstanding debt under Eureka's revolving credit facility and the outstanding senior notes issued by EQM were consolidated by the Company. See Note 7 to the Condensed Consolidated Financial Statements for a discussion of EQT's revolving credit facility, Eureka's revolving credit facility and the outstanding senior notes issued by EQM. Eureka's revolving credit facility contains various covenants and restrictive provisions that limit Eureka's ability to, among other things: incur or guarantee additional debt, make distributions on or redeem or repurchase membership units, incur or permit liens on assets, enter into certain types of transactions with affiliates, enter into burdensome agreements, subject to certain specified exceptions, enter into certain mergers or acquisitions; and, dispose of all or substantially all of their respective assets.

Additionally, under Eureka's revolving credit facility, Eureka is required to maintain a Consolidated Leverage Ratio (as defined in the Eureka Credit Agreement) of not more than 4.75 to 1.00 (or not more than 5.25 to 1.00 for certain measurement periods following the consummation of certain acquisitions). As of the end of any fiscal quarter, Eureka may not permit the ratio of Consolidated EBITDA (as defined in the Eureka Credit Agreement) for the four fiscal quarters then ending to Consolidated Interest Charges (as defined in the Eureka Credit Agreement) to be less than 2.50 to 1.00. Eureka's revolving credit facility also contains certain events of default, including the occurrence of a change of control (as defined in the Eureka Credit Agreement). Events beyond the control of Eureka (including changes in general economic and business conditions) may affect the ability of Eureka to meet and comply with their respective financial obligations and covenants.

The provisions of our and our subsidiaries' debt agreements may affect our ability to obtain future financing and pursue attractive business opportunities and our flexibility in planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of these debt agreements could result in an event of default, which could enable creditors to, subject to the terms and conditions of the applicable agreement, declare any outstanding principal of that debt, together with accrued and unpaid interest, to be immediately due and payable. If the payment of the debt is accelerated, our assets may be insufficient to repay such debt in full, and in turn our shareholders could experience a partial or total loss of their investments. EQT's revolving credit facility, Eureka's revolving credit facility, the Term Loan Facility and certain of EQT's and EQM's senior notes each contain a cross default provision that applies to a default related to any other indebtedness the applicable borrower may have with an aggregate principal amount in excess of a specified threshold as set forth in the applicable debt documents.

Our and our subsidiaries' levels of debt could have important consequences to us, including that our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired, or such financing may not be available on favorable terms; our funds available for operations, future business opportunities and dividends to our shareholders may be reduced by that portion of our cash flow required to make interest payments on our or our subsidiaries' debt; we may be more vulnerable to competitive pressures or a downturn in our business or the economy generally; and our flexibility in responding to changing business and economic conditions may be limited.

Our ability to service our and our subsidiaries' current, or our or our subsidiaries' future respective debts, will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. Further, we view de-levering our business as a critical strategic objective given that leverage levels affect the manner in which we may pursue strategic and organic initiatives, our ability to respond to market and competitive pressures, and the competition for investment capital. Our ability to de-lever and the pace thereof will depend on our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, as well as the MVP Joint Venture's ability to execute on project-level financing, some of which are beyond our control.

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If our operating results are not sufficient to service our and our subsidiaries' current, or our or our subsidiaries' future indebtedness, as applicable, or our operating results affect our ability to comply with covenants in our debt agreements, we may be forced to take actions such as seeking modifications to the terms of our debt agreements, including providing guarantees, pledging assets as collateral, reducing dividends, reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets or seeking additional equity or debt capital. We may not be able to timely effect any of these actions on satisfactory terms or at all. Further, if our operating results are not sufficient to enable de-levering or affect the pace of de-levering, or if MVP project-level financing is not realized, the manner in which we may pursue strategic and organic initiatives, address market and competitive pressures, and compete for investment capital may be adversely affected, absent additional actions to de-lever, which may not be available to us on satisfactory terms or at all.

Our and our subsidiaries' current indebtedness and the additional debt we and/or our subsidiaries will incur in the future for, among other things, working capital, repayment of existing indebtedness, capital expenditures, capital contributions to joint ventures, including the MVP Joint Venture, acquisitions or operating activities may adversely affect our liquidity and therefore our ability to pay dividends to our shareholders.

In addition, our and our subsidiaries' level of indebtedness may be viewed negatively by credit rating agencies, our or our subsidiaries' credit ratings may be lowered, we may reduce or delay our planned capital expenditures or investments, and we may revise our shareholder returns strategy or other strategic plans. Changes in our or our subsidiaries' credit ratings may affect our access to the capital markets, the cost of short-term debt through interest rates and fees under our lines of credit, the interest rate on EQT's revolving credit facility, Eureka's revolving credit facility, the Term Loan Facility and EQT's senior notes with adjustable rates, the rates available on new long-term debt, our pool of investors and funding sources, the borrowing costs and margin deposit requirements on our OTC derivative instruments and credit assurance requirements, including collateral, in support of our midstream service contracts, joint venture arrangements or construction contracts.

We may not achieve the anticipated benefits of the Equitrans Midstream Merger, and the Equitrans Midstream Merger may disrupt our current plans or operations.

There can be no assurance that we will be able to successfully integrate Equitrans Midstream and the anticipated benefits of the transaction may not be realized fully or at all or may take longer to realize than expected. If the combined company is not able to realize the anticipated benefits expected from the transaction within the anticipated timing or at all, the combined company's business, financial condition and operating results may be adversely affected, the combined company's earnings per share may be diluted, the accretive effect of the Equitrans Midstream Merger may decrease or be delayed and the share price of the combined company may be negatively impacted. The integration of the two companies has required and will continue to require significant time and focus from management and could result in performance shortfalls as a result of the diversion of management's attention to such integration efforts. Difficulties in integrating Equitrans Midstream into our company may result in the combined company performing differently than expected, in operational challenges or in the failure to realize anticipated synergies on the anticipated timeline. Potential difficulties that may be encountered in the integration process include, among others, complexities associated with managing a larger, more complex, integrated business; potential unknown liabilities and unforeseen expenses associated with Equitrans Midstream; and inconsistencies between the two company's standards, controls, procedures and policies. In addition, our business may be negatively impacted if we are unable to effectively manage our expanded operations.

We are expected to continue to incur significant transaction costs in connection with the Equitrans Midstream Merger, which may be in excess of those anticipated by us.

We have incurred and are expected to continue to incur a number of non-recurring costs associated with the Equitrans Midstream Merger, combining the operations of the two companies and achieving desired synergies. These fees and costs have been, and will continue to be, substantial and could have an adverse effect on our financial condition and operating results. For the three and nine months ended September 30, 2024, we recognized $274.6 million and $298.7 million, respectively, of transaction costs related to the Equitrans Midstream Merger. Of this amount, for the three months ended September 30, 2024, we recognized severance and other termination benefits and stock-based compensation costs of $161.0 million.

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

We did not repurchase any equity securities registered under Section 12 of the Exchange Act during the third quarter of 2024.

On December 13, 2021, we announced that our Board of Directors approved a share repurchase program (the Share Repurchase Program) authorizing us to repurchase shares of our outstanding common stock for an aggregate purchase price of up to $1 billion, excluding fees, commissions and expenses. On September 6, 2022, we announced that our Board of Directors approved a $1 billion increase to the Share Repurchase Program, pursuant to which approval we are authorized to repurchase shares of our outstanding common stock for an aggregate purchase price of up to $2 billion, excluding fees, commissions and expenses. Repurchases under the Share Repurchase Program may be made from time to time in amounts and at prices we deem appropriate and will be subject to a variety of factors, including the market price of our common stock, general market and economic conditions, applicable legal requirements and other considerations. The Share Repurchase Program was originally scheduled to expire on December 31, 2023; however, on April 26, 2023, we announced that our Board of Directors approved a one-year extension of the Share Repurchase Program. As a result of such extension, the Share Repurchase Program will expire on December 31, 2024, but it may be suspended, modified or discontinued at any time without prior notice. As of September 30, 2024, we had purchased shares for an aggregate purchase price of $622.1 million, excluding fees, commissions and expenses, under the Share Repurchase Program since its inception, and the approximate dollar value of shares that may yet be purchased under the Share Repurchase Program is $1.4 billion.

Item 5. Other Information

During the three months ended September 30, 2024, none of our directors or "officers" (as such term is defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement" (as each term is defined in Item 408(a) of Regulation S-K).

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Item 6. Exhibits

Exhibit No.

Description

Method of Filing

2.01(a)+

Amended and Restated Purchase Agreement, dated December 23, 2022, among THQ Appalachia I, LLC, THQ-XcL Holdings I, LLC, the subsidiaries of the foregoing entities named on the signature pages thereto, EQT Production Company and EQT Corporation.

Incorporated herein by reference to Exhibit 2.1 to Form 8-K (#001-3551) filed on December 27, 2022.

2.01(b)

First Amendment to Amended and Restated Purchase Agreement, dated April 21, 2023, among THQ Appalachia I, LLC, THQ-XcL Holdings I, LLC, the subsidiaries of the foregoing entities named on the signature pages thereto, EQT Production Company and EQT Corporation.

Incorporated herein by reference to Exhibit 2.2 to Form 8-K (#001-3551) filed on August 22, 2023.

2.01(c)

Second Amendment to Amended and Restated Purchase Agreement, dated August 21, 2023, among THQ Appalachia I, LLC, THQ-XcL Holdings I, LLC, the subsidiaries of the foregoing entities named on the signature pages thereto, EQT Production Company and EQT Corporation.

Incorporated herein by reference to Exhibit 2.3 to Form 8-K (#001-3551) filed on August 22, 2023.

2.02+

Agreement and Plan of Merger, dated March 10, 2024, among EQT Corporation, Humpty Merger Sub Inc., Humpty Merger Sub LLC and Equitrans Midstream Corporation.

Incorporated herein by reference to Exhibit 2.1 to Form 8-K (#001-3551) filed on March 11, 2024.

3.01(a)

Restated Articles of Incorporation of EQT Corporation (as amended through November 13, 2017).

Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-3551) filed on November 14, 2017.

3.01(b)

Articles of Amendment to the Restated Articles of Incorporation of EQT Corporation (effective May 1, 2020).

Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-3551) filed on May 4, 2020.

3.01(c)

Articles of Amendment to the Restated Articles of Incorporation of EQT Corporation (effective July 23, 2020).

Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-3551) filed on July 23, 2020.

3.01(d)

Articles of Amendment to the Restated Articles of Incorporation of EQT Corporation (effective July 18, 2024).

Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-3551) filed on July 18, 2024.

3.02(a)

Amended and Restated Bylaws of EQT Corporation (as amended through December 12, 2023).

Incorporated herein by reference to Exhibit 3.2 to Form 8-K (#001-3551) filed on December 12, 2023.

3.02(b)

Amendment to Amended and Restated Bylaws of EQT Corporation (effective July 18, 2024).

Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-3551) filed on July 22, 2024.

4.01(a)

Indenture, dated August 1, 2014, among EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP), as issuer, the subsidiaries of EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP) party thereto, and The Bank of New York Mellon Trust Company, N.A., as trustee.

Incorporated herein by reference to Exhibit 4.1 to EQM Midstream Partners, LP's Form 8-K (#001-35574) filed on August 1, 2014.

4.01(b)

Second Supplemental Indenture, dated November 4, 2016, between EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP) and The Bank of New York Mellon Trust Company, N.A., as trustee, pursuant to which EQM Midstream Partners, LP’s 4.125% Senior Notes due 2026 were issued.

Incorporated herein by reference to Exhibit 4.2 to EQM Midstream Partners, LP's Form 8-K (#001-35574) filed on November 4, 2016.

4.01(c)

Fourth Supplemental Indenture, dated June 25, 2018, between EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP) and The Bank of New York Mellon Trust Company, N.A., as trustee, pursuant to which EQM Midstream Partners, LP’s 5.500% Senior Notes due 2028 were issued.

Incorporated herein by reference to Exhibit 4.4 to EQM Midstream Partners, LP's Form 8-K (#001-35574) filed on June 25, 2018.

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Exhibit No.

Description

Method of Filing

4.01(d)

Fifth Supplemental Indenture, dated June 25, 2018, between EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP) and The Bank of New York Mellon Trust Company, N.A., as trustee, pursuant to which EQM Midstream Partners, LP’s 6.500% Senior Notes due 2048 were issued.

Incorporated herein by reference to Exhibit 4.6 to EQM Midstream Partners, LP's Form 8-K (#001-35574) filed on June 25, 2018.

4.02

Indenture, dated June 18, 2020, between EQM Midstream Partners, LP and The Bank of New York Mellon Trust Company, N.A., as trustee, pursuant to which EQM Midstream Partners, LP’s 6.000% Senior Notes due 2025 and 6.500% Senior Notes due 2027 were issued.

Incorporated herein by reference to Exhibit 4.1 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on June 18, 2020.

4.03

Indenture, dated January 8, 2021, between EQM Midstream Partners, LP and The Bank of New York Mellon Trust Company, N.A., as trustee, pursuant to which EQM Midstream Partners, LP’s 4.50% Senior Notes due 2029 and 4.75% Senior Notes due 2031 were issued.

Incorporated herein by reference to Exhibit 4.1 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on January 8, 2021.

4.04

Indenture, dated June 7, 2022, between EQM Midstream Partners, LP and U.S. Bank Trust Company, National Association, as trustee, pursuant to which EQM Midstream Partners, LP’s 7.500% Senior Notes due 2027 and 7.500% Senior Notes due 2030 were issued.

Incorporated herein by reference to Exhibit 4.1 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on June 7, 2022.

4.05

Indenture, dated February 26, 2024, between EQM Midstream Partners, LP and U.S. Bank Trust Company, National Association, as trustee, pursuant to which EQM Midstream Partners, LP’s 6.375% Senior Notes due 2029 were issued.

Incorporated herein by reference to Exhibit 4.1 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on February 26, 2024.

10.01+

Fourth Amended and Restated Credit Agreement, dated July 22, 2024, among EQT Corporation, PNC Bank, National Association, as Administrative Agent, Swing Line Lender and L/C Issuer, and the other lenders party thereto.

Incorporated herein by reference to Exhibit 10.1 to Form 8-K (#001-3551) filed on July 22, 2024.

10.02+

Fourth Amendment to Credit Agreement, dated July 22, 2024, among EQT Corporation, PNC Bank, National Association, as Administrative Agent, and the other lenders party thereto.

Incorporated herein by reference to Exhibit 10.2 to Form 8-K (#001-3551) filed on July 22, 2024.

10.03**

Second Amendment to the EQT Corporation 2020 Long-Term Incentive Plan.

Incorporated herein by reference to Exhibit 10.3 to Form 8-K (#001-3551) filed on July 22, 2024.

10.04(a)

Third Amended and Restated Limited Liability Company Agreement of Mountain Valley Pipeline, LLC, dated as of April 6, 2018, by and among MVP Holdco, LLC, US Marcellus Gas Infrastructure, LLC, WGL Midstream MVP LLC (formerly WGL Midstream, Inc.), Con Edison Gas Pipeline and Storage, LLC, RGC Midstream, LLC and Mountain Valley Pipeline, LLC. Specific items in this exhibit have been redacted, as marked by three asterisks [***], because confidential treatment for those items has been granted by the SEC. The redacted material has been separately filed with the SEC.

Incorporated herein by reference to Exhibit 10.1 to EQM Midstream Partners, LP's Form 10-Q/A (#001-35574) for the quarter ended March 31, 2018.

10.04(b)

First Amendment to Third Amended and Restated Limited Liability Company Agreement of Mountain Valley Pipeline, LLC, dated as of February 5, 2020, by and among MVP Holdco, LLC, US Marcellus Gas Infrastructure, LLC, WGL Midstream MVP LLC (formerly WGL Midstream, Inc.), Con Edison Gas Pipeline and Storage, LLC, RGC Midstream, LLC and Mountain Valley Pipeline, LLC.

Incorporated herein by reference to Exhibit 10.21(b) to Equitrans Midstream Corporation's Form 10-K (#001-38629) for the year ended December 31, 2019.

Table of Contents

Exhibit No.

Description

Method of Filing

10.05(a)**

Equitrans Midstream Corporation Amended and Restated Directors' Deferred Compensation Plan.

Incorporated herein by reference to Exhibit 10.18 to Equitrans Midstream Corporation’s Form 10-Q (#001-38629) for the quarter ended March 31, 2020.

10.05(b)**

Form of Equitrans Midstream Corporation Director Participant Award Agreement.

Incorporated herein by reference to Exhibit 10.10 to Equitrans Midstream Corporation’s Form 10-Q (#001-38629) for the quarter ended March 31, 2019.

10.06(a)**

Amended and Restated Confidentiality, Non-Solicitation and Non-Competition Agreement, dated November 13, 2018, between Equitrans Midstream Corporation and Thomas F. Karam.

Incorporated herein by reference to Exhibit 10.9 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on November 13, 2018.

10.06(b)**

First Amendment, dated February 20, 2023, to Amended and Restated Confidentiality, Non-Solicitation and Non-Competition Agreement, dated as of November 13, 2018, between Equitrans Midstream Corporation and Thomas F. Karam.

Incorporated herein by reference to Exhibit 10.15(b) to Equitrans Midstream Corporation’s Form 10-K (#001-38629) for the year ended December 31, 2022.

10.06(c)**

Second Amendment, effective September 6, 2023, to Amended and Restated Confidentiality, Non-Solicitation and Non-Competition Agreement, dated November 13, 2018, between Equitrans Midstream Corporation and Thomas F. Karam.

Incorporated herein by reference to Exhibit 10.3 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on September 7, 2023.

10.06(d)**

Transition Agreement, dated September 6, 2023, between Equitrans Midstream Corporation and Thomas F. Karam.

Incorporated herein by reference to Exhibit 10.1 to Equitrans Midstream Corporation’s Form 8-K (#001-38629) filed on September 7, 2023.

10.06(e)**+

Separation Agreement and General Release, dated August 14, 2024, between EQT Corporation and Thomas F. Karam.

Filed herewith as Exhibit 10.06(e).

31.01

Rule 13(a)-14(a) Certification of Principal Executive Officer.

Filed herewith as Exhibit 31.01.

31.02

Rule 13(a)-14(a) Certification of Principal Financial Officer.

Filed herewith as Exhibit 31.02.

Section 1350 Certification of Principal Executive Officer and Principal Financial Officer.

Furnished herewith as Exhibit 32.

101

Interactive Data File.

Filed herewith as Exhibit 101.

104

Cover Page Interactive Data File.

Formatted as Inline XBRL and contained in Exhibit 101.

+ Certain schedules and similar attachments to this exhibit have been omitted pursuant to Item 601(a)(5) of Regulation S-K. EQT Corporation agrees to provide a copy of any omitted schedule or attachment to the Securities and Exchange Commission or its staff upon request.

** Management contract or compensatory arrangement.

Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.


						EQT CORPORATION
						(Registrant)


			By:			/s/ Jeremy T. Knop
						Jeremy T. Knop
						Chief Financial Officer

Date: October 30, 2024

Exhibit 10.06(e)

SPECIFIC EXHIBITS TO THIS AGREEMENT HAVE BEEN REDACTED BECAUSE SUCH EXHIBITS ARE BOTH NOT MATERIAL AND ARE OF A TYPE THAT EQT CORPORATION TREATS AS CONFIDENTIAL. THE REDACTED EXHIBITS HAVE BEEN MARKED IN THIS EXHIBIT AT THE APPROPRIATE PLACE WITH THREE ASTERISKS [***].

SEPARATION AGREEMENT AND GENERAL RELEASE

This Separation Agreement and General Release (this “Agreement”) is made and entered into by and between THOMAS KARAM (“Employee”) and EQT CORPORATION (including its predecessors, subsidiaries and affiliates, collectively, “EQT” or “Company”).

WHEREAS, on July 22, 2024, EQT Corporation, Humpty Merger Sub Inc., an indirect wholly owned subsidiary of EQT, and Humpty Merger Sub LLC, an indirect wholly owned subsidiary of EQT Corporation, completed the transactions contemplated by the Agreement and Plan of Merger (the “Merger Agreement”) with Equitrans Midstream Corporation (“ETRN”);

WHEREAS, in connection with the Mergers (as such term is defined in the Merger Agreement), Employee’s employment with the Company terminated immediately following the First Merger and prior to the Second Merger (as such terms are defined in the Merger Agreement) on July 22, 2024;

WHEREAS, Employee is a party to one or more written agreements with ETRN providing for severance benefits in the event of certain qualifying terminations of Employee’s employment and certain restrictive covenants that have been communicated to or executed by Employee (such agreement(s), the “Severance Agreement”); and

WHEREAS, EQT desires to provide Employee with consideration in exchange for, among other things, Employee’s general release of all claims against EQT and the other Releasees (as defined below), including any claims arising out of Employee’s employment and the termination thereof in accordance with the terms of the Severance Agreement.

NOW, THEREFORE, in consideration of the respective representations, acknowledgments, covenants and agreements of the parties, as expressly set forth in this Agreement, the parties, intending to be legally bound, agree as follows:

1.Employee understands that, effective immediately following the First Merger and prior to the Second Merger on July 22, 2024 (the “Date of Termination”), his/her employment with the Company was terminated other than for cause. Employee agrees that all other officer, director and employment positions that Employee held at or through ETRN or EQT, and each of their parents, subsidiaries, predecessors and successors, ceased effective as of the Date of Termination and Employee agrees to promptly execute such additional documentation as requested by the Company to effectuate the foregoing. Employee represents that he/she has been properly paid for all time worked and received all salary, wages, bonuses, payment for accrued but unused vacation or paid time off, expense reimbursements, and all other amounts of any kind due as of the date Employee signs this Agreement, with the exception of payments under the applicable short-term incentive plan, which shall be made no later than August 16, 2024 in accordance with the Merger Agreement, and awards made pursuant to the Company Equity Plan (as defined in the Merger Agreement), which shall be settled in accordance with the terms provided in the Merger Agreement, the Company Equity Plan and applicable award agreement(s).

2.In exchange for Employee’s agreement to the terms of this Agreement and his/her release of all claims as set forth in Paragraph 3 below, EQT and Employee agree as follows:

(a)Provided that the ADEA Effective Date (defined below) occurs and Employee complies with the terms and conditions of this Agreement, EQT shall provide the following compensation and benefits to Employee in full satisfaction of the Company’s obligations under the Severance Agreement:

(i)A lump sum cash payment of $2,876,705 (less applicable withholding obligations, such as for income taxes and FICA), which represents the sum of:

(A)thirty (30) months of Employee’s annualized base salary in effect as of the Date of Termination; plus

(B)an additional lump sum of $1,250,000, equal to two (2) times Employee’s annual target bonus opportunity under the Company’s applicable Short-Term Incentive Plan as in effect on the Date of Termination; plus

(C)thirty (30) times the Consolidated Omnibus Budget Reconciliation Act rate for continuation of family coverage in effect on the Date of Termination.

(b)Subject to Employee’s execution of, and satisfaction of the requirements of, this Agreement, the cash payment contemplated by subparagraph 2(a)(i) shall be paid within fifteen (15) days of the ADEA Effective Date, as defined below.

(c)Employee acknowledges and agrees that but for his/her execution and non-revocation of this Agreement, he/she would not be entitled to receive the consideration identified in subparagraph 2(a)(i), and in no event shall Employee be entitled to severance pay or benefits beyond those specified in subparagraph 2(a)(i). Employee acknowledges and agrees that, except as expressly set forth under this Agreement, Employee is not entitled to receive any additional compensation, bonus, equity compensation, payment in lieu of any paid time off, severance payments or other payments or benefits of any kind from EQT or ETRN, whether contractual or otherwise, with respect to Employee’s employment with EQT, including, without limitation, any payments of any kind under the Severance Agreement. Notwithstanding the foregoing or anything to the contrary herein, this Paragraph 2(c) shall not impact Employee’s currently held equity compensation awards, Key Talent Award, and/or Transaction Retention Award (each, as applicable), any vested or accrued benefits pursuant to any applicable plan, agreement, or arrangement of ETRN or EQT, and each of their parents, subsidiaries, joint ventures, affiliates, predecessors and successors (collectively, the “EQT Companies”), any right to indemnification, advancement of legal fees or directors and officers liability insurance coverage existing under the constituent documents of the EQT Companies (as in effect from time to time), and Employee’s right to elect certain continued medical coverage under the Consolidated Omnibus Budget Reconciliation Act of 1985 (“COBRA”) or the right to convert certain insurance coverage to a personal plan, as applicable, and reimbursements for legitimate business expenses owed to Employee by the EQT Companies pursuant to the expense reimbursement policies of the EQT Companies; provided, that Employee submits such expenses for reimbursement no later than 30 days following the Date of Termination, which, in each case, shall remain

subject to the terms and conditions governing those awards or rights and any applicable terms of the Merger Agreement.

(d)EQT will not contest a claim filed by Employee for unemployment compensation benefits. However, Employee understands that eligibility for unemployment compensation is determined by the applicable state, not by EQT.

(e)The parties acknowledge and agree that the payments and other covenants described herein constitute fair and adequate consideration for: (i) Employee’s agreement to keep the terms of this Agreement confidential; (ii) Employee’s release of all claims and causes of action against the Releasees (as defined below); and (iii) all other covenants and commitments mentioned in this Agreement.

(f)To the extent the Worker Adjustment and Retraining Notification Act (“WARN Act”), or other applicable law, may have otherwise required the Company to provide notice to Employee related to a plant closure or layoff, the parties hereby agree that the payments made to Employee described in Paragraph 2(a) above shall offset, and be in lieu of, any required notice and/or any corresponding payments to Employee.

3.In consideration for the promises of the Company set forth in this Agreement, Employee and his/her agents, attorneys, heirs, executors, administrators, personal representatives, and assigns hereby voluntarily, irrevocably and unconditionally release and forever discharge EQT, each of its subsidiaries, predecessors and successors in interest, and other affiliates (for the avoidance of doubt, including ETRN and its subsidiaries, predecessors, successors in interest, and other affiliates), and each of the foregoing entities’ respective past, present and future officers, directors, managers, members, agents, representatives, employees and shareholders, as well as the heirs, successors or assigns of any of such persons or entities (severally and collectively called “Releasees”), jointly and individually, from any and all claims, demands, issues, or causes of action, including any and all claims, demands, issues, or causes of action arising out of, or in any way related to Employee’s employment with Releasees and/or his/her separation from employment with Releasees, whether asserted by him/her or on his/her behalf by any person or entity and whether known or unknown, and arising on or before the date Employee signs this Agreement. This release includes, but is not limited to, claims for back pay, front pay, emotional distress, compensatory damages, liquidated damages, punitive damages, fringe benefits, reinstatement, attorneys’ fees, interest, costs and/or remedies or relief of any sort whatsoever under any possible legal, equitable, tort, contract or statutory theory, including, but not limited to, any claims arising under Title VII of the Civil Rights Act of 1964, the Civil Rights Act of 1991, sections 1981 through 1988 of Title 42 of the United States Code, the Age Discrimination in Employment Act of 1967, the Immigration Reform Control Act, the Americans with Disabilities Act of 1990, the Older Workers Benefit Protection Act, the Family Medical Leave Act, the WARN Act, the Families First Coronavirus Response Act, the Coronavirus Aid, Relief, and Economic Security Act, the Pennsylvania Human Relations Act, the Pennsylvania Wage Payment and Collection Law, the Pennsylvania Minimum Wage Act, the Pennsylvania Medical Marijuana Act, the Pennsylvania Whistleblower Law, the Commonwealth of Pennsylvania and United States Constitutions, and any other federal, state and local statutes, ordinances, executive orders or regulations, under theories of unjust dismissal or wrongful discharge, breach of contract or fiduciary duty, or based on any intentional or negligent tort which Employee has, had or may have, whether known or unknown and of whatever kind or nature against Releasees, which arose on or before the date Employee signs this Agreement. Employee also hereby releases all Releasees from any and all claims for: (i) the fees, costs, expenses and

interest of any and all attorneys who now represent or who have at any time represented Employee in connection with this Agreement and/or in connection with any of the matters released in this Agreement; and (ii) wages, payments, benefits, attorneys’ fees, interest, costs and/or remedies or relief of any kind whatsoever arising under the WARN Act and/or any other laws requiring notice of plant closure or layoff. For the avoidance of doubt, for purposes of this Agreement, any references to statutes include any applicable amendments thereto.

The release in the preceding paragraph is intended to be a general release, excluding only claims which Employee is legally barred from releasing. Employee understands, and EQT expressly acknowledges, that the release does not include: any claims that cannot be released or waived as a matter of law; any claim for or right to vested or accrued benefits under any EQT Companies’ plans, agreements, or arrangements; claims for breach of this Agreement; or any right to enforce this Agreement and any claims based on acts or events occurring after Employee signs this Agreement. The release also shall not affect: (i) Employee’s equity compensation awards, Key Talent Award, and/or Transaction Retention Award, (ii) any right to indemnification, advancement of legal fees or directors and officers liability insurance coverage existing under the constituent documents of the EQT Companies (as in effect from time to time), (iii) Employee’s right to elect certain continued medical coverage under COBRA or the right to convert certain insurance coverage to a personal plan, as applicable, and (iv) reimbursements for legitimate business expenses owed to Employee by the EQT Companies pursuant to the expense reimbursement of the EQT Companies; provided, that Employee submits such expenses for reimbursement no later than thirty (30) days following the Date of Termination. Nothing in this Agreement prevents a challenge to the validity of the Agreement or prohibits the filing of a charge or complaint with, or testimony, assistance or participation in or cooperation with, any investigation, proceeding or hearing conducted by any federal, state or local governmental agency, including but not limited to the Equal Employment Opportunity Commission. However, Employee explicitly waives any right to receive monetary damages in any agency action against any Releasees.

4.Employee warrants that he/she has no actions or claims now pending against any of the Releasees in any court of the United States or any State thereof based upon any acts or events arising out of or related to his/her employment with Releasees or his/her separation from employment with Releasees. Notwithstanding any other language in this Agreement, the parties understand that this Agreement does not prohibit Employee from filing an administrative charge of alleged employment discrimination or unlawful practices with the Equal Employment Opportunity Commission, the National Labor Relations Board or other governmental agency or commission. Employee, however, waives his/her right to monetary or other recovery should any federal, state or local administrative agency pursue any claims on his/her behalf arising out of or relating to his/her employment with and/or separation from employment with any of the Releasees. This means that by signing this Agreement, Employee will have waived any right he/she had to obtain a recovery if an administrative agency pursues a claim against any of the Releasees based on any actions taken by any of the Releasees up to the date of the signing of this Agreement, and that Employee will have released the Releasees of any and all claims of any nature arising up to the date of the signing of this Agreement. However, nothing in this Agreement prevents Employee from (i) making any reports to or seeking or receiving any awards based upon Employee’s reporting of violations of laws or regulations containing whistleblower provisions or (ii) participating, cooperating, or testifying in any action, investigation, or proceeding with, or providing information to, any governmental agency or legislative body, any self-regulatory organization, and/or pursuant to the Sarbanes-Oxley Act.

5.By entering into this Agreement, EQT in no way thereby admits that it or any of the Releasees has treated Employee unlawfully or wrongfully in any way. Neither this Agreement nor the implementation thereof shall be construed to be, or shall be admissible in any proceedings as, evidence of any admission by EQT or any of the Releasees of any violation of or failure to comply with any federal, state, or local law, ordinance, agreement, rule, regulation or order.

6.Employee, upon reasonable notice and at reasonable times, agrees to cooperate with the Company in the prosecution of or defense of litigation and in investigations of any claims or actions now in existence or that may be threatened or brought in the future relating to events or occurrences that transpired while Employee was employed by the Company or any of the Releasees (for the avoidance of doubt, including while Employee was employed by ETRN). Employee shall not testify for, cooperate with, encourage, or counsel non-governmental attorneys or their clients in the investigation, pursuit or defense of any disputes, claims, lawsuits, arbitrations, charges or complaints by any non-governmental third party against any of the Releasees, unless compelled to do so by order or subpoena issued by a court or governmental agency holding jurisdiction over Employee, and in such case only after first notifying the Company in writing within three days after receipt of such subpoena or court order. Employee further agrees to cooperate with Company in opposing the issuance and enforcement of such subpoena or court order. Employee further agrees to notify the Company in writing and within three days after receipt in the event of any requests for information, documents or testimony that Employee receives in connection with any of the foregoing. Employee acknowledges his/her continuing obligations under EQT’s policies to preserve EQT’s, and all Releasees, confidential information and that he/she has returned all EQT property in his/her possession, including EQT confidential information (which includes, for the avoidance of doubt, any confidential information of ETRN). Further, the parties agree that, with respect to breaches of Paragraph 6, monetary compensation is not sufficient and EQT shall be entitled to (without posting any bond or deposit) specific performance and/or other injunctive relief from any court of competent jurisdiction in order to enforce or prevent any violations of such obligations. The EQT Companies will promptly advance or reimburse any reasonable costs and expenses incurred by Employee as a result of Employee’s obligations under this Paragraph, and to the extent that Employee’s cooperation under this Paragraph exceeds four (4) hours in any month, the EQT Companies shall promptly compensate Employee at the rate of $250 per hour for each hour, or portion thereof, in excess of four (4) hours in a month. Nothing in this Paragraph is intended to alter or shall alter the Company’s obligations to provide insurance coverage and indemnification with respect to the Employee pursuant to Section 5.11 of the Merger Agreement.

7.Employee agrees that, except as required by law and as permitted by this Paragraph and Paragraph 4, the terms and conditions of this Agreement will be kept strictly confidential and will not be discussed, disclosed, or revealed, directly or indirectly, to any person, corporation, or other entity, other than to Employee’s spouse, attorney, accountant for use on tax matters or to government taxing agencies or taxing officials. Nothing in this Agreement prohibits Employee from: (i) reporting possible violations of federal, state, or local law or regulation to any governmental agency or entity, or from making other disclosures that are protected under the whistleblower provisions of federal, state, or local law or regulation; or (ii) disclosing confidential information and/or trade secrets when this disclosure is solely for the purpose of: (a) reporting possible violations of federal, state, or local law or regulation to any governmental agency or entity; (b) working with legal counsel in order to determine whether possible violations of federal, state, or local law or regulation exist; or (c) filing a complaint or other document in a lawsuit or other proceeding, if such filing is made under seal. Any disclosures of trade secrets must comply with the restrictions in the Defend Trade Secrets Act of 2016 (“DTSA”). The DTSA provides that no individual will be held criminally or

civilly liable under Federal or State trade secret law for the disclosure of a trade secret that: is made in confidence to a Federal, State, or local government official, either directly or indirectly, or to an attorney; and made solely for the purpose of reporting or investigating a suspected violation of law; or, is made in a complaint or other document if such filing is under seal so that it is not made public. Also, an individual who pursues a lawsuit for retaliation by an employer for reporting a suspected violation of the law may disclose the trade secret to the attorney of the individual and use the trade secret information in the court proceeding, if the individual files any document containing the trade secret under seal, and does not disclose the trade secret, except as permitted by court order.

8.Employee also agrees (unless otherwise required by law or legal process or as permitted by Paragraphs 4 and 7 of this Agreement) not to make any defamatory, maliciously untrue, or disparaging remarks, comments or statements, verbally or in writing, regarding any Releasee, their respective businesses, products or services or their respective directors, officers or persons known by Employee to be employees of the Releasees in their capacity as employees. EQT agrees to instruct its named executive officers (as disclosed in EQT’s most recent annual proxy statement and who are currently employed by EQT) and current members of its Board of Directors not to make any defamatory, maliciously untrue, or disparaging remarks, comments, or statements about Employee. Nothing in this Agreement shall prohibit Employee from engaging in concerted activity protected under the National Labor Relations Act (to the extent applicable), including relative to the terms and conditions of Employee’s employment, Employee’s ability to file unfair labor practice charges or assist others in doing so, and cooperating in any investigative process with the National Labor Relations Board. Nothing in this Agreement prevents Employee from discussing or disclosing information about unlawful acts in the workplace, such as harassment or discrimination or any other conduct that Employee has reason to believe is unlawful.

9.In the event that the Centers for Medicare & Medicaid Services (CMS) (this term includes any related agency representing Medicare’s interests) determines that Medicare has an interest in the payment to Employee under this Agreement, Employee agrees to (i) indemnify, defend and hold the Company harmless from any action by CMS relating to medical expenses of Employee, including full satisfaction by Employee of any lien(s) asserted by CMS; (ii) reasonably cooperate with the Company upon request with respect to any information needed to satisfy the reporting requirements under Section 111 of the Medicare, Medicaid, and SCHIP Extension Act of 2007, if applicable, including completion of the Medicare Information Authorization Form (Attachment A to this Agreement); and (iii) waive any and all future actions against the Company for any private cause of action for damages pursuant to 42 U.S.C. § 1395y(b)(3)(A).

10.Employee acknowledges that this Agreement includes a release and waiver of any and all claims of age discrimination Employee may have under the Age Discrimination in Employment Act and the Older Workers Benefit Protection Act (collectively, “ADEA”) arising prior to the date of this Agreement. Employee acknowledges that he/she has been given forty-five (45) calendar days from the day Employee received this Agreement to review and consider this Agreement before executing it, and that he/she is hereby advised in writing to consult with an attorney before executing it. Employee further acknowledges that he/she has had a full and fair opportunity to consult with an attorney, that he/she has carefully read and fully understands all of the provisions of this Agreement, that he/she has discussed this Agreement with such attorneys if he/she has chosen to, and that he/she is voluntarily executing and entering into this Agreement, intending to be legally bound hereby. Employee has carefully read and fully understands the attached Exhibit A, which reflects the job titles and ages of employees in the decisional unit selected and not selected for termination of employment at this time, in accordance with the Older Workers

Benefit Protection Act. If Employee signs this Agreement in less than forty-five (45) calendar days, Employee acknowledges that he/she has thereby knowingly and voluntarily waived his/her right to the full forty-five (45) calendar day period. Employee acknowledges and agrees that any changes made since Employee’s receipt of this Agreement are not material and/or were made at Employee’s request and shall not restart the forty-five (45) day review period.

11.Employee and the Company agree that, for a period of seven (7) calendar days following the execution of this Agreement, Employee may revoke those provisions of this Agreement releasing and waiving Employee’s rights and claims under the ADEA, and those provisions shall not become effective or enforceable until the revocation period has expired without Employee exercising the right to revoke. If Employee wishes to revoke, he/she must do so by delivery of a written notice to the office of the General Counsel, EQT Corporation, 625 Liberty Avenue, Suite 1700, Pittsburgh, PA, 15222, by no later than 5:00 p.m. on the seventh calendar day following Employee’s execution of this agreement. All other terms and conditions of this Agreement shall be binding and enforceable immediately upon Employee’s execution of this Agreement, and shall remain effective regardless of whether Employee revokes Employee’s waiver and release of ADEA rights and claims.

12.This Agreement shall, upon execution by Employee, immediately become effective and enforceable, except for the waiver of ADEA claims which shall not become effective or enforceable until the expiration without exercise of the seven (7) day revocation period described in Paragraph 11 above (“ADEA Effective Date”).

13.If Employee has materially or willfully breached this Agreement or revokes his/her execution of this Agreement, EQT, in addition to any other remedies it may have (whether under applicable law or otherwise), shall be entitled to (i) suspend payment of the payments contemplated by Paragraph 2 of this Agreement to the extent not previously paid or provided and (ii) the prompt return by Employee of any portion of such payments previously paid or provided pending a court or arbitrator determination of whether such breach has occurred. Without limiting the generality of the foregoing, in the event of either party’s actual or threatened breach of any condition set forth in this Agreement, the other party shall be entitled to seek injunctive relief (including temporary restraining orders, preliminary injunctions and permanent injunctions), without posting a bond, in any court of competent jurisdiction. Employee understands that by entering into this Agreement he/she will be limiting the availability of certain remedies that he/she may have against the Releasees and limiting also his/her ability to pursue certain claims against the Releasees.

14.This Agreement is intended to comply with Section 409A of the Internal Revenue Code of 1986, as amended and the Treasury regulations thereunder (“Section 409A”) or an exemption thereunder and shall be construed and administered to the fullest extent allowed to avoid any additional tax under Section 409A. Notwithstanding any other provision of this Agreement, payments provided under this Agreement may only be made upon an event and in a manner that complies with Section 409A or an applicable exemption. Any payments under this Agreement that may be excluded from Section 409A either as separation pay due to an involuntary separation from service or as a short-term deferral shall be excluded from Section 409A to the maximum extent possible. Notwithstanding anything herein to the contrary, (i) if on the Date of Termination, Employee is a “specified employee” as defined in Section 409A, and the deferral of the commencement of any payments or benefits otherwise payable hereunder as a result of such termination of employment is necessary in order to prevent any accelerated or additional tax under Section 409A (e.g., because they do not satisfy the short-term deferral exception and/or the

separation pay exception), then the Company will defer the commencement of the payment of any such payments or benefits hereunder (without any reduction in such payments or benefits ultimately paid or provided to Employee) until the first business day to occur following the date that is six (6) months following the Date of Termination (or the earliest date as is permitted under Section 409A), which initial payment will include the payments and benefits that would have been paid to Employee during such six (6) month period but for the delay required by Section 409A; and (ii) if any other payments of money or other benefits due to Employee hereunder could cause the application of an accelerated or additional tax under Section 409A, such payments or other benefits shall be deferred if deferral will make such payment or other benefits compliant under Section 409A, or otherwise such payment or other benefits shall be restructured, to the extent possible, in a manner that does not cause such an accelerated or additional tax. The Company shall consult with Employee in good faith regarding the implementation of the preceding sentence. For purposes of Section 409A, each installment payment provided under this Agreement shall be treated as a separate payment. Any payments to be made under this Agreement upon a termination of employment shall only be made upon a “separation from service” under Section 409A. If any payment subject to Section 409A is contingent on the delivery of a release by Employee and could occur in either of two (2) years, the payment will occur in the later year. Notwithstanding the foregoing, the Company makes no representations that the payments and benefits provided under this Agreement comply with Section 409A and in no event shall the Company be liable for all or any portion of any taxes, penalties, interest or other expenses that may be incurred by Employee on account of non-compliance with Section 409A.

15.This Agreement may not be changed, amended, or modified except by a written instrument signed by both parties.

16.This Agreement shall be binding upon and inure to the benefit of the successors and assigns of the Company.

17.This Agreement sets forth the entire agreement between the parties with respect to the subject matter hereof and fully supersedes any and all prior agreements or understandings between the parties relating to the same. Employee acknowledges and agrees that Employee shall continue to remain bound by, and hereby reaffirms, any and all obligations and restrictive covenants, including all cooperation, confidentiality, intellectual property, noncompetition, nonsolicitation, and nondisparagement obligations that Employee owes to the Company or the other Releasees including, for the avoidance of doubt, obligations Employee owes as provided in this Agreement. Employee specifically acknowledges and agrees that notwithstanding any discussions or negotiations Employee may have had with any of the Releasees prior to the execution of this Agreement, Employee is not relying on any promises or assurances other than those explicitly contained in this Agreement.

18.Each of the Releasees shall be a third party beneficiary of this Agreement and entitled to enforce it in accordance with its terms. PDF or other electronic copies of this Agreement shall have the same force and effect as the original. This Agreement may be executed in counterparts and each shall be considered to be an original and all of which taken together will constitute one and the same agreement.

19.This Agreement shall be governed by and construed in accordance with the laws of the Commonwealth of Pennsylvania without regard to conflict of law principles. The Company and Employee expressly consent to the jurisdiction of Pennsylvania’s state and/or federal courts and agree such courts are the proper venue for any dispute over this Agreement. EACH PARTY AGREES THAT THEY WAIVE THEIR RESPECTIVE RIGHTS TO TRIAL BY JURY OF ANY CLAIMS OR CAUSES OF ACTION ARISING UNDER THIS AGREEMENT AND ALL SUCH CLAIMS OR CAUSES OF ACTION SHALL BE DETERMINED BY A JUDGE SITTING WITHOUT A JURY.

20.The provisions of this Agreement are severable. To the extent that any provision of this Agreement is deemed unenforceable in any court of law, the parties intend that such provision be construed by such court in a manner to make it enforceable, and the remaining provisions of this Agreement shall remain in full force and effect.

[Remainder of Page Intentionally Left Blank; Signature Page Follows]

EMPLOYEE’S ASSURANCES TO THE COMPANY

This Agreement is a legal document with legal consequences. The Company wants to be certain that Employee fully understands the legal effect of signing this Agreement. Employee, therefore, makes the following assurances to the Company:

(1) I have carefully read the complete Agreement.

(2) The Agreement is written in language that I understand.

(3) I understand all of the provisions of this Agreement.

(4) I understand that this Agreement is a waiver of any and all claims set forth in the Agreement that I may have against the Company and all the other Releasees.

(5) I understand that this Agreement, and payments made or to be made to me in connection with my termination, including payments under any short-term incentive plan and awards made pursuant to the Company Equity Plan (as defined in the Merger Agreement) in accordance with the Merger Agreement, together are in full satisfaction, and/or replace all, of the Company’s obligations under the Severance Agreement.

(6) I willingly waive any and all claims set forth in the Agreement, in exchange for the promises of the Company in this Agreement, which I acknowledge constitute valuable consideration that I am not otherwise entitled to receive. I understand that I am not releasing any claims that arise after I sign this Agreement.

(7) I enter this Agreement freely and voluntarily. I am under no coercion or duress whatsoever in considering or agreeing to the provisions of this Agreement.

(8) I understand that this Agreement is a contract. As such, I understand that either party may enforce it.

IN WITNESS WHEREOF, the aforesaid parties, intending to be legally bound hereby, have caused this Agreement to be executed on the dates set forth below.

EQT CORPORATION:

By: /s/ Lesley Evancho Date: 08/14/2024

EMPLOYEE:

By: /s/ Thomas Karam Date: 08/14/2024

Thomas Karam

EXHIBIT A

OWBPA DISCLOSURE

[***]

A-1

ATTACHMENT A

MEDICARE INFORMATION AND AUTHORIZATION FORM

The Center for Medicare & Medicaid Services (CMS) is the federal agency that oversees the Medicare program. In certain situations, Medicare may make a “conditional payment” so as not to inconvenience the beneficiary, and seek to recover the payments later. When an individual receives severance or other payments in exchange for a release of claims, Section 111 of the Medicare, Medicaid and SCHIP Extension Act (MMSEA), requires the Company to determine whether the individual is a Medicare Beneficiary and, if so, to report the severance or other payment and related information.

Please review this picture of the Medicare card to determine if you have, or have ever had, a similar Medicare card and complete Sections I and II of this Form.

Medicare card:

Section I

Are you presently, or have you ever been, enrolled in
Medicare Part A or Part B?

□ Yes

□ No

Full Name:
(Please print the name exactly as it appears on your SSN or Medicare card if available.)

Medicare Claim #:

Date of Birth:
(Month/Day/Year)

‒

Social Security Number:
(If Medicare Claim Number is Unavailable)

Sex:

□ Female

□ Male

Section II

I authorize [COMPANY NAME] (“COMPANY”) and/or COMPANY’s insurers/agents to run a query with CMS to determine my Medicare eligibility and enrollment status (i.e. whether I am a Medicare Beneficiary). If CMS identifies me as a Medicare Beneficiary, I further authorize COMPANY and/or COMPANY’s insurers/agents to take all necessary steps to report any required information in connection with any severance or other payments I will receive in exchange for a release of claims. I understand that the information requested is to enable COMPANY and/or COMPANY’s insurers/agents to meet any mandatory reporting obligations under Medicare law. The information provided for confirmation of my Medicare status, including my name, gender, date of birth, and Social Security Number, is complete, accurate, and current.


Name (Please Print)
Signature						Date
If you have completed Sections I and II above, stop here and submit this form to COMPANY. If you are refusing to provide the information requested in Sections I and II, proceed to Section III.

Section III


Name (Please Print)
For the reason(s) listed below, I have not provided the information requested. I understand that if I am a Medicare Beneficiary and I do not provide the requested information, I may be violating obligations to assist Medicare in coordinating benefits to pay my claims correctly and promptly.

Reason(s) For Refusal To Provide Requested Information:


Signature of Person/Guardian Completing Section III						Date

EQT Medical Spending Account Plan for Eligible Retirees

Dear Thomas Karam:

Upon your termination of service with EQT and based on your age and service, you will become eligible for an employer contribution to your Medical Spending Account Plan for Eligible Retirees (“MSA”). Your eligibility has been confirmed based on your age being 55 or greater and having at least five years of service upon your termination. The amount of the contribution that EQT will provide is determined by your length of service using your Equitrans service date, as required in connection with EQT’s acquisition of Equitrans. Under the EQT MSA, you are entitled to $1,000 for each full year of service.

Based on your service date, we have determined that you have five full years of service entitling you to a contribution of $5,000 from EQT.

You will receive further communication from the EQT Benefit Solutions Center within the next two weeks, informing you of the steps necessary to establish, access and utilize your MSA.

The MSA is provided at no cost to you. You may be reimbursed from your MSA for your cost of healthcare coverage that you buy on an after-tax basis and/or for eligible health expenses that are not covered by another source.

Enrollment Tips

These Enrollment Tips provide the information you need to understand your options and enroll successfully for Medical/Rx, Dental and Vision coverages. You must enroll in these coverages to be eligible for Cobra benefits, and you will only be eligible for Cobra continuation for the coverages and tiers that you choose during this enrollment. For example, if you do not enroll in Vision coverage, you will not be eligible for Cobra Vision benefits; if you enroll for the Employee Only coverage tier, you will not be able to add dependents upon your enrollment for Cobra.

You have 31 days to finalize your enrollment, but to avoid delays in coverage, please complete your enrollment as soon as possible. Upon completion of your enrollment, your information will be provided to EQT’s Cobra administrator, and you will receive your Cobra enrollment information. If you do not submit your enrollment within 31 days, you will not be eligible to enroll in EQT’s Cobra benefits.

If you have questions about your options or enrolling, call the EQT Benefit Solutions Center at 1-888-246-2449 (8 A.M. to 6 P.M. ET, Monday-Friday).

What You Need to Do Enroll—Review these Enrollment Tips and use the EQT Total Rewards portal eqtbenefitsolutions.com to enroll.

Health Savings Account (HSA)—If you currently have a Health Savings Account, you may continue to make post-tax contributions directly if you are enrolled in a qualified HDHP.

Note: You will continue to use your current Fidelity NetBenefits login information for the HSA.

Enroll Online

We recommend following the steps in the order shown:

1.Login—Go to the Total Rewards portal (eqtbenefitsolutions.com)

•User ID—6-digit EQT employee ID number. If a former EQT employee, use previous EQT ID number

•Password—Month/day of birth and last four digits of Social Security number (mmdd1234)

2.Start Enrollment—Click Enrollments under Quick Links and follow the prompts.

3.Review Profile—If any personal information is incorrect, contact the EQT Benefit Solutions Center.

4.Add Dependents—Complete the information requested if you wish to cover dependents.

5.Tobacco User Status—The Smoker Surcharge will not apply to Cobra premiums. Please select “No” to the question “Do you or your spouse smoke?”

Equitrans Midstream—EQT 1 7/2024

6.Medical—You may waive EQT Medical coverage if you have other coverage—or you may elect coverage for you and your eligible dependents. (see the included summaries for details)

7.Health Savings Account (HSA)—If you currently have a HSA, you may make post-tax contributions while covered under a qualified HDHP. These contributions can be made directly from you to your HSA administrator. Please elect $0 contribution on this screen. EQT will not make HSA contributions on your behalf.

8.MetLife Dental and EyeMed Vision—Coverage is optional. There are two Dental options: the Basic Plan and the Enhanced Plan. (see the included summaries for details)

9.MetLife Long-Term Disability (LTD)—LTD benefits are not applicable. Please click “Next”.

10.MetLife Basic Life/AD&D—Basic Life/AD&D benefits are not applicable. Please click “Next”.

11.MetLife Contributory Life/AD&D—Contributory Life/AD&D benefits are not applicable. Please select “Waive Coverage” and click “Next”.

12.Spouse and Child Life Insurance—Please select “Waive Coverage” and click “Next” on the Spouse Life and Child Life screens.

13.Business Travel Accident—BTA benefit is not applicable. Please click “Next”.

14.EAP – EAP benefit not applicable. Please click “Next”.

15.Review Your Elections—Review the information shown and change/correct if needed.

16.Review Beneficiaries—Any dependents you entered in the Review Dependents step will be available to choose as beneficiaries. You may disregard this step as you will not receive life insurance benefits under the EQT plan.

17.SUBMIT—If you log out before you click Submit, your changes will be saved—but not processed, potentially resulting in coverage delays. Please be sure to hit the “Submit” button to finalize your elections.

18.Confirmation—Review and save your confirmation statement.

Equitrans Midstream—EQT 2 8/2024

EQT Benefit Solutions Center

When you have benefit questions, call the EQT Benefit Solutions Center at 1-888-246-2449 (8 A.M. to 6 P.M. ET, Monday-Friday).

Benefits Summaries

Medical and Prescription Drug Coverage Chart

Highmark Blue Cross Blue Shield

Claims accumulated in this calendar year under your current ETRN coverage will be counted towards meeting the deductible and out-of-pocket maximum under the EQT plan.

Equitrans Midstream—EQT 3 8/2024

Dental Coverage Chart

MetLife

Claims accumulated in this calendar year under your current ETRN coverage will be counted towards your deductible and plan maximums under the EQT plan.

Equitrans Midstream—EQT 4 8/2024

Vision Plan Coverage Chart

MetLife

Resources for benefit questions


Tom Torchia Director, Total Rewards [***]	Christian Jones Lead Compensation & Benefits Analyst [***]	Kathleen Curran Payroll & Benefits Analyst [***]
EQT Benefit Solutions Center 1-888-246-2449 From 8 a.m. to 6 p.m. ET Monday-Friday

Equitrans Midstream—EQT 5 8/2024

Offboarding – Frequently Asked Questions

Final Pay

When and how will I receive my final pay?

Your final paycheck will be direct deposited in your account(s) on record. The deposit will occur on the regularly scheduled pay date for the pay period that includes your Date of Termination—08/14/2024.

What deductions will be withheld from my final pay?

All applicable income tax withholdings.

Paystubs & Annual Statements

Where can I obtain statements after my last day of employment?

You can access your paystubs and annual statements for three years prior in MyADP. To access MyADP, you will need:

1.Direct website https://my.adp.com.

2.Use the same ADP log in credentials that you used while employed with EQT. Ex. first initial and last name@eqt. (jdoe@eqt)

3.You will have the capability to reset your password from the log in page, if needed.

Payroll Contact Information

Who can I contact with any payroll related questions after my last day of employment?

You can reach out to the payroll department with any payroll related questions via email at payroll@eqt.com.

Exhibit 31.01

CERTIFICATION

I, Toby Z. Rice, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of EQT Corporation (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditor and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


Date:	October 30, 2024

		/s/ Toby Z. Rice
		Toby Z. Rice
		President and Chief Executive Officer

Exhibit 31.02

CERTIFICATION

I, Jeremy T. Knop, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of EQT Corporation (the "registrant");

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


Date:	October 30, 2024

		/s/ Jeremy T. Knop
		Jeremy T. Knop
		Chief Financial Officer

Exhibit 32

CERTIFICATION

In connection with the Quarterly Report of EQT Corporation ("EQT") on Form 10-Q for the period ended September 30, 2024, as filed with the Securities and Exchange Commission on the date hereof (the "Report"), each of the undersigned certify pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to their knowledge:

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

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


/s/ Toby Z. Rice						October 30, 2024
Toby Z. Rice
President and Chief Executive Officer


/s/ Jeremy T. Knop						October 30, 2024
Jeremy T. Knop
Chief Financial Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signatures that appear in typed form within the electronic version of this written statement required by Section 906, has been provided to EQT and will be retained by EQT and furnished to the Securities and Exchange Commission or its staff upon request.

v3.24.3

Cover - shares
shares in Thousands
9 Months Ended

Sep. 30, 2024

Oct. 25, 2024

Cover [Abstract]

Document Type 10-Q

Document Quarterly Report true

Document Period End Date Sep. 30, 2024

Document Transition Report false

Entity File Number 001-03551

Entity Registrant Name EQT CORPORATION

Entity Incorporation, State or Country Code PA

Entity Tax Identification Number 25-0464690

Entity Address, Street 625 Liberty Avenue

Entity Address, Suite Suite 1700

Entity Address, City or Town Pittsburgh

Entity Address, State or Province PA

Entity Address, Postal Zip Code 15222

City Area Code 412

Local Phone Number 553-5700

Title of 12(b) Security Common Stock, no par value

Trading Symbol EQT

Security Exchange Name NYSE

Entity Current Reporting Status Yes

Entity Interactive Data Current Yes

Entity Filer Category Large Accelerated Filer

Entity Small Business false

Entity Emerging Growth false

Entity Shell Company false

Entity Common Stock, Shares Outstanding 596,684

Entity Central Index Key 0000033213

Current Fiscal Year End Date --12-31

Document Fiscal Year Focus 2024

Document Fiscal Period Focus Q3

Amendment Flag false

v3.24.3

STATEMENTS OF CONDENSED CONSOLIDATED OPERATIONS (UNAUDITED) - USD ($)
shares in Thousands, $ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Operating revenues:

Gain on derivatives $ 66,816 $ 177,906 $ 234,660 $ 1,167,144

Total operating revenues 1,283,802 1,186,102 3,648,582 4,865,924

Operating expenses:

Transportation and processing 440,845 554,788 1,529,093 1,592,934

Production 93,842 62,858 273,042 163,963

Operating and maintenance 40,518 4,235 65,824 6,108

Exploration 282 447 2,576 2,602

Selling, general and administrative 88,470 56,942 228,730 168,999

Depreciation, depletion and amortization 589,299 446,886 1,542,031 1,230,255

Loss (gain) on sale/exchange of long-lived assets 10,117 1,511 (309,865) 17,814

Impairment and expiration of leases 12,095 6,419 58,963 22,290

Other operating expenses 290,174 36,209 354,337 69,265

Total operating expenses 1,565,642 1,170,295 3,744,731 3,274,230

Operating (loss) income (281,840) 15,807 (96,149) 1,591,694

(Income) loss from investments (34,242) 546 (36,674) (5,310)

Other income (3,960) (132) (23,596) (869)

Loss (gain) on debt extinguishment 365 1,089 5,651 (55)

Interest expense, net 158,299 60,427 268,390 146,856

(Loss) income before income taxes (402,302) (46,123) (309,920) 1,451,072

Income tax (benefit) expense (104,870) (126,853) (124,790) 217,975

Net (loss) income (297,432) 80,730 (185,130) 1,233,097

Less: Net income (loss) attributable to noncontrolling interests 3,391 (525) 2,688 (80)

Net (loss) income attributable to EQT Corporation $ (300,823) $ 81,255 $ (187,818) $ 1,233,177

(Loss) income per share of common stock attributable to EQT Corporation:

Weighted average common stock outstanding - Basic (in shares) 559,603 383,359 480,354 368,936

Net (loss) income attributable to EQT Corporation - Basic (in dollars per share) $ (0.54) $ 0.21 $ (0.39) $ 3.34

Weighted average common stock outstanding - Diluted (in shares) 559,603 416,190 480,354 401,859

Net (loss) income attributable to EQT Corporation - Diluted (in dollars per share) $ (0.54) $ 0.20 $ (0.39) $ 3.08

Sales of natural gas, NGLs and oil

Operating revenues:

Sales of natural gas, natural gas liquids and oil $ 1,099,752 $ 1,001,883 $ 3,293,174 $ 3,680,566

Pipeline, net marketing services and other

Operating revenues:

Pipeline, net marketing services and other $ 117,234 $ 6,313 $ 120,748 $ 18,214

v3.24.3

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE (LOSS) INCOME (UNAUDITED) - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Statement of Comprehensive Income [Abstract]

Net (loss) income $ (297,432) $ 80,730 $ (185,130) $ 1,233,097

Other comprehensive income, net of tax:

Other postretirement benefits liability adjustment, net of tax: $13, $15, $39 and $44 28 57 114 270

Comprehensive (loss) income (297,404) 80,787 (185,016) 1,233,367

Less: Comprehensive income (loss) attributable to noncontrolling interests 3,391 (525) 2,688 (80)

Comprehensive (loss) income attributable to EQT Corporation $ (300,795) $ 81,312 $ (187,704) $ 1,233,447

v3.24.3

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Statement of Comprehensive Income [Abstract]

Other post-retirement benefits liability adjustment, tax expense $ 13 $ 15 $ 39 $ 44

v3.24.3

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($)
$ in Thousands

Sep. 30, 2024

Dec. 31, 2023

Current assets:

Cash and cash equivalents $ 88,980 $ 80,977

Accounts receivable (less provision for doubtful accounts: $9,135 and $663) 577,599 823,695

Derivative instruments, at fair value 251,657 978,634

Income tax receivable 92,791 91,414

Prepaid expenses and other 71,265 38,255

Total current assets 1,082,292 2,012,975

Property, plant and equipment 44,884,752 33,817,169

Less: Accumulated depreciation and depletion 12,338,210 10,866,999

Net property, plant and equipment 32,546,542 22,950,170

Investment in the MVP Joint Venture 3,358,346 0

Net intangible assets 268,308 22,595

Goodwill 2,178,236 0

Other assets 511,865 299,358

Total assets 39,945,589 25,285,098

Current liabilities:

Current portion of debt 400,150 292,432

Accounts payable 1,042,393 1,272,522

Derivative instruments, at fair value 197,712 186,363

Accrued interest 189,965 80,520

Other current liabilities 283,730 205,003

Total current liabilities 2,113,950 2,036,840

Revolving credit facility borrowings 2,297,000 0

Term Loan Facility borrowings 497,970 1,244,265

Senior notes 10,598,428 4,176,180

Note payable to EQM Midstream Partners, LP 0 82,236

Deferred income taxes 2,746,292 1,904,821

Other liabilities and credits 1,203,631 1,059,939

Total liabilities 19,457,271 10,504,281

Equity:

Common stock, no par value, shares authorized: 1,280,000 and 640,000, shares issued: 596,268 and 419,896 18,076,243 12,093,986

Retained earnings 2,261,086 2,681,898

Accumulated other comprehensive loss (2,570) (2,684)

Total common shareholders' equity 20,334,759 14,773,200

Noncontrolling interest in consolidated subsidiaries 153,559 7,617

Total equity 20,488,318 14,780,817

Total liabilities and equity $ 39,945,589 $ 25,285,098

v3.24.3

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - USD ($)
$ in Thousands

Sep. 30, 2024

Dec. 31, 2023

Statement of Financial Position [Abstract]

Provision for doubtful accounts $ 9,135 $ 663

Common stock, par value (in dollars per share) $ 0 $ 0

Common stock, authorized shares (in shares) 1,280,000,000 640,000,000

Common stock, shares issued (in shares) 596,268,000 419,896,000

v3.24.3

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED) - USD ($)
$ in Thousands
9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Cash flows from operating activities:

Net (loss) income $ (185,130) $ 1,233,097

Adjustments to reconcile net (loss) income to net cash provided by operating activities:

Deferred income tax (benefit) expense (123,725) 227,701

Depreciation, depletion and amortization 1,542,031 1,230,255

Gain/loss on sale/exchange of long-lived assets and impairments (250,902) 40,104

Income from investments (36,674) (5,310)

Loss (gain) on debt extinguishment 5,651 (55)

Share-based compensation expense 141,578 38,179

Distributions from equity method investments 11,187 18,073

Other 13,160 12,022

Gain on derivatives (234,660) (1,167,144)

Net cash settlements received on derivatives 1,037,321 625,051

Net premiums paid on derivatives (41,970) (231,343)

Changes in other assets and liabilities:

Accounts receivable 331,452 1,122,843

Accounts payable (122,252) (515,879)

Other current assets (10,150) 91,946

Other items, net (6,220) (165,076)

Net cash provided by operating activities 2,070,697 2,554,464

Cash flows from investing activities:

Capital expenditures (1,662,112) (1,485,898)

Cash paid for acquisitions (864,242) (2,288,201)

Proceeds from sale/exchange of assets 451,906 4,831

Capital contributions to equity method investments (87,804) (5,000)

Other investing activities (80) 159

Net cash used in investing activities (2,162,332) (3,774,109)

Cash flows from financing activities:

Proceeds from revolving credit facility borrowings 3,578,000 313,000

Repayment of revolving credit facility borrowings (2,316,000) (313,000)

Proceeds from issuance of debt 750,000 1,250,000

Proceeds from net settlement of capped call transactions 93,290 0

Debt issuance costs (18,854) (5,336)

Repayment and retirement of debt (1,655,706) (1,014,346)

(Premiums paid) discounts received on debt extinguishment (1,543) 5,313

Dividends paid (232,603) (162,567)

Repurchase and retirement of common stock 0 (201,029)

Net distribution to noncontrolling interest (1,640) (7,322)

Cash paid for taxes to net settle share-based incentive awards (92,492) (41,238)

Other financing activities (2,814) 2,276

Net cash provided by (used in) financing activities 99,638 (174,249)

Net change in cash and cash equivalents 8,003 (1,393,894)

Cash and cash equivalents at beginning of period 80,977 1,458,644

Cash and cash equivalents at end of period $ 88,980 $ 64,750

v3.24.3

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED) - USD ($)
shares in Thousands, $ in Thousands

Total

Common Stock

Retained Earnings

Accumulated Other Comprehensive Loss

Noncontrolling Interest in Consolidated Subsidiaries

Beginning balance (in shares) at Dec. 31, 2022 365,363

Beginning balance at Dec. 31, 2022 $ 11,213,328 $ 9,891,890 $ 1,283,578 $ (2,994) ^[1] $ 40,854

Comprehensive income (loss), net of tax

Net (loss) income 1,233,097 1,233,177 (80)

Other post-retirement benefits liability adjustment, net of tax 270 270 ^[1]

Dividends (162,567) (162,567)

Share-based compensation plans (in shares) 2,247

Share-based compensation plans 5,367 $ 5,367

Convertible Notes settlements (in shares) 7

Convertible Notes settlements 98 $ 98

Repurchase and retirement of common stock (in shares) (5,906)

Repurchase and retirement of common stock (201,029) $ (91,545) (109,484)

Acquisitions and Merger (in shares) 49,600

Acquisition and Merger 2,152,631 $ 2,152,631

Distribution to noncontrolling interest (11,072) (11,072)

Contribution from noncontrolling interest 3,750 3,750

Dissolution of consolidated variable interest entity (25,227) (25,227)

Other 911 911

Ending balance (in shares) at Sep. 30, 2023 411,311

Ending balance at Sep. 30, 2023 14,209,557 $ 11,958,441 2,245,615 (2,724) ^[1] 8,225

Beginning balance (in shares) at Jun. 30, 2023 361,654

Beginning balance at Jun. 30, 2023 12,045,028 $ 9,790,855 2,217,698 (2,781) ^[2] 39,256

Comprehensive income (loss), net of tax

Net (loss) income 80,730 81,255 (525)

Other post-retirement benefits liability adjustment, net of tax 57 57 ^[2]

Dividends (54,249) (54,249)

Share-based compensation plans (in shares) 56

Share-based compensation plans 14,939 $ 14,939

Convertible Notes settlements (in shares) 1

Convertible Notes settlements 16 $ 16

Acquisitions and Merger (in shares) 49,600

Acquisition and Merger 2,152,631 $ 2,152,631

Distribution to noncontrolling interest (5,279) (5,279)

Dissolution of consolidated variable interest entity (25,227) (25,227)

Other 911 911

Ending balance (in shares) at Sep. 30, 2023 411,311

Ending balance at Sep. 30, 2023 14,209,557 $ 11,958,441 2,245,615 (2,724) ^[1] 8,225

Beginning balance (in shares) at Dec. 31, 2023 419,896

Beginning balance at Dec. 31, 2023 14,780,817 $ 12,093,986 2,681,898 (2,684) ^[1] 7,617

Comprehensive income (loss), net of tax

Net (loss) income (185,130) (187,818) 2,688

Other post-retirement benefits liability adjustment, net of tax 114 114 ^[1]

Dividends (232,994) (232,994)

Share-based compensation plans (in shares) 3,952

Share-based compensation plans 54,751 $ 54,751

Convertible Notes settlements (in shares) 19,992

Convertible Notes settlements 285,608 $ 285,608

Acquisitions and Merger (in shares) 152,428

Acquisition and Merger 5,693,502 $ 5,548,608 144,894

Net settlement of Capped Call Transactions 93,290 $ 93,290

Distribution to noncontrolling interest (1,640) (1,640)

Ending balance (in shares) at Sep. 30, 2024 596,268

Ending balance at Sep. 30, 2024 20,488,318 $ 18,076,243 2,261,086 (2,570) ^[2] 153,559

Beginning balance (in shares) at Jun. 30, 2024 441,597

Beginning balance at Jun. 30, 2024 15,124,748 $ 12,464,492 2,655,940 (2,598) ^[2] 6,914

Comprehensive income (loss), net of tax

Net (loss) income (297,432) (300,823) 3,391

Other post-retirement benefits liability adjustment, net of tax 28 28 ^[2]

Dividends (94,031) (94,031)

Share-based compensation plans (in shares) 2,243

Share-based compensation plans 63,143 $ 63,143

Acquisitions and Merger (in shares) 152,428

Acquisition and Merger 5,693,502 $ 5,548,608 144,894

Distribution to noncontrolling interest (1,640) (1,640)

Ending balance (in shares) at Sep. 30, 2024 596,268

Ending balance at Sep. 30, 2024 $ 20,488,318 $ 18,076,243 $ 2,261,086 $ (2,570) ^[2] $ 153,559

[1] Amounts included in accumulated other comprehensive loss are related to other postretirement benefits liability adjustments, net of tax, which are attributable to net actuarial losses and net prior service costs.

[2] Amounts included in accumulated other comprehensive loss are related to other postretirement benefits liability adjustments, net of tax, which are attributable to net actuarial losses and net prior service costs.

v3.24.3

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED) (Parenthetical) - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Statement of Stockholders' Equity [Abstract]

Other post-retirement benefits liability adjustment, net of tax $ 13 $ 15 $ 39 $ 44

Dividends (in dollars per share) $ 0.1575 $ 0.15 $ 0.4725 $ 0.45

Common stock, authorized shares (in shares) 1,280,000,000 640,000,000 1,280,000,000 640,000,000

Preferred stock authorized (in shares) 3,000,000 3,000,000 3,000,000 3,000,000

Preferred stock issued (in shares) 0 0 0 0

Preferred stock outstanding (in shares) 0 0 0 0

v3.24.3

Financial Statements
9 Months Ended

Sep. 30, 2024

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Financial Statements Financial Statements

Nature of Operations. EQT Corporation is an integrated natural gas production, gathering and transmission company with operations focused in the Appalachian Basin.

In this Quarterly Report on Form 10-Q, references to "EQT" refer to EQT Corporation and references to the "Company" refer collectively to EQT Corporation and its consolidated subsidiaries in each case unless otherwise noted or indicated.

Basis of Presentation. The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all information and notes required by GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of the Company as of September 30, 2024 and December 31, 2023, the results of its operations and equity for the three and nine month periods ended September 30, 2024 and 2023 and its cash flows for the nine month periods ended September 30, 2024 and 2023. Certain previously reported amounts have been reclassified to conform to the current period presentation. In addition, as discussed further in Note 2, certain prior period amounts have been recast to reflect the Company's change in reportable segments from one reportable segment to three reportable segments consisting of Production, Gathering and Transmission.

The Condensed Consolidated Balance Sheet at December 31, 2023 has been derived from the audited financial statements at that date. For further information, refer to the Consolidated Financial Statements and accompanying notes in the Company's Annual Report on Form 10-K for the year ended December 31, 2023.

Principles of Consolidation. The Condensed Consolidated Financial Statements include the accounts of EQT and all subsidiaries, ventures and partnerships in which EQT directly or indirectly holds a controlling interest. Intercompany accounts and transactions have been eliminated in consolidation.

Upon the closing of the Equitrans Midstream Merger (defined in Note 12), the Company acquired a controlling 60% interest in Eureka Midstream Holdings, LLC (Eureka Midstream Holdings) and an equity method investment in Mountain Valley Pipeline, LLC (the MVP Joint Venture).

Eureka Midstream Holdings is a joint venture that owns a gathering header pipeline system that is operated by a subsidiary of EQT. Because the Company is the primary beneficiary of Eureka Midstream Holdings, the Company consolidates Eureka Midstream Holdings and records noncontrolling interest in its Condensed Consolidated Financial Statements. See Note 7 for discussion of the revolving credit facility of Eureka Midstream, LLC (Eureka), a wholly-owned subsidiary of Eureka Midstream Holdings.

The MVP Joint Venture is a joint venture formed among a subsidiary of EQT and, as applicable, affiliates of each of NextEra Energy, Inc., Consolidated Edison, Inc., AltaGas Ltd. and RGC Resources, Inc. for purposes of constructing and operating the Mountain Valley Pipeline (the MVP) and the MVP Southgate project (MVP Southgate). See Note 8 for further discussion of the MVP Joint Venture, the MVP and MVP Southgate. Because the Company has the ability to exercise significant influence over the MVP Joint Venture but does not have the power to direct the activities that most significantly affect the MVP Joint Venture's economic performance, the Company applies the equity method of accounting to the MVP Joint Venture.
Supplemental Cash Flow Information. The following table summarizes net cash paid for interest and income taxes and non-cash activity included in the Statements of Condensed Consolidated Cash Flows.
Nine Months Ended September 30,
2024 2023
(Thousands)
Cash paid during the period for:
Interest, net of amount capitalized $ 196,632 $ 145,787
Income taxes, net 4,850 13,441
Non-cash activity during the period for:
Equity issued as consideration for acquisition (Notes 12 and 11)
$ 5,548,608 $ 2,152,631
Issuance of EQT common stock for Convertible Notes settlement (Note 7)
285,608 98
NEPA Non-Operated Asset Divestiture (Note 11)
155,241 —
Increase in right-of-use assets and lease liabilities, net 11,501 25,849
Increase in asset retirement costs and obligations 7,947 5,216
Capitalization of non-cash equity share-based compensation 5,273 4,587
Investments in nonconsolidated entities 17,598 —
Dissolution of consolidated variable interest entity — 25,227

Common Stock. On July 18, 2024, following approval by its shareholders, EQT amended its Restated Articles of Incorporation to increase the authorized number of shares of EQT common stock from 640,000,000 shares to 1,280,000,000 shares.

Recently Issued Accounting Standards

In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures to improve reportable segment disclosure requirements, primarily through the requirement of enhanced disclosure of significant segment expenses. In addition, this ASU enhances interim disclosure requirements, clarifies circumstances in which an entity can disclose multiple segment measures of profit or loss and provides new segment disclosure requirements for entities with a single reportable segment. This ASU is effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-07 to have a material impact on its currently-presented financial statements and related disclosures.

In December 2023, the FASB issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures to improve its income tax disclosure requirements. Under this ASU, public business entities must annually (1) disclose specific categories in the rate reconciliation and (2) provide additional information for reconciling items that meet a quantitative threshold. This ASU is effective for fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-09 to have a material impact on its financial statements and related disclosures.

v3.24.3

Financial Information by Business Segment
9 Months Ended

Sep. 30, 2024

Segment Reporting [Abstract]

Financial Information by Business Segment Financial Information by Business Segment
Prior to the completion of the Equitrans Midstream Merger, the Company's operations consisted of one reportable segment. Historically, the Company administered all properties as a whole rather than by discrete operating segments and measured financial performance as a single enterprise and not on an area-by-area basis.

As a result of the completion of the Equitrans Midstream Merger, the Company adjusted its internal reporting structure and the Company's chief operating decision maker changed the manner in which he allocates resources and measures financial performance to incorporate the gathering and transmission assets acquired by the Company in the Equitrans Midstream Merger. Hence, the Company's operations expanded to comprise three discrete operating segments reflective of its three lines of business consisting of Production, Gathering and Transmission. Accordingly, the manner in which the Company reports its operations has been changed retrospectively, with certain prior period amounts recast between Production and Gathering.
Certain amounts, including cash and cash equivalents, debt, income taxes and other amounts related to the Company's headquarters function as well as amounts related to the Company's energy transition initiatives, are managed on a consolidated basis and, as such, have not been allocated to the Company's reportable segments and are presented as "Other" along with intersegment eliminations. Water assets acquired in the Equitrans Midstream Merger primarily support the Company's production operations and, as such, have been included in the Company's Production segment.

Substantially all of the Company's operating revenues and assets are generated and located in the United States.

Profit and loss metric with reconciliation to net (loss) income attributable to EQT Corporation for the three months ended September 30, 2024
Production Gathering Transmission Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 1,099,752 $ — $ — $ — $ 1,099,752
Gain (loss) on derivatives 72,489 (5,673) — — 66,816
Pipeline, net marketing services and other 5,826 276,829 87,384 (252,805) 117,234
Total operating revenues 1,178,067 271,156 87,384 (252,805) 1,283,802
Operating expenses:
Transportation and processing 693,670 — — (252,825) 440,845
Production 93,842 — — — 93,842
Operating and maintenance — 30,712 9,806 — 40,518
Exploration 282 — — — 282
Selling, general and administrative (a) 62,952 11,366 5,492 8,660 88,470
Depreciation, depletion and amortization 530,745 37,773 17,109 3,672 589,299
Loss on sale/exchange of long-lived assets 9,708 — 409 — 10,117
Impairment and expiration of leases 12,095 — — — 12,095
Other operating expenses (b) 10,206 — — 279,968 290,174
Total operating expenses 1,413,500 79,851 32,816 39,475 1,565,642
Operating (loss) income $ (235,433) $ 191,305 $ 54,568 $ (292,280) $ (281,840)
Reconciliation of profit and loss metric to net (loss) income attributable to EQT Corporation
Loss (income) from investments $ 1,671 $ (597) $ (35,616) $ 300 $ (34,242)
Other income (3,488) (128) (75) (269) (3,960)
Loss on debt extinguishment — — — 365 365
Interest expense, net — — — 158,299 158,299
(Loss) income before income taxes (233,616) 192,030 90,259 (450,975) (402,302)
Income tax benefit — — — (104,870) (104,870)
Net (loss) income (233,616) 192,030 90,259 (346,105) (297,432)
Less: Net income (loss) attributable to noncontrolling interests — 3,687 — (296) 3,391
Net (loss) income attributable to EQT Corporation $ (233,616) $ 188,343 $ 90,259 $ (345,809) $ (300,823)
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Equitrans Midstream Merger. See Note 12.
Profit and loss metric with reconciliation to net income attributable to EQT Corporation for the three months ended September 30, 2023
Production Gathering Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 1,001,883 $ — $ — $ 1,001,883
Gain on derivatives 177,906 — — 177,906
Pipeline, net marketing services and other 3,456 42,057 (39,200) 6,313
Total operating revenues 1,183,245 42,057 (39,200) 1,186,102
Operating expenses:
Transportation and processing 593,988 — (39,200) 554,788
Production 62,858 — — 62,858
Operating and maintenance — 4,235 — 4,235
Exploration 447 — — 447
Selling, general and administrative (a) 56,942 — — 56,942
Depreciation, depletion and amortization 440,360 4,054 2,472 446,886
Loss on sale/exchange of long-lived assets 1,511 — — 1,511
Impairment and expiration of leases 6,419 — — 6,419
Other operating expenses (b) (621) — 36,830 36,209
Total operating expenses 1,161,904 8,289 102 1,170,295
Operating income (loss) $ 21,341 $ 33,768 $ (39,302) $ 15,807
Reconciliation of profit and loss metric to net income attributable to EQT Corporation
Loss (income) from investments $ 424 $ (255) $ 377 $ 546
Other income — — (132) (132)
Loss on debt extinguishment — — 1,089 1,089
Interest expense, net — — 60,427 60,427
Income (loss) before income taxes 20,917 34,023 (101,063) (46,123)
Income tax benefit — — (126,853) (126,853)
Net income 20,917 34,023 25,790 80,730
Less: Net income (loss) attributable to noncontrolling interests 149 — (674) (525)
Net income attributable to EQT Corporation $ 20,768 $ 34,023 $ 26,464 $ 81,255
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Tug Hill and XcL Midstream Acquisition (defined in Note 11).
Profit and loss metric with reconciliation to net (loss) income attributable to EQT Corporation for the nine months ended September 30, 2024
Production Gathering Transmission Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 3,293,174 $ — $ — $ — $ 3,293,174
Gain (loss) on derivatives 240,333 (5,673) — — 234,660
Pipeline, net marketing services and other 2,757 415,491 87,384 (384,884) 120,748
Total operating revenues 3,536,264 409,818 87,384 (384,884) 3,648,582
Operating expenses:
Transportation and processing 1,914,010 — — (384,917) 1,529,093
Production 273,042 — — — 273,042
Operating and maintenance — 56,018 9,806 — 65,824
Exploration 2,576 — — — 2,576
Selling, general and administrative (a) 180,767 11,366 5,492 31,105 228,730
Depreciation, depletion and amortization 1,470,966 45,282 17,109 8,674 1,542,031
(Gain) loss on sale/exchange of long-lived assets (310,252) (22) 409 — (309,865)
Impairment and expiration of leases 58,963 — — — 58,963
Other operating expenses (b) 23,650 — — 330,687 354,337
Total operating expenses 3,613,722 112,644 32,816 (14,451) 3,744,731
Operating (loss) income $ (77,458) $ 297,174 $ 54,568 $ (370,433) $ (96,149)
Reconciliation of profit and loss metric to net (loss) income attributable to EQT Corporation
(Income) loss from investments $ (371) $ (2,109) $ (35,616) $ 1,422 $ (36,674)
Other income (17,638) (5,153) (75) (730) (23,596)
Loss on debt extinguishment — — — 5,651 5,651
Interest expense, net — — — 268,390 268,390
(Loss) income before income taxes (59,449) 304,436 90,259 (645,166) (309,920)
Income tax benefit — — — (124,790) (124,790)
Net (loss) income (59,449) 304,436 90,259 (520,376) (185,130)
Less: Net income (loss) attributable to noncontrolling interests — 3,687 — (999) 2,688
Net (loss) income attributable to EQT Corporation $ (59,449) $ 300,749 $ 90,259 $ (519,377) $ (187,818)
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Equitrans Midstream Merger. See Note 12.
Profit and loss metric with reconciliation to net income (loss) attributable to EQT Corporation for the nine months ended September 30, 2023
Production Gathering Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 3,680,566 $ — $ — $ 3,680,566
Gain on derivatives 1,167,144 — — 1,167,144
Pipeline, net marketing services and other 9,675 95,753 (87,214) 18,214
Total operating revenues 4,857,385 95,753 (87,214) 4,865,924
Operating expenses:
Transportation and processing 1,680,009 — (87,075) 1,592,934
Production 163,963 — — 163,963
Operating and maintenance — 6,108 — 6,108
Exploration 2,602 — — 2,602
Selling, general and administrative (a) 168,999 — — 168,999
Depreciation, depletion and amortization 1,214,882 8,077 7,296 1,230,255
Loss on sale/exchange of long-lived assets 17,814 — — 17,814
Impairment and expiration of leases 22,290 — — 22,290
Other operating expenses (b) 7,645 — 61,620 69,265
Total operating expenses 3,278,204 14,185 (18,159) 3,274,230
Operating income (loss) $ 1,579,181 $ 81,568 $ (69,055) $ 1,591,694
Reconciliation of profit and loss metric to net income (loss) attributable to EQT Corporation
(Income) loss from investments $ (2,675) $ (4,004) $ 1,369 $ (5,310)
Other income (395) — (474) (869)
Gain on debt extinguishment — — (55) (55)
Interest expense, net — — 146,856 146,856
Income (loss) before income taxes 1,582,251 85,572 (216,751) 1,451,072
Income tax expense — — 217,975 217,975
Net income (loss) 1,582,251 85,572 (434,726) 1,233,097
Less: Net income (loss) attributable to noncontrolling interests 1,588 — (1,668) (80)
Net income (loss) attributable to EQT Corporation $ 1,580,663 $ 85,572 $ (433,058) $ 1,233,177
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Tug Hill and XcL Midstream Acquisition.
Assets by segment as of September 30, 2024
Production Gathering Transmission Other and intersegment eliminations EQT Corporation
(Thousands)
Investment in the MVP Joint Venture $ — $ — $ 3,358,346 $ — $ 3,358,346
Goodwill — — 1,289,759 888,477 2,178,236
Other segment assets (a) 22,890,299 8,187,601 2,962,486 368,621 34,409,007
Total assets $ 22,890,299 $ 8,187,601 $ 7,610,591 $ 1,257,098 $ 39,945,589
(a)Other segment assets in other and intersegment eliminations includes cash and cash equivalents.

Assets by segment as of September 30, 2023
Production Gathering Other and intersegment eliminations EQT Corporation
(Thousands)
Total assets (a) $ 23,138,353 $ 1,167,766 $ 248,869 $ 24,554,988
(a)Total assets in other and intersegment eliminations includes cash and cash equivalents.

The Company did not have an investment in the MVP Joint Venture or goodwill as of September 30, 2023.

Capital expenditures by segment
Three Months Ended September 30, Nine Months Ended
September 30,
2024 2023 2024 2023
(Thousands)
Capital expenditures:
Production (a) $ 454,772 $ 435,646 $ 1,539,904 $ 1,366,669
Gathering (b) 79,597 6,941 111,644 11,521
Transmission 10,118 — 10,118 —
Other 13,402 1,998 21,345 8,546
Total capital expenditures $ 557,889 $ 444,585 $ 1,683,011 $ 1,386,736
(a)Production capital expenditures included capital expenditures attributable to the noncontrolling interest in The Mineral Company LLC (a joint venture formed between a subsidiary of EQT and a third-party investor for the purpose of purchasing certain mineral rights in the Appalachian Basin) of approximately $8.5 million for the nine months ended September 30, 2023. The Mineral Company LLC was dissolved in the third quarter of 2023.
(b)Gathering capital expenditures included capital expenditures attributable to the noncontrolling interest in Eureka Midstream Holdings of approximately $1.6 million for both the three and nine months ended September 30, 2024. See Notes 1 and 12.

Intersegment contracts

On February 26, 2020, EQT and certain of its affiliates (such parties, collectively, the EQT Producer) entered into a gas gathering and compression agreement (the Consolidated GGA) with an affiliate of EQM Midstream Partners, LP (EQM), which became an indirect wholly-owned subsidiary of EQT upon the closing of the Equitrans Midstream Merger. Pursuant to the terms of the Consolidated GGA, among other things, the EQM affiliate agreed to provide gas gathering services to the EQT Producer, and the EQT Producer committed to an initial annual minimum volume commitment (MVC) of 3.0 Bcf per day and an acreage dedication in Pennsylvania and West Virginia. The Consolidated GGA is effective through December 31, 2035 and will renew annually thereafter unless terminated by the parties thereto.
The Consolidated GGA provides for cash bonus payments (the Henry Hub Cash Bonus) payable by the EQT Producer to the EQM affiliate during each quarter beginning with the first day of the quarter in which the MVP In-Service Date (as defined in the Consolidated GGA) occurs and ending on the earlier of 36 months thereafter or December 31, 2024. Such payments are conditioned upon the quarterly average of the NYMEX Henry Hub natural gas settlement price exceeding certain price thresholds. Upon commencement of long-term firm capacity obligations, the MVP In-Service Date occurred on July 1, 2024. See Note 8.

The EQT Producer's derivative liability and any gain or loss realized related to the Henry Hub Cash Bonus are included in the Company's Production segment; the EQM affiliate's derivative asset and any gain or loss realized related to the Henry Hub Cash Bonus are included in the Company's Gathering segment. All balances and gains or losses related to the Henry Hub Cash Bonus have been eliminated in consolidation. As of September 30, 2024 and December 31, 2023, the derivative related to the Henry Hub Cash Bonus had a fair value of approximately $15 million and $48 million, respectively. The fair value of the derivative asset and liability related to the Henry Hub Cash Bonus is based on significant inputs that are interpolated from observable market data and, as such, is a Level 2 fair value measurement. See Note 5 for a description of the fair value hierarchy.

v3.24.3

Revenue from Contracts with Customers
9 Months Ended

Sep. 30, 2024

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers Revenue from Contracts with Customers
Sales of natural gas, NGLs and oil. Under the Company's natural gas, natural gas liquids (NGLs) and oil sales contracts, the Company generally considers the delivery of each unit (million British thermal units (MMBtu) or barrel (Bbl)) to be a separate performance obligation that is satisfied upon delivery. These contracts typically require payment within 25 days of the end of the calendar month in which the commodity is delivered. A significant number of these contracts contain variable consideration because the payment terms refer to market prices at future delivery dates. In these situations, the Company has not identified a standalone selling price because the terms of the variable payments relate specifically to the Company's efforts to satisfy the performance obligations. Other contracts, such as fixed price contracts or contracts with a fixed differential to New York Mercantile Exchange (NYMEX) or index prices, contain fixed consideration. The fixed consideration is allocated to each performance obligation on a relative standalone selling price basis, which requires judgment from management. For these contracts, the Company generally concludes that the fixed price or fixed differentials in the contracts are representative of the standalone selling price.

Based on management's judgment, the performance obligations for the sale of natural gas, NGLs and oil are satisfied at a point in time because the customer obtains control and legal title of the asset when the natural gas, NGLs or oil is delivered to the designated sales point.

The sales of natural gas, NGLs and oil presented in the Statements of Condensed Consolidated Operations represent the Company's share of revenues net of royalties and exclude revenue interests owned by others. When selling natural gas, NGLs and oil on behalf of royalty or working interest owners, the Company acts as an agent and, thus, reports the revenue on a net basis.

Pipeline revenue. The Company recognizes revenue under gathering and transmission and storage contracts when it satisfies certain performance obligations.

The Company provides firm and interruptible gathering and transmission and storage services. Firm service contracts generally require the customer to pay a firm reservation fee, which is a fixed, monthly charge to reserve an agreed upon amount of pipeline or storage capacity regardless of whether the customer uses the capacity. Volumetric-based fees, which are charges based on the volume of gas gathered, transported or stored, can also be charged under firm contracts for each firm contracted volume gathered, transported or stored, as well as for volumes gathered, transported or stored in excess of the firm contracted volume so long as capacity exists. Interruptible service contracts require the customer to pay volumetric-based fees and generally do not guarantee access to the pipeline or storage facility.

Gathering and transmission and storage services contracts can be short-term or long-term in duration. Firm and interruptible gathering service contracts are invoiced on a one-month lag, with payment typically due within 21 days of the invoice date. Revenue for gathering services provided but not yet invoiced is estimated based on contract data, preliminary throughput and allocation measurements on a monthly basis. Firm and interruptible transmission and storage service contracts are invoiced at the end of each calendar month, with payment typically due within 10 days of the invoice date.
Under its firm service contracts, the Company has a stand-ready obligation to provide the firm service over the life of the contract. The performance obligation for revenue from firm reservation fees is satisfied over time as the pipeline capacity is made available to the customer. As such, the Company recognizes firm reservation fee revenue evenly over the contract period using a time-elapsed output method to measure progress. The performance obligation for revenue from volumetric-based fees is generally satisfied upon the Company's monthly invoicing to the customer for volumes gathered, transported or stored during the month. The amount invoiced generally corresponds directly to the value of the Company's performance to date as the customer obtains value as each volume is gathered, transported or stored.

For all of the Company's gathering and transmission and storage services contracts, the Company allocates the transaction price to each performance obligation based on the estimated relative standalone selling price. Any excess of consideration received over revenue recognized results in the deferral of those amounts until future periods based on a units-of-production or straight-line methodology as these methods align with the consumption of services provided to the customer. The units-of-production methodology requires the use of judgment to estimate future production volumes.

Certain of the Company's gathering service agreements are structured with MVCs, which specify minimum quantities that the customer will be charged regardless of whether such quantities are gathered. Revenue is recognized for MVCs when the performance obligation has been met, which is the earlier of when the gas is gathered or when the likelihood that the customer will be able to meet its MVC is remote. If a customer fails to meet its MVC for a specified period (thus not exercising all the contractual rights to gathering services within the specified period), the customer is obligated to pay a contractually-determined fee based on the shortfall between actual volume gathered and the MVC.
Disaggregated revenue information. The table below provides disaggregated information on the Company's revenues. Certain other revenue contracts are outside the scope of ASU 2014-09, Revenue from Contracts with Customers. These contracts are reported in pipeline, net marketing services and other revenues in the Statements of Condensed Consolidated Operations. Derivative contracts are also outside the scope of ASU 2014-09.
Three Months Ended
September 30, Nine Months Ended
September 30,
2024 2023 2024 2023
(Thousands)
Revenues from contracts with customers:
Production:
Sales of natural gas, NGLs and oil
Natural gas sales $ 938,911 $ 859,512 $ 2,791,190 $ 3,337,600
NGLs sales 139,697 108,205 435,581 274,932
Oil sales 21,144 34,166 66,403 68,034
Sales of natural gas, NGLs and oil 1,099,752 1,001,883 3,293,174 3,680,566
Gathering:
Pipeline revenues
Firm reservation fee revenues (a) 136,752 — 136,752 —
Volumetric-based fee revenues 140,077 42,057 278,739 95,753
Total 276,829 42,057 415,491 95,753
Transmission:
Pipeline revenues
Firm reservation fee revenues 73,034 — 73,034 —
Volumetric-based fee revenues 14,226 — 14,226 —
Total 87,260 — 87,260 —
Other and intersegment eliminations (252,805) (39,200) (384,884) (87,214)
Total revenues from contracts with customers $ 1,211,036 $ 1,004,740 $ 3,411,041 $ 3,689,105
Other sources of revenue:
Gain on derivatives $ 66,816 $ 177,906 $ 234,660 $ 1,167,144
Net marketing services and other revenues 5,950 3,456 2,881 9,675
Total other sources of revenue $ 72,766 $ 181,362 $ 237,541 $ 1,176,819
Total operating revenues $ 1,283,802 $ 1,186,102 $ 3,648,582 $ 4,865,924
(a)Firm reservation fee revenues for the three and nine months ended September 30, 2024 included unbilled revenues supported by MVCs of approximately $1.8 million.

For contracts with customers where the Company's performance obligations had been satisfied and an unconditional right to consideration existed as of the balance sheet date, the Company recorded amounts due from contracts with customers of $443.3 million and $584.8 million in accounts receivable in the Condensed Consolidated Balance Sheets as of September 30, 2024 and December 31, 2023, respectively.
Summary of remaining performance obligations. The following table summarizes the transaction price allocated to the Company's remaining obligations on all contracts with fixed consideration as of September 30, 2024. The table excludes contracts that qualified for the exception to the relative standalone selling price method as of September 30, 2024. The MVP Joint Venture is accounted for as an equity method investment and, as such, its remaining performance obligations have been excluded from the table.
2024 (a) 2025 2026 2027 2028 Thereafter Total
(Thousands)
Gathering firm reservation fees:
Third-party contracts $ 25,850 $ 101,137 $ 92,186 $ 85,651 $ 85,651 $ 457,444 $ 847,919
Affiliate contracts 22,445 87,075 80,698 80,362 76,670 1,188,383 1,535,633
Total Gathering firm reservation fees 48,295 188,212 172,884 166,013 162,321 1,645,827 2,383,552
Gathering revenues supported by MVCs:
Third-party contracts 21,036 82,257 89,078 80,765 77,014 250,652 600,802
Affiliate contracts 90,630 372,446 397,966 410,621 411,740 2,453,073 4,136,476
Total Gathering revenues supported by MVCs 111,666 454,703 487,044 491,386 488,754 2,703,725 4,737,278
Transmission firm reservation fees:
Third-party contracts 48,754 175,010 174,191 171,750 169,393 980,973 1,720,071
Affiliate contracts 57,415 227,116 225,588 225,588 225,260 1,752,347 2,713,314
Total Transmission firm reservation fees 106,169 402,126 399,779 397,338 394,653 2,733,320 4,433,385
Total $ 266,130 $ 1,045,041 $ 1,059,707 $ 1,054,737 $ 1,045,728 $ 7,082,872 $ 11,554,215
(a)October 1 through December 31.

As of September 30, 2024, the Company had no remaining performance obligations on its natural gas sales contracts with fixed consideration.

Based on total projected contractual revenues, the Company's firm gathering affiliate contracts and firm transmission and storage affiliate contracts had weighted average remaining terms of approximately 13 years and 11 years, respectively, as of September 30, 2024. Based on total projected contractual revenues, the Company's firm gathering third-party contracts and firm transmission and storage third-party contracts had weighted average remaining terms of approximately 12 years and 11 years, respectively, as of September 30, 2024.

v3.24.3

Derivative Instruments
9 Months Ended

Sep. 30, 2024

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments Derivative Instruments

The Company's primary market risk exposure is the volatility of future prices for natural gas and NGLs, which can affect the Company's operating results. The Company uses derivative commodity instruments to hedge its cash flows from sales of produced natural gas and NGLs. The overall objective of the Company's hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices.

The derivative commodity instruments used by the Company are primarily swap, collar and option agreements. These agreements may result in payments to, or receipt of payments from, counterparties based on the differential between two prices for the commodity. The Company uses these agreements to hedge its NYMEX and basis exposure. The Company may also use other contractual agreements when executing its commodity hedging strategy. The Company typically enters into over the counter (OTC) derivative commodity instruments with financial institutions, and the creditworthiness of all counterparties is regularly monitored.
The Company does not designate any of its derivative instruments as cash flow hedges; therefore, all changes in fair value of the Company's derivative instruments are recognized in operating revenues in gain on derivatives in the Statements of Condensed Consolidated Operations. The Company recognizes all derivative instruments as either assets or liabilities at fair value on a gross basis. These derivative instruments are reported as either current assets or current liabilities due to their highly liquid nature. The Company can net settle its derivative instruments at any time.

Contracts that result in physical delivery of a commodity expected to be sold by the Company in the normal course of business are generally designated as normal sales and are exempt from derivative accounting. Contracts that result in the physical receipt or delivery of a commodity but are not designated or do not meet all of the criteria to qualify for the normal purchase and normal sale scope exception are subject to derivative accounting.

The Company's OTC derivative instruments generally require settlement in cash. The Company also enters into exchange traded derivative commodity instruments that are generally settled with offsetting positions. Settlements of derivative commodity instruments are reported as a component of cash flows from operating activities in the Statements of Condensed Consolidated Cash Flows.

With respect to the derivative commodity instruments held by the Company, the Company hedged portions of its expected sales of production and portions of its basis exposure covering approximately 2,574 Bcf of natural gas and 1,464 thousand barrels (Mbbl) of NGLs as of September 30, 2024 and 2,045 Bcf of natural gas and 1,049 Mbbl of NGLs as of December 31, 2023. The open positions at both September 30, 2024 and December 31, 2023 had maturities extending through December 2027.

Certain of the Company's OTC derivative instrument contracts provide that, if EQT's credit rating assigned by Moody's Investors Service, Inc. (Moody's), S&P Global Ratings (S&P) or Fitch Ratings Service (Fitch) is below the agreed-upon credit rating threshold (typically, below investment grade) and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the counterparty to such contract can require the Company to deposit collateral. Similarly, if such counterparty's credit rating assigned by Moody's, S&P or Fitch is below the agreed-upon credit rating threshold and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the Company can require the counterparty to deposit collateral with the Company. Such collateral can be up to 100% of the derivative liability. Investment grade refers to the quality of a company's credit as assessed by one or more credit rating agencies. To be considered investment grade, a company must be rated "Baa3" or higher by Moody's, "BBB–" or higher by S&P and "BBB–" or higher by Fitch. Anything below these ratings is considered non-investment grade. As of September 30, 2024, EQT's senior notes were rated "Baa3" by Moody's, "BBB–" by S&P and "BBB–" by Fitch.

When the net fair value of any of the Company's OTC derivative instrument contracts represents a liability to the Company that is in excess of the agreed-upon dollar threshold for the Company's then-applicable credit rating, the counterparty has the right to require the Company to remit funds as a margin deposit in an amount equal to the portion of the derivative liability that is in excess of the dollar threshold amount. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. As of September 30, 2024, none of the Company's OTC derivative instruments with credit rating risk-related contingent features were in a net liability position. As of December 31, 2023, the aggregate fair value of the Company's OTC derivative instruments with credit rating risk-related contingent features in a net liability position was $6.4 million, for which no deposits were required or recorded in the Condensed Consolidated Balance Sheet.

When the net fair value of any of the Company's OTC derivative instrument contracts represents an asset to the Company that is in excess of the agreed-upon dollar threshold for the counterparty's then-applicable credit rating, the Company has the right to require the counterparty to remit funds as a margin deposit in an amount equal to the portion of the derivative asset that is in excess of the dollar threshold amount. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. As of both September 30, 2024 and December 31, 2023, there were no such deposits recorded in the Condensed Consolidated Balance Sheets.
When the Company enters into exchange traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good-faith deposits to guard against the risks associated with changing market conditions. The Company is required to make such deposits based on an established initial margin requirement and the net liability position, if any, of the fair value of the associated contracts. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. When the fair value of such contracts is in a net asset position, the broker may remit funds to the Company. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the contract. The margin requirements are subject to change at the exchanges' discretion. As of September 30, 2024 and December 31, 2023, there were $17.5 million and $13.0 million, respectively, of such deposits recorded as current assets in the Condensed Consolidated Balance Sheets.

The Company has netting agreements with financial institutions and its brokers that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities. The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets Derivative instruments subject to
master netting agreements Margin requirements with counterparties Net derivative instruments
(Thousands)
September 30, 2024
Asset derivative instruments, at fair value $ 251,657 $ (152,115) $ — $ 99,542
Liability derivative instruments, at fair value 197,712 (152,115) (17,488) 28,109
December 31, 2023
Asset derivative instruments, at fair value $ 978,634 $ (112,203) $ — $ 866,431
Liability derivative instruments, at fair value 186,363 (112,203) (13,017) 61,143

v3.24.3

Fair Value Measurements
9 Months Ended

Sep. 30, 2024

Fair Value Disclosures [Abstract]

Fair Value Measurements Fair Value Measurements

The Company records its financial instruments, which are principally derivative instruments, at fair value in the Condensed Consolidated Balance Sheets. The Company estimates the fair value of its financial instruments using quoted market prices when available. If quoted market prices are not available, the fair value is based on models that use market-based parameters, including forward curves, discount rates, volatilities and nonperformance risk, as inputs. Nonperformance risk considers the effect of the Company's credit standing on the fair value of liabilities and the effect of the counterparty's credit standing on the fair value of assets. The Company estimates nonperformance risk by analyzing publicly available market information, including a comparison of the yield on debt instruments with credit ratings similar to EQT's or the counterparty's credit rating and the yield on a risk-free instrument.

The Company has categorized its assets and liabilities recorded at fair value into a three-level fair value hierarchy based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). Assets and liabilities that use Level 2 inputs primarily include the Company's swap, collar and option agreements.

Exchange traded commodity swaps have Level 1 inputs. The fair value of the commodity swaps with Level 2 inputs is based on standard industry income approach models that use significant observable inputs, including, but not limited to, NYMEX natural gas forward curves, SOFR-based discount rates, basis forward curves and NGLs forward curves. The Company's collars and options are valued using standard industry income approach option models. The significant observable inputs used by the option pricing models include NYMEX forward curves, natural gas volatilities and SOFR-based discount rates.
The table below summarizes assets and liabilities measured at fair value on a recurring basis.
Fair value measurements at reporting date using:
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets Quoted prices in active
markets for identical assets
(Level 1) Significant other observable inputs
(Level 2) Significant unobservable inputs
(Level 3)
(Thousands)
September 30, 2024
Asset derivative instruments, at fair value $ 251,657 $ 41,772 $ 209,885 $ —
Liability derivative instruments, at fair value 197,712 17,402 180,310 —
December 31, 2023
Asset derivative instruments, at fair value $ 978,634 $ 66,302 $ 912,332 $ —
Liability derivative instruments, at fair value 186,363 42,218 144,145 —

The carrying value of cash equivalents, accounts receivable and accounts payable approximates fair value due to their short-term maturities. The carrying value of borrowings under EQT's revolving credit facility, Eureka's revolving credit facility and the Term Loan Facility (defined in Note 7) approximates fair value as each facility's interest rate is based on prevailing market rates. The Company considers all of these fair values to be Level 1 fair value measurements.

The Company has an investment in a fund (the Investment Fund) that invests in companies developing technology and operating solutions for exploration and production companies. The Company values the Investment Fund using, as a practical expedient, the net asset value provided in the financial statements received from fund managers.

The Company estimates the fair value of its senior notes using established fair value methodology. Because not all of the Company's senior notes are actively traded, their fair value is a Level 2 fair value measurement. As of September 30, 2024 and December 31, 2023, the Company's senior notes had a fair value of approximately $11.2 billion and $4.9 billion, respectively, and a carrying value of approximately $11.0 billion and $4.5 billion, respectively, inclusive of any current portion. See Note 7 for further discussion of the Company's debt.

Upon the closing of the Equitrans Midstream Merger, EQT's note payable to EQM became an intercompany transaction on a consolidated basis and, as such, was effectively settled on July 22, 2024. See Note 12. As of December 31, 2023, the fair value of EQT's note payable to EQM was estimated using an income approach model with a market-based discount rate and was considered a Level 3 fair value measurement. As of December 31, 2023, EQT's note payable to EQM had a fair value and carrying value of approximately $91 million and $88 million, respectively, inclusive of any current portion.

The Company recognizes transfers between Levels as of the actual date of the event or change in circumstances that caused the transfer. There were no transfers between Levels 1, 2 and 3 during the periods presented.

See Note 2 for a discussion of the fair value measurement of the Henry Hub Cash Bonus (which became an intercompany derivative asset and liability upon the closing of the Equitrans Midstream Merger). See Note 11 for a discussion of the fair value measurement of the NEPA Non-Operated Asset Divestiture (defined therein). See Note 12 for a discussion of the fair value measurement of the Equitrans Midstream Merger. See Note 1 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, 2023 for a discussion of the fair value measurement and any subsequent impairments of the Company's oil and gas properties and other long-lived assets, including impairment and expiration of leases.

v3.24.3

Income Taxes
9 Months Ended

Sep. 30, 2024

Income Tax Disclosure [Abstract]

Income Taxes Income Taxes
For the nine months ended September 30, 2024 and 2023, the Company calculated the provision for income taxes by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the nine months ended September 30, 2024.

For the nine months ended September 30, 2024 and 2023, the Company recorded income tax (benefit) expense at an effective tax rate of 40.3% and 15.0%, respectively. The Company's effective tax rate for the nine months ended September 30, 2024 was higher compared to the U.S. federal statutory rate primarily as a result of recognition of tax benefits related to higher losses on the Company's state tax-paying entities and the utilization of some its capital loss carryforwards with the capital gain generated from the NEPA Non-Operated Asset Divestiture, which resulted in the release of the associated valuation allowance. The Company's effective tax rate for the nine months ended September 30, 2023 was lower compared to the U.S. federal statutory rate due primarily to the release of valuation allowances limiting certain state deferred tax assets and net state deferred tax benefits related to a rate reduction from a Pennsylvania tax law change enacted in July 2022 and the Tug Hill and XcL Midstream Acquisition.

v3.24.3

Debt
9 Months Ended

Sep. 30, 2024

Debt Disclosure [Abstract]

Debt Debt
The table below summarizes the Company's outstanding debt.

September 30, 2024 December 31, 2023
Principal Value Carrying Value (a) Principal Value Carrying Value (a)
(Thousands)
EQT's revolving credit facility maturing July 23, 2029 $ 1,967,000 $ 1,967,000 $ — $ —
Eureka's revolving credit facility maturing November 13, 2025 330,000 330,000 — —
Term Loan Facility due June 30, 2026 (b) 500,000 497,970 1,250,000 1,244,265
Debentures and senior notes:
EQT's 6.125% notes due February 1, 2025 (b)
— — 601,521 600,389
EQM's 6.000% notes due July 1, 2025
400,000 400,150 — —
EQT's 1.75% convertible notes due May 1, 2026 (c)
— — 290,177 286,185
EQT's 3.125% notes due May 15, 2026
392,915 390,889 392,915 389,978
EQT's 7.75% debentures due July 15, 2026
115,000 114,088 115,000 113,716
EQM's 4.125% notes due December 1, 2026
500,000 487,340 — —
EQM's 7.500% notes due June 1, 2027
500,000 512,554 — —
EQM's 6.500% notes due July 1, 2027
900,000 917,091 — —
EQT's 3.90% notes due October 1, 2027
1,169,503 1,166,252 1,169,503 1,165,439
EQT's 5.700% notes due April 1, 2028
500,000 492,074 500,000 490,376
EQM's 5.500% notes due July 15, 2028
850,000 846,328 — —
EQT's 5.00% notes due January 15, 2029
318,494 315,619 318,494 315,121
EQM's 4.50% notes due January 15, 2029
800,000 764,360 — —
EQM's 6.375% notes due April 1, 2029
600,000 609,177 — —
EQT's 7.000% notes due February 1, 2030 (b)
674,800 671,486 674,800 671,020
EQM's 7.500% notes due June 1, 2030
500,000 537,317 — —
EQM's 4.75% notes due January 15, 2031
1,100,000 1,042,951 — —
EQT's 3.625% notes due May 15, 2031
435,165 430,649 435,165 430,141
EQT's 5.750% notes due February 1, 2034
750,000 742,598 — —
EQM's 6.500% notes due July 15, 2048
550,000 557,655 — —
EQT's note payable to EQM (d) — — 88,483 88,483
Total debt 13,852,877 13,793,548 5,836,058 5,795,113
Less: Current portion of debt (e) 400,000 400,150 296,424 292,432
Long-term debt $ 13,452,877 $ 13,393,398 $ 5,539,634 $ 5,502,681
(a)For EQT's revolving credit facility, Eureka's revolving credit facility and, as of December 31, 2023, EQT's note payable to EQM, the principal value represents the carrying value. For all other debt, the principal value less the unamortized debt issuance costs and debt discounts and, for EQM's senior notes, the unamortized fair value adjustments recorded with Equitrans Midstream Merger purchase price accounting represents the carrying value.
(b)Interest rates for the Term Loan Facility and EQT's 7.000% senior notes fluctuate based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Prior to EQT's redemption of all of its outstanding 6.125% senior notes, interest rates for EQT's 6.125% senior notes fluctuated based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Interest rates for the Company's other outstanding debt do not fluctuate.
(c)As of December 31, 2023, the fair value of EQT's 1.75% convertible notes was $768.6 million and was a Level 2 fair value measurement. See Note 5.
(d)As a result of the Equitrans Midstream Merger, EQT's note payable to EQM has been eliminated in consolidation.
(e)As of September 30, 2024, the current portion of debt included EQM's 6.000% senior notes. As of December 31, 2023, the current portion of debt included EQT's 1.75% convertible notes and a portion of EQT's note payable to EQM.
Debt Repayments. The Company repaid, redeemed or repurchased the following debt during the nine months ended September 30, 2024.
Debt Tranche Principal Premiums Accrued but Unpaid Interest Total Cost
(Thousands)
EQM's 4.00% notes due August 1, 2024 (a)
$ 300,000 $ — $ 6,000 $ 306,000
EQT's 6.125% notes due February 1, 2025
601,521 1,178 13,612 616,311
Term Loan Facility due June 30, 2026 750,000 — 332 750,332
EQT's 1.75% convertible notes due May 1, 2026
583 — — 583
Total $ 1,652,104 $ 1,178 $ 19,944 $ 1,673,226
(a)EQM's 4.00% senior notes, which were consolidated by the Company as a result of the Equitrans Midstream Merger, were redeemed at maturity.

EQT's Revolving Credit Facility. EQT has a $3.5 billion revolving credit facility. On July 22, 2024, EQT entered into a Fourth Amended and Restated Credit Agreement (the Fourth A&R Credit Agreement) with PNC Bank National Association, as administrative agent, swing line lender and L/C issuer, and the other lenders party thereto, amending and restating the Third Amended and Restated Credit Agreement, dated June 28, 2022 (the Credit Agreement), under which such lenders agreed to make to EQT unsecured revolving loans in an aggregate principal amount of up to $3.5 billion. The Fourth A&R Credit Agreement, among other things, (i) extends the maturity date of the commitments and loans under the Credit Agreement to July 23, 2029 and provides, at EQT's option, two one-year extensions thereafter, subject to satisfaction of certain conditions, and (ii) allows for additional commitment increases up to $1 billion, subject to the agreement of EQT and new or existing lenders. EQT can obtain Base Rate Loans (as defined in the Fourth A&R Credit Agreement) or Term SOFR Rate Loans (as defined in the Fourth A&R Credit Agreement). Base Rate Loans are denominated in dollars and bear interest at a Base Rate (as defined in the Fourth A&R Credit Agreement) plus a margin ranging from 12.5 basis points to 100 basis points determined on the basis of EQT's credit ratings. Term SOFR Rate Loans bear interest at a Term SOFR Rate (as defined in the Fourth A&R Credit Agreement) plus an additional 10 basis point credit spread adjustment plus a margin ranging from 112.5 basis points to 200 basis points determined on the basis of EQT's credit ratings.

As of September 30, 2024, the Company had approximately $1 million of letters of credit outstanding under EQT's revolving credit facility and no letters of credit outstanding under Eureka's revolving credit facility. As of December 31, 2023, the Company had approximately $15 million of letters of credit outstanding under EQT's revolving credit facility.

During the three months ended September 30, 2024 and 2023, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $2,301 million and $158 million, respectively, and the average daily balance was approximately $1,608 million and $28 million, respectively. During the nine months ended September 30, 2024 and 2023, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $2,301 million and $158 million, respectively, and the average daily balance was approximately $551 million and $9 million, respectively. For each of the three and nine month periods ended September 30, 2024 and 2023, interest under EQT's revolving credit facility was incurred at a weighted average annual interest rate of 6.9%.

Eureka's Revolving Credit Facility. Upon the closing of the Equitrans Midstream Merger, the Company acquired a controlling interest in Eureka Midstream Holdings. See Notes 1 and 12. Eureka, a wholly-owned subsidiary of Eureka Midstream Holdings, has a $400 million senior secured revolving credit facility with Sumitomo Mitsui Banking Corporation, as administrative agent, the lenders party thereto from time to time and any other persons party thereto from time to time.

For the period beginning on July 22, 2024 and ending on September 30, 2024, under Eureka's revolving credit facility, both the maximum amount of outstanding borrowings and average daily balance was $330 million, and interest was incurred at a weighted average annual interest rate of 8.1%.

Eureka's revolving credit facility contains negative covenants that, among other things, limit restricted payments, incurrence of debt, dispositions, mergers and other fundamental changes and transactions with affiliates, in each case and as applicable, subject to certain specified exceptions. In addition, Eureka's revolving credit facility contains certain specified events of default, including insolvency, nonpayment of scheduled principal or interest obligations, loss and failure to replace certain material contracts, change of control and cross-default provisions related to the acceleration or default of certain other financial obligations.
EQM's revolving credit facility. Immediately following the closing of the Equitrans Midstream Merger, on July 22, 2024, EQM repaid outstanding obligations under that certain Third Amended and Restated Credit Agreement, dated October 31, 2018, by and among EQM, Wells Fargo Bank, National Association, as administrative agent, swing line lender and L/C issuer, and the other financial institutions from time to time party thereto for principal of $705 million and interest and fees of $4.5 million using cash on hand and cash contributions from EQT funded by borrowings under EQT's revolving credit facility, and, thereafter, EQM terminated its revolving credit facility.

Term Loan Facility. On November 9, 2022, EQT entered into a Credit Agreement (as amended on December 23, 2022, April 25, 2023, January 16, 2024 and July 22, 2024, the Term Loan Agreement) with PNC Bank, National Association, as administrative agent, and the other lenders party thereto, under which such lenders agreed to make to EQT unsecured term loans in a single draw in an aggregate principal amount of up to $1.25 billion (the Term Loan Facility) to partly fund the Tug Hill and XcL Midstream Acquisition. On August 21, 2023, EQT borrowed $1.25 billion under the Term Loan Facility, receiving net proceeds of $1,242.9 million.

On January 16, 2024, EQT entered into a third amendment to the Term Loan Agreement to, among other things, extend the maturity date of the Term Loan Agreement from June 30, 2025 to June 30, 2026. The third amendment to the Term Loan Agreement became effective on January 19, 2024 upon EQT's prepayment of $750 million principal amount of the term loans outstanding under the Term Loan Facility (funded with the net proceeds from the issuance of EQT's 5.750% senior notes and cash on hand) and the satisfaction of other closing conditions. On July 22, 2024, EQT entered into a fourth amendment to the Term Loan Agreement to, among other things, make certain conforming changes to the Term Loan Agreement in alignment with the Fourth A&R Credit Agreement. Pursuant to the Term Loan Agreement, EQT may voluntarily prepay, in whole or in part, borrowings under the Term Loan Facility without premium or penalty but subject to reimbursement of funding losses with respect to prepayment of loans that bear interest based on the Term SOFR Rate (as defined in the Term Loan Agreement). Borrowings under the Term Loan Facility that are repaid may not be re-borrowed.

At EQT's election, the term loans outstanding under the Term Loan Facility bear interest at a Term SOFR Rate plus the SOFR Adjustment or Base Rate (both terms defined in the Term Loan Agreement), each plus a margin based on EQT's credit ratings. For both the three and nine months ended September 30, 2024, interest under the Term Loan Facility was incurred at a weighted average annual interest rate of 6.9%. For the period beginning on August 21, 2023 and ending on September 30, 2023, interest under the Term Loan Facility was incurred at a weighted average annual interest rate of 7.0%.

EQM's Senior Notes. Upon the closing of the Equitrans Midstream Merger, EQM became an indirect wholly-owned subsidiary of EQT, and EQM's outstanding senior notes were consolidated by the Company.

The indentures governing EQM's senior notes contain certain restrictive financial and operating covenants, including covenants that restrict, among other things, EQM's ability to incur, as applicable, indebtedness, incur liens, enter into sale and leaseback transactions, complete acquisitions, merge, sell assets and perform certain other corporate actions. Certain of EQM's senior notes also include an offer to repurchase provision applicable upon the occurrence of certain change of control events specified in the applicable indentures.

As of September 30, 2024, aggregate maturities for EQM's senior notes are zero for the three months ended December 31, 2024, $400 million in 2025, $500 million in 2026, $1,400 million in 2027, $850 million in 2028, $1,400 million in 2029 and $2,150 million thereafter.

EQT's 5.750% Senior Notes. On January 19, 2024, EQT issued $750 million aggregate principal amount of 5.750% senior notes due February 1, 2034. The Company used net proceeds of $742.0 million, composed of the principal amount of $750 million net of capitalized debt issuance costs and underwriters' discount of $8.0 million, and cash on hand to prepay $750 million principal amount of the term loans outstanding under the Term Loan Facility. The covenants of the 5.750% senior notes are consistent with EQT's existing senior unsecured notes.

EQT's 1.75% Convertible Notes. In April 2020, EQT issued $500 million aggregate principal amount of 1.75% convertible senior notes (the Convertible Notes). The effective interest rate for the Convertible Notes was 2.4%.
On January 2, 2024, in accordance with the indenture governing the Convertible Notes (the Convertible Notes Indenture), EQT issued an irrevocable notice of redemption for all of the outstanding Convertible Notes and announced that EQT would redeem any of the Convertible Notes outstanding on January 17, 2024 in cash for 100% of the principal amount, plus accrued and unpaid interest on such Convertible Notes to, but excluding, such redemption date (the Redemption Price).

Pursuant to the Convertible Notes Indenture, between January 2, 2024 and the conversion deadline of 5:00 p.m., New York City time, on January 12, 2024, certain holders of the Convertible Notes exercised their right to convert their Convertible Notes prior to the redemption and validly surrendered an aggregate principal amount of $289.6 million of Convertible Notes. Based on a conversion rate of 69.0364 shares of EQT common stock per $1,000 principal amount of Convertible Notes, EQT issued to such holders an aggregate 19,992,482 shares of EQT common stock. Settlement of such Convertible Note conversion right exercises net of unamortized deferred issuance costs increased shareholder's equity by $285.6 million.

The remaining $0.6 million in outstanding principal amount of Convertible Notes was redeemed on January 17, 2024 in cash for the Redemption Price.

Inclusive of January 2024 settlements of Convertible Notes conversion right exercises that were exercised in December 2023, during January 2024, EQT settled $290.2 million aggregate principal amount of Convertible Notes conversion right exercises by issuing an aggregate 20,036,639 shares of EQT common stock to the converting holders at an average conversion price of $38.03.

Settlement and Termination of Capped Call Transactions. In connection with, but separate from, the issuance of the Convertible Notes, in 2020, EQT entered into capped call transactions (the Capped Call Transactions) with certain financial institutions (the Capped Call Counterparties) to reduce the potential dilution to EQT common stock upon any conversion of Convertible Notes at maturity and/or offset any cash payments that the Company is required to make in excess of the principal amount of such converted notes. The Capped Call Transactions had an initial strike price of $15.00 per share of EQT common stock and an initial cap price of $18.75 per share of EQT common stock, each of which were subject to certain customary adjustments, including adjustments as a result of EQT paying dividends on its common stock, and were set to expire in April 2026. The Company recorded the cost to purchase the Capped Call Transactions of $32.5 million as a reduction to shareholders' equity.

On January 18, 2024, EQT entered into separate termination agreements with each of the Capped Call Counterparties, pursuant to which the Capped Call Counterparties paid EQT an aggregate $93.3 million (the Termination Payments), and the Capped Call Transactions were terminated. EQT received the Termination Payments on January 22, 2024. The Termination Payments were recorded as an increase to shareholders' equity.

v3.24.3

Investment in the MVP Joint Venture
9 Months Ended

Sep. 30, 2024

Equity Method Investments and Joint Ventures [Abstract]

Investment in the MVP Joint Venture Investment in the MVP Joint Venture
The MVP Joint Venture. Upon the closing of the Equitrans Midstream Merger, the Company acquired an equity method investment in the MVP Joint Venture.

The MVP. The Company owned a 49.2% interest in the MVP as of September 30, 2024 and is the operator of the MVP. The MVP is a 303-mile long, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that spans from the Company's transmission and storage system in Wetzel County, West Virginia to Pittsylvania County, Virginia. Following receipt of authorization from the Federal Energy Regulatory Commission (the FERC), the MVP entered into service on June 14, 2024 and became available for interruptible or short-term firm transportation service. On July 1, 2024, the MVP commenced long-term firm capacity obligations. Estimated total project cost of the MVP is approximately $8.1 billion, excluding allowance for funds used during construction.

As of September 30, 2024, the Company had a negative basis difference between the carrying value of its equity method investment and its proportionate share of the MVP's net assets, which are composed of fixed assets. The basis difference is accreted over the life of the fixed assets and presented in income from investments in the Company's Statements of Condensed Consolidated Operations.

In September 2024, the MVP Joint Venture issued a capital call notice for the funding of the MVP project to the Company for $15.2 million, which was paid in October 2024. The capital contributions payable, which is presented in other current liabilities, and corresponding increase to the investment asset are included in the Condensed Consolidated Balance Sheet as of September 30, 2024.
MVP Southgate. As of September 30, 2024, the Company owned a 47.2% interest in MVP Southgate. MVP Southgate is a contemplated interstate pipeline that was approved by the FERC and was initially designed to extend approximately 75 miles from the MVP in Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina using 24-inch and 16-inch diameter pipe.

In December 2023, the MVP Joint Venture entered into precedent agreements with Public Service Company of North Carolina, Inc. and Duke Energy Carolinas, LLC. The precedent agreements contemplate an amended project and, among other things, describe certain conditions precedent to the parties' respective obligations regarding MVP Southgate. As amended, the natural gas interstate pipeline would extend approximately 31 miles from the terminus of the MVP in Pittsylvania County, Virginia to planned new delivery points in Rockingham County, North Carolina using 30-inch diameter pipe and have a targeted capacity of 550,000 dekatherms per day. Completion of the MVP Southgate pipeline is targeted for June 2028. The Company expects to operate the MVP Southgate pipeline.

Pursuant to the MVP Joint Venture's limited liability company agreement and upon the closing of the Equitrans Midstream Merger, the Company is obligated to provide performance assurances with respect to MVP Southgate that may take the form of a guarantee from EQM (provided that, in accordance with the requirements of the MVP Joint Venture's limited liability company agreement, EQM's debt is assigned an investment grade credit rating), a letter of credit or cash collateral. Upon receipt of the FERC's initial release to begin construction of the MVP Southgate project, the Company will be obligated to provide performance assurance in an amount equal to 33% of its share of MVP Southgate's remaining capital commitments.

v3.24.3

(Loss) Income Per Share
9 Months Ended

Sep. 30, 2024

Earnings Per Share [Abstract]

(Loss) Income Per Share (Loss) Income Per Share
The table below provides the computation for basic and diluted (loss) income per share.
Three Months Ended
September 30, Nine Months Ended
September 30,
2024 2023 2024 2023
(Thousands, except per share amounts)
Net (loss) income attributable to EQT Corporation – Basic (loss) income available to shareholders $ (300,823) $ 81,255 $ (187,818) $ 1,233,177
Add back: Interest expense on Convertible Notes, net of tax (a) — 2,042 — 6,117
Diluted (loss) income available to shareholders $ (300,823) $ 83,297 $ (187,818) $ 1,239,294
Weighted average common stock outstanding – Basic 559,603 383,359 480,354 368,936
Options, restricted stock, performance awards and stock appreciation rights (a) — 4,398 — 4,606
Convertible Notes (a) — 28,433 — 28,317
Weighted average common stock outstanding – Diluted 559,603 416,190 480,354 401,859
(Loss) income per share of common stock attributable to EQT Corporation:
Basic $ (0.54) $ 0.21 $ (0.39) $ 3.34
Diluted $ (0.54) $ 0.20 $ (0.39) $ 3.08
(a)In periods when the Company reports a net loss, all options, restricted stock, performance awards and stock appreciation awards, as applicable, are excluded from the calculation of diluted weighted average shares outstanding because of their anti-dilutive effect on loss per share. As a result, for the three and nine months ended September 30, 2024, all such securities of 7.6 million and 6.0 million, respectively, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share.

In addition, prior to EQT's redemption of the Convertible Notes, the Company used the if-converted method to calculate the impact of the Convertible Notes on diluted (loss) income per share. For the nine months ended September 30, 2024, such if-converted securities of approximately 0.5 million as well as the related add back of interest expense on the Convertible Notes, net of tax, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share.

v3.24.3

Share-based Compensation
9 Months Ended

Sep. 30, 2024

Share-Based Payment Arrangement [Abstract]

Share-based Compensation Share-based Compensation
In 2024, the Management Development and Compensation Committee of the Company's Board of Directors (the Compensation Committee) adopted the 2024 Incentive Performance Share Unit Program (2024 Incentive PSU Program) under the 2020 Long-Term Incentive Plan. During the nine months ended September 30, 2024, a total of 371,500 share units were granted under the 2024 Incentive PSU Program. The payout of the share units will vary between zero and 200% of the number of outstanding units contingent upon the Company's absolute total shareholder return and total shareholder return relative to a predefined peer group over the period of January 1, 2024 through December 31, 2026.

During the nine months ended September 30, 2024, the Compensation Committee granted 995,620 restricted stock unit equity awards that follow a three-year graded vesting schedule commencing with the date of grant, assuming continued employment through each vesting date. The share total includes the Company's "equity-for-all" program, instituted in 2021, pursuant to which the Company grants equity awards to all permanent employees.

In conjunction with the Equitrans Midstream Merger, the Company assumed all outstanding and unvested share-based compensation awards of Equitrans Midstream Corporation (Equitrans Midstream) and converted those assumed awards into 5,175,814 restricted stock unit equity awards that maintained the assumed awards' prior vesting schedules, assuming continued employment through each vesting date.

v3.24.3

Acquisitions and Divestitures
9 Months Ended

Sep. 30, 2024

Business Combination, Asset Acquisition, and Joint Venture Formation [Abstract]

Acquisitions and Divestitures Acquisitions and Divestitures
Tug Hill and XcL Midstream Acquisition. On August 22, 2023, the Company completed its acquisition (the Tug Hill and XcL Midstream Acquisition) of the upstream assets from THQ Appalachia I, LLC and the gathering and processing assets from THQ-XcL Holdings I, LLC through the acquisition of all of the issued and outstanding membership interests of each of THQ Appalachia I Midco, LLC and THQ-XcL Holdings I Midco, LLC. The purchase price for the Tug Hill and XcL Midstream Acquisition consisted of 49,599,796 shares of EQT common stock and approximately $2.4 billion in cash, subject to customary post-closing adjustments.

The Company accounted for the Tug Hill and XcL Midstream Acquisition as a business combination using the acquisition method. The Company completed the purchase price allocation for the Tug Hill and XcL Midstream Acquisition during the first quarter of 2024. The purchase accounting adjustments recorded in 2024 were not material.

NEPA Gathering System Acquisition. The Company operates and has historically owned a 50% interest in gathering assets located in Northeast Pennsylvania (collectively, the NEPA Gathering System). On April 11, 2024, the Company completed its acquisition of a minority equity partner's 33.75% interest in the NEPA Gathering System for a purchase price of approximately $205 million (the NEPA Gathering System Acquisition), subject to customary post-closing adjustments. The NEPA Gathering System Acquisition was accounted for as an asset acquisition and, as such, its purchase price was allocated to property, plant and equipment.

NEPA Non-Operated Asset Divestiture. On May 31, 2024, the Company completed the divestiture (the NEPA Non-Operated Asset Divestiture) of an undivided 40% interest in the Company's non-operated natural gas assets in Northeast Pennsylvania with a carrying amount of approximately $522 million to Equinor USA Onshore Properties Inc. and its affiliates (collectively, the Equinor Parties). The carrying value was composed of approximately $549 million of property, plant and equipment, approximately $7 million of other current liabilities and approximately $20 million of other liabilities and credits. In exchange, as consideration, the Company received from the Equinor Parties cash of $500 million, subject to customary post-closing purchase price adjustments, certain upstream assets and the remaining 16.25% equity interest in the NEPA Gathering System. The total fair value of consideration received, net of liabilities assumed, was approximately $842 million, subject to customary post-closing purchase price adjustments, and included $413 million of property, plant and equipment.

As a result of the NEPA Non-Operated Asset Divestiture, for the nine months ended September 30, 2024, the Company recognized a gain of approximately $312 million in loss (gain) on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations, inclusive of an $8 million loss recognized for the three months ended September 30, 2024. The gain was calculated as the carrying value of divested assets less the fair value of consideration received, net of liabilities assumed and divestiture costs incurred of approximately $8 million. Cash proceeds from the NEPA Non-Operated Asset Divestiture were used to partly fund EQT's redemption of its 6.125% senior notes.
The fair values of the natural gas properties received as consideration for the NEPA Non-Operated Asset Divestiture were measured using discounted cash flow valuation techniques based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include future commodity prices, projections of estimated quantities of reserves, estimated future rates of production, projected reserve recovery factors, timing and amount of future development and operating costs and a weighted average cost of capital.

The fair value of the undeveloped properties received as consideration for the NEPA Non-Operated Asset Divestiture were measured using the guideline transaction method based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include future development plans from a market participant perspective.

The fair value of the interest in the NEPA Gathering System received as consideration for the NEPA Non-Operated Asset Divestiture was measured using the cost approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include replacement cost for similar assets, relative age of the assets and potential economic or functional obsolescence.

See Note 5 for a description of the fair value hierarchy.

In addition, subsequent to the completion of the NEPA Non-Operated Asset Divestiture, the Company and the Equinor Parties entered into a gas buy-back agreement with respect to the assets received by the Company as consideration for the NEPA Non-Operated Asset Divestiture, whereby the Equinor Parties agreed to purchase a specified amount of natural gas from the Company through the first quarter of 2028.

Remaining NEPA Non-Operated Assets Divestiture. On October 29, 2024, the Company entered into an agreement with the Equinor Parties, pursuant to which the Company agreed to sell to the Equinor Parties the Company's remaining, undivided 60% interest in the Company's non-operated natural gas assets in Northeast Pennsylvania. In exchange, the Company will receive from the Equinor Parties $1.25 billion of cash (the Remaining NEPA Non-Operated Assets Divestiture). The Company intends to use the proceeds from the Remaining NEPA Non-Operated Assets Divestiture for repayment of the Company's debt. The Remaining NEPA Non-Operated Assets Divestiture is subject to customary closing adjustments, required regulatory approvals and clearances.

v3.24.3

Equitrans Midstream Merger
9 Months Ended

Sep. 30, 2024

Business Combination, Asset Acquisition, and Joint Venture Formation [Abstract]

Equitrans Midstream Merger Equitrans Midstream Merger
On July 22, 2024, the Company completed the Equitrans Midstream Merger pursuant to the agreement and plan of merger dated March 10, 2024 (the Merger Agreement), by and among EQT, Humpty Merger Sub Inc., an indirect wholly-owned subsidiary of EQT (Merger Sub), Humpty Merger Sub LLC, an indirect wholly-owned subsidiary of EQT (LLC Sub), and Equitrans Midstream.

Upon the terms and subject to the conditions set forth in the Merger Agreement, Merger Sub merged with and into Equitrans Midstream (the First Merger), with Equitrans Midstream surviving as an indirect wholly-owned subsidiary of EQT (the First Step Surviving Corporation), and, as the second step in a single integrated transaction with the First Merger, the First Step Surviving Corporation merged with and into LLC Sub (the Second Merger and, together with the First Merger, the Equitrans Midstream Merger), with LLC Sub surviving the Second Merger as an indirect wholly-owned subsidiary of EQT.

Upon the closing of the Equitrans Midstream Merger, each share of common stock, no par value, of Equitrans Midstream (Equitrans Midstream common stock) that was issued and outstanding immediately prior to the effective time of the First Merger (other than shares of Equitrans Midstream common stock owned by Equitrans Midstream or its subsidiaries or by the Company) was converted into the right to receive, without interest, 0.3504 shares of EQT common stock, which totaled 152,427,848 shares of EQT common stock with an aggregate value of $5.5 billion, based on an EQT common stock share price of $35.88. In addition, in connection with the closing of the Equitrans Midstream Merger, the Company paid an aggregate of $79.5 million of equity consideration to employees of Equitrans Midstream who did not continue with the Company following the Equitrans Midstream Merger closing date.
Immediately prior to the completion of the Equitrans Midstream Merger, on July 22, 2024, using borrowings under EQT's revolving credit facility, the Company paid $685.3 million to effect the purchase and redemption of all of the issued and outstanding Series A Perpetual Convertible Preferred Shares, no par value, of Equitrans Midstream (the Equitrans Midstream preferred stock).

Immediately following the closing of the Equitrans Midstream Merger, on July 22, 2024, EQM repaid all of its outstanding obligations under EQM's revolving credit facility using cash on hand and cash contributions from EQT, and, thereafter, EQM terminated its revolving credit facility. See Note 7.

Upon completion of the Equitrans Midstream Merger, the pre-existing contractual relationships between the Company, as producer, and Equitrans Midstream, as gathering and transmission services provider, are treated as intercompany transactions on a consolidated basis and, as such, were effectively settled on July 22, 2024. Likewise, upon completion of the Equitrans Midstream Merger, EQT's note payable to EQM became an intercompany transaction on a consolidated basis and, as such, was effectively settled on July 22, 2024.

For the three and nine months ended September 30, 2024, the Company recognized $274.6 million and $298.7 million, respectively, of transaction costs related to the Equitrans Midstream Merger within other operating expenses in the Statements of Condensed Consolidated Operations.
Allocation of Purchase Price. The Equitrans Midstream Merger was accounted for as a business combination using the acquisition method. The table below summarizes the preliminary purchase price and estimated fair values of assets acquired and liabilities assumed as of July 22, 2024 with the excess of purchase price over estimated fair value of the identified net assets recognized as goodwill. Certain information necessary to complete the purchase price allocation is not yet available, including, but not limited to, final appraisals of assets acquired and liabilities assumed and final income tax computations. The Company expects to complete the purchase price allocation once it has received all necessary information, at which time the value of the assets acquired and liabilities assumed will be revised if necessary.
Preliminary Purchase Price Allocation
(Thousands)
Consideration:
Equity $ 5,548,608
Cash (paid in lieu of fractional shares) 29
Redemption of Equitrans Midstream preferred stock 685,337
Settlement of pre-existing relationships (237,662)
Total consideration $ 5,996,312
Fair value of assets acquired:
Cash and cash equivalents $ 58,767
Accounts receivable, net 85,308
Income tax receivable 2,192
Prepaid expenses and other 22,048
Property, plant and equipment 9,387,823
Investment in the MVP Joint Venture 3,222,311
Net intangible assets 250,000
Other assets 240,248
Noncontrolling interest in consolidated subsidiaries (144,894)
Amount attributable to assets acquired $ 13,123,803
Fair value of liabilities assumed:
Current portion of debt $ 699,837
Accounts payable 65,761
Accrued interest 47,996
Other current liabilities 76,563
Revolving credit facility borrowings 1,035,000
Senior notes 6,273,941
Deferred income taxes 961,894
Other liabilities and credits 144,735
Amount attributable to liabilities assumed $ 9,305,727
Goodwill $ 2,178,236
The fair value of Equitrans Midstream's property, plant and equipment, which primarily includes gathering systems, transmission and storage systems and water infrastructure assets, and Equitrans Midstream's equity method investment in the MVP Joint Venture was measured using a combination of a cost and income approach based on inputs that are not observable in the market and, as such, are Level 3 fair value measurements. Significant inputs to the valuation of Equitrans Midstream's property, plant and equipment and investment in the MVP Joint Venture include replacement costs for similar assets, relative age of the assets, any potential economic or functional obsolescence associated with the assets, future revenue estimates and future operating cost assumptions and estimated weighted average costs of capital.

The fair value of the noncontrolling interest in Eureka Midstream Holdings was calculated using the noncontrolling interest ownership percentage and the enterprise value of Eureka Midstream Holdings, which was measured using a combination of a cost and income approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs to the valuation of the noncontrolling interest in Eureka Midstream Holdings include replacement costs for similar assets, relative age of the assets, any potential economic or functional obsolescence associated with the assets, future revenue estimates, future operating cost assumptions and estimated weighted average cost of capital.

As part of the preliminary purchase price allocation, the Company identified intangible assets related to certain of Equitrans Midstream's transmission services contracts. The fair value of the identified intangible assets was determined using the income approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs to the valuation of the identified intangible assets include future revenue estimates, future cost assumptions, estimated contract renewals, a discount rate assumption and an estimated required rate of return on the assets. The identified intangible assets are amortized over their useful life of 15 years on a straight-line basis, which reflects the pattern in which the Company expects to consume the economic benefits of the assets.

The fair value of EQM's senior notes was measured using established fair value methodology. Because not all of EQM's senior notes are actively traded, their fair value is a Level 2 fair value measurement. The difference between the fair value and principal amount of the assumed senior notes is amortized over the remaining life of the debt. The unamortized amount is presented as a reduction of debt in the Condensed Consolidated Balance Sheet. Because the carrying value of borrowings under EQM's revolving credit facility and Eureka's revolving credit facility approximated their respective fair value (as each facility's interest rate is based on prevailing market rates), the Company considers their fair values to be Level 1 fair value measurements.

Goodwill is attributable to the Company's qualitative assumptions of long-term value that the Equitrans Midstream Merger creates for EQT shareholders. Of the total goodwill, the Company attributed $1.3 billion to synergies expected from the vertical integration of the business, including from the elimination of contracted transportation and processing costs with Equitrans Midstream as the Company is unable to recognize intangible assets related to its significant long-term customer contracts with Equitrans Midstream as such contracts became intercompany transactions upon the closing of the Equitrans Midstream Merger. In addition, the Company attributed $0.9 billion of total goodwill to additional deferred tax liabilities that arose from the differences between the preliminary purchase price allocation based on fair value and tax basis that carried over from Equitrans Midstream to the Company. The Company allocated all of the goodwill from the Equitrans Midstream Merger to the Company's Transmission segment. Differences between the preliminary purchase price allocation and the final purchase price allocation may change the amount of goodwill recognized.

In conjunction with the Equitrans Midstream Merger, as of the Equitrans Midstream Merger closing date, the Company had unamortized carryover tax basis of $647.2 million of tax deductible goodwill.

See Note 5 for a description of the fair value hierarchy.
Post-Acquisition Operating Results. The table below summarizes amounts contributed by the assets acquired in the Equitrans Midstream Merger, inclusive of intercompany eliminations, to the Company's consolidated results for the period beginning on July 22, 2024 and ending on September 30, 2024.
July 22, 2024 through September 30, 2024
(Thousands)
Loss on derivatives $ (5,673)
Pipeline, net marketing services and other 110,403
Total operating revenues $ 104,730
Net loss $ (159,313)
Less: Net income attributable to noncontrolling interests 3,687
Net loss attributable to EQT Corporation $ (163,000)

Unaudited Pro Forma Information. The table below summarizes the Company's results as though the Equitrans Midstream Merger had been completed on January 1, 2023. Certain historical amounts were reclassified to conform to the Company's current financial presentation of operations. Such unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Equitrans Midstream Merger occurred on January 1, 2023 nor are they indicative of future consolidated results of operations.
Nine Months Ended
September 30,
2024 2023
(Thousands, except per share amounts)
Pro forma operating revenues:
Pro forma sales of natural gas, NGLs and oil $ 3,293,174 $ 3,680,566
Pro forma gain on derivatives 201,228 1,221,557
Pro forma pipeline, net marketing services and other 454,136 456,082
Pro forma total operating revenues $ 3,948,538 $ 5,358,205
Pro forma net income $ 19,543 $ 1,677,891
Less: Pro forma net income attributable to noncontrolling interests 17,696 21,891
Pro forma net income attributable to EQT Corporation $ 1,847 $ 1,656,000
Pro forma income per share of common stock attributable to EQT Corporation:
Pro forma net income attributable to EQT Corporation – Basic $ 0.00 $ 4.49
Pro forma net income attributable to EQT Corporation – Diluted $ 0.00 $ 4.14

v3.24.3

Commitments and Contingencies
9 Months Ended

Sep. 30, 2024

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies Commitments and Contingencies
Purchase Obligations

The following table summarizes the Company's commitments to pay demand charges under long-term contracts and binding precedent agreements with various pipelines and charges for processing capacity. The table presents the year or years in which such commitments are to be paid as of September 30, 2024 and December 31, 2023.

As of September 30, 2024 As of December 31, 2023
(Billions)
2024 (a) $ 0.2 $ 1.8
2025 0.8 1.8
2026 0.7 1.7
2027 0.7 1.7
2028 0.6 1.4
Thereafter 4.2 13.6
Total $ 7.2 $ 22.0
(a)As of September 30, 2024, the noted amount represented commitments payable for the three months ended December 31, 2024; as of December 31, 2023, the noted amount represented commitments payable for the year ended December 31, 2024.

The following table summarizes the Company's commitments to pay for services related to its operations, including electric hydraulic fracturing services, and purchase equipment, materials and sand. The table presents the year or years in which such commitments are to be paid as of September 30, 2024 and December 31, 2023.

As of September 30, 2024 As of December 31, 2023
(Millions)
2024 (a) $ 60.7 $ 228.8
2025 194.6 164.5
2026 148.4 138.0
2027 88.2 111.0
2028 37.9 72.9
Thereafter — 107.9
Total $ 529.8 $ 823.1
(a)As of September 30, 2024, the noted amount represented commitments payable for the three months ended December 31, 2024; as of December 31, 2023, the noted amount represented commitments payable for the year ended December 31, 2024.
Legal and Regulatory Proceedings

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company. While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings.

The Company evaluates its legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrues a loss for such matters when the Company believes that it is probable a liability has been incurred and the amount of the loss can be reasonably estimated. In such cases, if some amount within a range of loss appears to be a better estimate than any other amount within the range, that amount is accrued; however, when no amount within the range is a better estimate than any other amount, the minimum amount in the range is accrued. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event the Company determines that (i) it is probable a liability has been incurred but the amount of the loss cannot be reasonably estimated, or (ii) it less likely than probable but is reasonably possible that a liability has been incurred, then the Company is required to disclose the matter in its Annual Report on Form 10-K with any update thereto in this Quarterly Report on Form 10-Q, as applicable, although the Company is not required to accrue such loss.

When able, the Company determines an estimate of reasonably possible losses or ranges of reasonably possible losses, whether in excess of any related accrued loss or where there is no accrued loss, for legal proceedings. In instances where such estimates can be made, any such estimates are based on the Company's analysis of currently available information and are subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained.

The ultimate outcome of the matters described below is inherently uncertain. Furthermore, due to the inherent subjectivity of the assessments and unpredictability of outcomes of legal proceedings, any amounts accrued or estimated as possible losses may not represent the ultimate loss to the Company from the legal proceedings in question and the Company's exposure and ultimate losses may be higher, and possibly significantly so, than the amounts accrued or estimated.

Securities Class Action Litigation. On December 6, 2019, an amended putative class action complaint was filed in the United States District Court for the Western District of Pennsylvania by Cambridge Retirement System, Government of Guam Retirement Fund, Northeast Carpenters Annuity Fund, and Northeast Carpenters Pension Fund, on behalf of themselves and all those similarly situated, against EQT, and certain former executives and current and former board members of EQT (the Securities Class Action). The complaint alleges that certain statements made by EQT regarding its merger with Rice Energy Inc. in 2017 were materially false and violated various federal securities laws. Pursuant to the complaint, the plaintiffs seek compensatory or rescissory damages in an unspecified amount for all damages allegedly sustained by the class as a result of alleged negative impacts to EQT's stock price in 2018 and 2019.

Additionally, following the filing of the Securities Class Action complaint, several other lawsuits were filed in the United States District Court for the Western District of Pennsylvania and the Court of Common Pleas of Allegheny County, Pennsylvania by certain shareholders of EQT against EQT and certain former executives and current and former board members of EQT asserting substantially the same allegations as those raised in the Securities Class Action. These matters are currently pending, the majority of which have been stayed pending a ruling on dispositive motions in the Securities Class Action.

Following the commencement of the Securities Class Action, the parties engaged in fact and expert discovery. In June 2024, the discovery phase of the Securities Class Action was completed. On June 27, 2024, the parties to the Securities Class Action participated in a mediation (the Mediation), which did not result in resolution. A trial date for the Securities Class Action has not been determined.
In the second quarter of 2024, the Company recorded an accrual for estimated loss contingencies associated with the Securities Class Action in an amount equal to the settlement offer the Company tendered at the Mediation. Due to the inherent subjectivity of the assessments and unpredictability of outcomes of legal proceedings, the amount accrued for estimated losses associated with the Securities Class Action may not represent the ultimate loss to the Company, and the Company's exposure and ultimate losses may be higher, and possibly significantly so, than the amounts accrued or estimated. The amount accrued for such estimated losses is based on the Company's analysis of currently available information and is subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained. While the parties have completed discovery, various motions, including dispositive motions, have not yet been decided, the matters present meaningful legal uncertainties, and predicting the outcome depends on making assumptions about future decisions of courts and the behavior of other parties for which the Company does not currently have sufficient information. Given these uncertainties, the Company is unable at this time to reasonably estimate the range of possible additional losses above the amount accrued. The Company disputes the claims asserted in the Securities Class Action and related litigation and believes it has meritorious defenses, but unpredictability is inherent in litigation and the Company cannot predict the outcomes with any certainty.

See Note 11 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, 2023 for additional discussion of the Company's commitments and contingencies, including certain other pending legal and regulatory proceedings and other contingent matters. As of September 30, 2024, except as disclosed herein, there have been no material changes to such matters disclosed therein.

v3.24.3

Pay vs Performance Disclosure - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Pay vs Performance Disclosure

Net Income (Loss) $ (300,823) $ 81,255 $ (187,818) $ 1,233,177

v3.24.3

Insider Trading Arrangements
3 Months Ended

Sep. 30, 2024

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

v3.24.3

Financial Statements (Policies)
9 Months Ended

Sep. 30, 2024

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation
Basis of Presentation. The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all information and notes required by GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of the Company as of September 30, 2024 and December 31, 2023, the results of its operations and equity for the three and nine month periods ended September 30, 2024 and 2023 and its cash flows for the nine month periods ended September 30, 2024 and 2023. Certain previously reported amounts have been reclassified to conform to the current period presentation. In addition, as discussed further in Note 2, certain prior period amounts have been recast to reflect the Company's change in reportable segments from one reportable segment to three reportable segments consisting of Production, Gathering and Transmission.

Principles of Consolidation
Principles of Consolidation. The Condensed Consolidated Financial Statements include the accounts of EQT and all subsidiaries, ventures and partnerships in which EQT directly or indirectly holds a controlling interest. Intercompany accounts and transactions have been eliminated in consolidation.

Recently Issued Accounting Standards
Recently Issued Accounting Standards

In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures to improve reportable segment disclosure requirements, primarily through the requirement of enhanced disclosure of significant segment expenses. In addition, this ASU enhances interim disclosure requirements, clarifies circumstances in which an entity can disclose multiple segment measures of profit or loss and provides new segment disclosure requirements for entities with a single reportable segment. This ASU is effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-07 to have a material impact on its currently-presented financial statements and related disclosures.

In December 2023, the FASB issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures to improve its income tax disclosure requirements. Under this ASU, public business entities must annually (1) disclose specific categories in the rate reconciliation and (2) provide additional information for reconciling items that meet a quantitative threshold. This ASU is effective for fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-09 to have a material impact on its financial statements and related disclosures.

v3.24.3

Financial Statements (Tables)
9 Months Ended

Sep. 30, 2024

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures The following table summarizes net cash paid for interest and income taxes and non-cash activity included in the Statements of Condensed Consolidated Cash Flows.
Nine Months Ended September 30,
2024 2023
(Thousands)
Cash paid during the period for:
Interest, net of amount capitalized $ 196,632 $ 145,787
Income taxes, net 4,850 13,441
Non-cash activity during the period for:
Equity issued as consideration for acquisition (Notes 12 and 11)
$ 5,548,608 $ 2,152,631
Issuance of EQT common stock for Convertible Notes settlement (Note 7)
285,608 98
NEPA Non-Operated Asset Divestiture (Note 11)
155,241 —
Increase in right-of-use assets and lease liabilities, net 11,501 25,849
Increase in asset retirement costs and obligations 7,947 5,216
Capitalization of non-cash equity share-based compensation 5,273 4,587
Investments in nonconsolidated entities 17,598 —
Dissolution of consolidated variable interest entity — 25,227

v3.24.3

Financial Information by Business Segment (Tables)
9 Months Ended

Sep. 30, 2024

Segment Reporting [Abstract]

Schedule Of Financial Information By Business Segment and Capital Expenditures
Profit and loss metric with reconciliation to net (loss) income attributable to EQT Corporation for the three months ended September 30, 2024
Production Gathering Transmission Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 1,099,752 $ — $ — $ — $ 1,099,752
Gain (loss) on derivatives 72,489 (5,673) — — 66,816
Pipeline, net marketing services and other 5,826 276,829 87,384 (252,805) 117,234
Total operating revenues 1,178,067 271,156 87,384 (252,805) 1,283,802
Operating expenses:
Transportation and processing 693,670 — — (252,825) 440,845
Production 93,842 — — — 93,842
Operating and maintenance — 30,712 9,806 — 40,518
Exploration 282 — — — 282
Selling, general and administrative (a) 62,952 11,366 5,492 8,660 88,470
Depreciation, depletion and amortization 530,745 37,773 17,109 3,672 589,299
Loss on sale/exchange of long-lived assets 9,708 — 409 — 10,117
Impairment and expiration of leases 12,095 — — — 12,095
Other operating expenses (b) 10,206 — — 279,968 290,174
Total operating expenses 1,413,500 79,851 32,816 39,475 1,565,642
Operating (loss) income $ (235,433) $ 191,305 $ 54,568 $ (292,280) $ (281,840)
Reconciliation of profit and loss metric to net (loss) income attributable to EQT Corporation
Loss (income) from investments $ 1,671 $ (597) $ (35,616) $ 300 $ (34,242)
Other income (3,488) (128) (75) (269) (3,960)
Loss on debt extinguishment — — — 365 365
Interest expense, net — — — 158,299 158,299
(Loss) income before income taxes (233,616) 192,030 90,259 (450,975) (402,302)
Income tax benefit — — — (104,870) (104,870)
Net (loss) income (233,616) 192,030 90,259 (346,105) (297,432)
Less: Net income (loss) attributable to noncontrolling interests — 3,687 — (296) 3,391
Net (loss) income attributable to EQT Corporation $ (233,616) $ 188,343 $ 90,259 $ (345,809) $ (300,823)
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Equitrans Midstream Merger. See Note 12.
Profit and loss metric with reconciliation to net income attributable to EQT Corporation for the three months ended September 30, 2023
Production Gathering Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 1,001,883 $ — $ — $ 1,001,883
Gain on derivatives 177,906 — — 177,906
Pipeline, net marketing services and other 3,456 42,057 (39,200) 6,313
Total operating revenues 1,183,245 42,057 (39,200) 1,186,102
Operating expenses:
Transportation and processing 593,988 — (39,200) 554,788
Production 62,858 — — 62,858
Operating and maintenance — 4,235 — 4,235
Exploration 447 — — 447
Selling, general and administrative (a) 56,942 — — 56,942
Depreciation, depletion and amortization 440,360 4,054 2,472 446,886
Loss on sale/exchange of long-lived assets 1,511 — — 1,511
Impairment and expiration of leases 6,419 — — 6,419
Other operating expenses (b) (621) — 36,830 36,209
Total operating expenses 1,161,904 8,289 102 1,170,295
Operating income (loss) $ 21,341 $ 33,768 $ (39,302) $ 15,807
Reconciliation of profit and loss metric to net income attributable to EQT Corporation
Loss (income) from investments $ 424 $ (255) $ 377 $ 546
Other income — — (132) (132)
Loss on debt extinguishment — — 1,089 1,089
Interest expense, net — — 60,427 60,427
Income (loss) before income taxes 20,917 34,023 (101,063) (46,123)
Income tax benefit — — (126,853) (126,853)
Net income 20,917 34,023 25,790 80,730
Less: Net income (loss) attributable to noncontrolling interests 149 — (674) (525)
Net income attributable to EQT Corporation $ 20,768 $ 34,023 $ 26,464 $ 81,255
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Tug Hill and XcL Midstream Acquisition (defined in Note 11).
Profit and loss metric with reconciliation to net (loss) income attributable to EQT Corporation for the nine months ended September 30, 2024
Production Gathering Transmission Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 3,293,174 $ — $ — $ — $ 3,293,174
Gain (loss) on derivatives 240,333 (5,673) — — 234,660
Pipeline, net marketing services and other 2,757 415,491 87,384 (384,884) 120,748
Total operating revenues 3,536,264 409,818 87,384 (384,884) 3,648,582
Operating expenses:
Transportation and processing 1,914,010 — — (384,917) 1,529,093
Production 273,042 — — — 273,042
Operating and maintenance — 56,018 9,806 — 65,824
Exploration 2,576 — — — 2,576
Selling, general and administrative (a) 180,767 11,366 5,492 31,105 228,730
Depreciation, depletion and amortization 1,470,966 45,282 17,109 8,674 1,542,031
(Gain) loss on sale/exchange of long-lived assets (310,252) (22) 409 — (309,865)
Impairment and expiration of leases 58,963 — — — 58,963
Other operating expenses (b) 23,650 — — 330,687 354,337
Total operating expenses 3,613,722 112,644 32,816 (14,451) 3,744,731
Operating (loss) income $ (77,458) $ 297,174 $ 54,568 $ (370,433) $ (96,149)
Reconciliation of profit and loss metric to net (loss) income attributable to EQT Corporation
(Income) loss from investments $ (371) $ (2,109) $ (35,616) $ 1,422 $ (36,674)
Other income (17,638) (5,153) (75) (730) (23,596)
Loss on debt extinguishment — — — 5,651 5,651
Interest expense, net — — — 268,390 268,390
(Loss) income before income taxes (59,449) 304,436 90,259 (645,166) (309,920)
Income tax benefit — — — (124,790) (124,790)
Net (loss) income (59,449) 304,436 90,259 (520,376) (185,130)
Less: Net income (loss) attributable to noncontrolling interests — 3,687 — (999) 2,688
Net (loss) income attributable to EQT Corporation $ (59,449) $ 300,749 $ 90,259 $ (519,377) $ (187,818)
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Equitrans Midstream Merger. See Note 12.
Profit and loss metric with reconciliation to net income (loss) attributable to EQT Corporation for the nine months ended September 30, 2023
Production Gathering Other and intersegment eliminations EQT Corporation
(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 3,680,566 $ — $ — $ 3,680,566
Gain on derivatives 1,167,144 — — 1,167,144
Pipeline, net marketing services and other 9,675 95,753 (87,214) 18,214
Total operating revenues 4,857,385 95,753 (87,214) 4,865,924
Operating expenses:
Transportation and processing 1,680,009 — (87,075) 1,592,934
Production 163,963 — — 163,963
Operating and maintenance — 6,108 — 6,108
Exploration 2,602 — — 2,602
Selling, general and administrative (a) 168,999 — — 168,999
Depreciation, depletion and amortization 1,214,882 8,077 7,296 1,230,255
Loss on sale/exchange of long-lived assets 17,814 — — 17,814
Impairment and expiration of leases 22,290 — — 22,290
Other operating expenses (b) 7,645 — 61,620 69,265
Total operating expenses 3,278,204 14,185 (18,159) 3,274,230
Operating income (loss) $ 1,579,181 $ 81,568 $ (69,055) $ 1,591,694
Reconciliation of profit and loss metric to net income (loss) attributable to EQT Corporation
(Income) loss from investments $ (2,675) $ (4,004) $ 1,369 $ (5,310)
Other income (395) — (474) (869)
Gain on debt extinguishment — — (55) (55)
Interest expense, net — — 146,856 146,856
Income (loss) before income taxes 1,582,251 85,572 (216,751) 1,451,072
Income tax expense — — 217,975 217,975
Net income (loss) 1,582,251 85,572 (434,726) 1,233,097
Less: Net income (loss) attributable to noncontrolling interests 1,588 — (1,668) (80)
Net income (loss) attributable to EQT Corporation $ 1,580,663 $ 85,572 $ (433,058) $ 1,233,177
(a)Selling, general and administrative expense incurred prior to the Equitrans Midstream Merger closing date was not recast as the necessary information is not available and the cost to develop such information would be excessive.
(b)Corporate other operating expenses consisted primarily of transaction costs related to the Tug Hill and XcL Midstream Acquisition.
The Company did not have an investment in the MVP Joint Venture or goodwill as of September 30, 2023.

Capital expenditures by segment
Three Months Ended September 30, Nine Months Ended
September 30,
2024 2023 2024 2023
(Thousands)
Capital expenditures:
Production (a) $ 454,772 $ 435,646 $ 1,539,904 $ 1,366,669
Gathering (b) 79,597 6,941 111,644 11,521
Transmission 10,118 — 10,118 —
Other 13,402 1,998 21,345 8,546
Total capital expenditures $ 557,889 $ 444,585 $ 1,683,011 $ 1,386,736
(a)Production capital expenditures included capital expenditures attributable to the noncontrolling interest in The Mineral Company LLC (a joint venture formed between a subsidiary of EQT and a third-party investor for the purpose of purchasing certain mineral rights in the Appalachian Basin) of approximately $8.5 million for the nine months ended September 30, 2023. The Mineral Company LLC was dissolved in the third quarter of 2023.
(b)Gathering capital expenditures included capital expenditures attributable to the noncontrolling interest in Eureka Midstream Holdings of approximately $1.6 million for both the three and nine months ended September 30, 2024. See Notes 1 and 12.

Schedule of Assets By Segment
Assets by segment as of September 30, 2024
Production Gathering Transmission Other and intersegment eliminations EQT Corporation
(Thousands)
Investment in the MVP Joint Venture $ — $ — $ 3,358,346 $ — $ 3,358,346
Goodwill — — 1,289,759 888,477 2,178,236
Other segment assets (a) 22,890,299 8,187,601 2,962,486 368,621 34,409,007
Total assets $ 22,890,299 $ 8,187,601 $ 7,610,591 $ 1,257,098 $ 39,945,589
(a)Other segment assets in other and intersegment eliminations includes cash and cash equivalents.

Assets by segment as of September 30, 2023
Production Gathering Other and intersegment eliminations EQT Corporation
(Thousands)
Total assets (a) $ 23,138,353 $ 1,167,766 $ 248,869 $ 24,554,988
(a)Total assets in other and intersegment eliminations includes cash and cash equivalents.

v3.24.3

Revenue from Contracts with Customers (Tables)
9 Months Ended

Sep. 30, 2024

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue The table below provides disaggregated information on the Company's revenues. Certain other revenue contracts are outside the scope of ASU 2014-09, Revenue from Contracts with Customers. These contracts are reported in pipeline, net marketing services and other revenues in the Statements of Condensed Consolidated Operations. Derivative contracts are also outside the scope of ASU 2014-09.
Three Months Ended
September 30, Nine Months Ended
September 30,
2024 2023 2024 2023
(Thousands)
Revenues from contracts with customers:
Production:
Sales of natural gas, NGLs and oil
Natural gas sales $ 938,911 $ 859,512 $ 2,791,190 $ 3,337,600
NGLs sales 139,697 108,205 435,581 274,932
Oil sales 21,144 34,166 66,403 68,034
Sales of natural gas, NGLs and oil 1,099,752 1,001,883 3,293,174 3,680,566
Gathering:
Pipeline revenues
Firm reservation fee revenues (a) 136,752 — 136,752 —
Volumetric-based fee revenues 140,077 42,057 278,739 95,753
Total 276,829 42,057 415,491 95,753
Transmission:
Pipeline revenues
Firm reservation fee revenues 73,034 — 73,034 —
Volumetric-based fee revenues 14,226 — 14,226 —
Total 87,260 — 87,260 —
Other and intersegment eliminations (252,805) (39,200) (384,884) (87,214)
Total revenues from contracts with customers $ 1,211,036 $ 1,004,740 $ 3,411,041 $ 3,689,105
Other sources of revenue:
Gain on derivatives $ 66,816 $ 177,906 $ 234,660 $ 1,167,144
Net marketing services and other revenues 5,950 3,456 2,881 9,675
Total other sources of revenue $ 72,766 $ 181,362 $ 237,541 $ 1,176,819
Total operating revenues $ 1,283,802 $ 1,186,102 $ 3,648,582 $ 4,865,924
(a)Firm reservation fee revenues for the three and nine months ended September 30, 2024 included unbilled revenues supported by MVCs of approximately $1.8 million.

Schedule of Remaining Performance Obligations The following table summarizes the transaction price allocated to the Company's remaining obligations on all contracts with fixed consideration as of September 30, 2024. The table excludes contracts that qualified for the exception to the relative standalone selling price method as of September 30, 2024. The MVP Joint Venture is accounted for as an equity method investment and, as such, its remaining performance obligations have been excluded from the table.
2024 (a) 2025 2026 2027 2028 Thereafter Total
(Thousands)
Gathering firm reservation fees:
Third-party contracts $ 25,850 $ 101,137 $ 92,186 $ 85,651 $ 85,651 $ 457,444 $ 847,919
Affiliate contracts 22,445 87,075 80,698 80,362 76,670 1,188,383 1,535,633
Total Gathering firm reservation fees 48,295 188,212 172,884 166,013 162,321 1,645,827 2,383,552
Gathering revenues supported by MVCs:
Third-party contracts 21,036 82,257 89,078 80,765 77,014 250,652 600,802
Affiliate contracts 90,630 372,446 397,966 410,621 411,740 2,453,073 4,136,476
Total Gathering revenues supported by MVCs 111,666 454,703 487,044 491,386 488,754 2,703,725 4,737,278
Transmission firm reservation fees:
Third-party contracts 48,754 175,010 174,191 171,750 169,393 980,973 1,720,071
Affiliate contracts 57,415 227,116 225,588 225,588 225,260 1,752,347 2,713,314
Total Transmission firm reservation fees 106,169 402,126 399,779 397,338 394,653 2,733,320 4,433,385
Total $ 266,130 $ 1,045,041 $ 1,059,707 $ 1,054,737 $ 1,045,728 $ 7,082,872 $ 11,554,215
(a)October 1 through December 31.

As of September 30, 2024, the Company had no remaining performance obligations on its natural gas sales contracts with fixed consideration.

v3.24.3

Derivative Instruments (Tables)
9 Months Ended

Sep. 30, 2024

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Offsetting Assets The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets Derivative instruments subject to
master netting agreements Margin requirements with counterparties Net derivative instruments
(Thousands)
September 30, 2024
Asset derivative instruments, at fair value $ 251,657 $ (152,115) $ — $ 99,542
Liability derivative instruments, at fair value 197,712 (152,115) (17,488) 28,109
December 31, 2023
Asset derivative instruments, at fair value $ 978,634 $ (112,203) $ — $ 866,431
Liability derivative instruments, at fair value 186,363 (112,203) (13,017) 61,143

Schedule of Offsetting Liabilities The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets Derivative instruments subject to
master netting agreements Margin requirements with counterparties Net derivative instruments
(Thousands)
September 30, 2024
Asset derivative instruments, at fair value $ 251,657 $ (152,115) $ — $ 99,542
Liability derivative instruments, at fair value 197,712 (152,115) (17,488) 28,109
December 31, 2023
Asset derivative instruments, at fair value $ 978,634 $ (112,203) $ — $ 866,431
Liability derivative instruments, at fair value 186,363 (112,203) (13,017) 61,143

v3.24.3

Fair Value Measurements (Tables)
9 Months Ended

Sep. 30, 2024

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis
The table below summarizes assets and liabilities measured at fair value on a recurring basis.
Fair value measurements at reporting date using:
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets Quoted prices in active
markets for identical assets
(Level 1) Significant other observable inputs
(Level 2) Significant unobservable inputs
(Level 3)
(Thousands)
September 30, 2024
Asset derivative instruments, at fair value $ 251,657 $ 41,772 $ 209,885 $ —
Liability derivative instruments, at fair value 197,712 17,402 180,310 —
December 31, 2023
Asset derivative instruments, at fair value $ 978,634 $ 66,302 $ 912,332 $ —
Liability derivative instruments, at fair value 186,363 42,218 144,145 —

v3.24.3

Debt (Tables)
9 Months Ended

Sep. 30, 2024

Debt Disclosure [Abstract]

Schedule of Long-Term Debt Instruments
The table below summarizes the Company's outstanding debt.

September 30, 2024 December 31, 2023
Principal Value Carrying Value (a) Principal Value Carrying Value (a)
(Thousands)
EQT's revolving credit facility maturing July 23, 2029 $ 1,967,000 $ 1,967,000 $ — $ —
Eureka's revolving credit facility maturing November 13, 2025 330,000 330,000 — —
Term Loan Facility due June 30, 2026 (b) 500,000 497,970 1,250,000 1,244,265
Debentures and senior notes:
EQT's 6.125% notes due February 1, 2025 (b)
— — 601,521 600,389
EQM's 6.000% notes due July 1, 2025
400,000 400,150 — —
EQT's 1.75% convertible notes due May 1, 2026 (c)
— — 290,177 286,185
EQT's 3.125% notes due May 15, 2026
392,915 390,889 392,915 389,978
EQT's 7.75% debentures due July 15, 2026
115,000 114,088 115,000 113,716
EQM's 4.125% notes due December 1, 2026
500,000 487,340 — —
EQM's 7.500% notes due June 1, 2027
500,000 512,554 — —
EQM's 6.500% notes due July 1, 2027
900,000 917,091 — —
EQT's 3.90% notes due October 1, 2027
1,169,503 1,166,252 1,169,503 1,165,439
EQT's 5.700% notes due April 1, 2028
500,000 492,074 500,000 490,376
EQM's 5.500% notes due July 15, 2028
850,000 846,328 — —
EQT's 5.00% notes due January 15, 2029
318,494 315,619 318,494 315,121
EQM's 4.50% notes due January 15, 2029
800,000 764,360 — —
EQM's 6.375% notes due April 1, 2029
600,000 609,177 — —
EQT's 7.000% notes due February 1, 2030 (b)
674,800 671,486 674,800 671,020
EQM's 7.500% notes due June 1, 2030
500,000 537,317 — —
EQM's 4.75% notes due January 15, 2031
1,100,000 1,042,951 — —
EQT's 3.625% notes due May 15, 2031
435,165 430,649 435,165 430,141
EQT's 5.750% notes due February 1, 2034
750,000 742,598 — —
EQM's 6.500% notes due July 15, 2048
550,000 557,655 — —
EQT's note payable to EQM (d) — — 88,483 88,483
Total debt 13,852,877 13,793,548 5,836,058 5,795,113
Less: Current portion of debt (e) 400,000 400,150 296,424 292,432
Long-term debt $ 13,452,877 $ 13,393,398 $ 5,539,634 $ 5,502,681
(a)For EQT's revolving credit facility, Eureka's revolving credit facility and, as of December 31, 2023, EQT's note payable to EQM, the principal value represents the carrying value. For all other debt, the principal value less the unamortized debt issuance costs and debt discounts and, for EQM's senior notes, the unamortized fair value adjustments recorded with Equitrans Midstream Merger purchase price accounting represents the carrying value.
(b)Interest rates for the Term Loan Facility and EQT's 7.000% senior notes fluctuate based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Prior to EQT's redemption of all of its outstanding 6.125% senior notes, interest rates for EQT's 6.125% senior notes fluctuated based on changes to the credit ratings assigned to EQT's senior notes by Moody's, S&P and Fitch. Interest rates for the Company's other outstanding debt do not fluctuate.
(c)As of December 31, 2023, the fair value of EQT's 1.75% convertible notes was $768.6 million and was a Level 2 fair value measurement. See Note 5.
(d)As a result of the Equitrans Midstream Merger, EQT's note payable to EQM has been eliminated in consolidation.
(e)As of September 30, 2024, the current portion of debt included EQM's 6.000% senior notes. As of December 31, 2023, the current portion of debt included EQT's 1.75% convertible notes and a portion of EQT's note payable to EQM.

Schedule of Debt Redeemed or Repurchased The Company repaid, redeemed or repurchased the following debt during the nine months ended September 30, 2024.
Debt Tranche Principal Premiums Accrued but Unpaid Interest Total Cost
(Thousands)
EQM's 4.00% notes due August 1, 2024 (a)
$ 300,000 $ — $ 6,000 $ 306,000
EQT's 6.125% notes due February 1, 2025
601,521 1,178 13,612 616,311
Term Loan Facility due June 30, 2026 750,000 — 332 750,332
EQT's 1.75% convertible notes due May 1, 2026
583 — — 583
Total $ 1,652,104 $ 1,178 $ 19,944 $ 1,673,226
(a)EQM's 4.00% senior notes, which were consolidated by the Company as a result of the Equitrans Midstream Merger, were redeemed at maturity.

v3.24.3

(Loss) Income Per Share (Table)
9 Months Ended

Sep. 30, 2024

Earnings Per Share [Abstract]

Computation of Basic and Diluted (Loss) Income Per Share
The table below provides the computation for basic and diluted (loss) income per share.
Three Months Ended
September 30, Nine Months Ended
September 30,
2024 2023 2024 2023
(Thousands, except per share amounts)
Net (loss) income attributable to EQT Corporation – Basic (loss) income available to shareholders $ (300,823) $ 81,255 $ (187,818) $ 1,233,177
Add back: Interest expense on Convertible Notes, net of tax (a) — 2,042 — 6,117
Diluted (loss) income available to shareholders $ (300,823) $ 83,297 $ (187,818) $ 1,239,294
Weighted average common stock outstanding – Basic 559,603 383,359 480,354 368,936
Options, restricted stock, performance awards and stock appreciation rights (a) — 4,398 — 4,606
Convertible Notes (a) — 28,433 — 28,317
Weighted average common stock outstanding – Diluted 559,603 416,190 480,354 401,859
(Loss) income per share of common stock attributable to EQT Corporation:
Basic $ (0.54) $ 0.21 $ (0.39) $ 3.34
Diluted $ (0.54) $ 0.20 $ (0.39) $ 3.08
(a)In periods when the Company reports a net loss, all options, restricted stock, performance awards and stock appreciation awards, as applicable, are excluded from the calculation of diluted weighted average shares outstanding because of their anti-dilutive effect on loss per share. As a result, for the three and nine months ended September 30, 2024, all such securities of 7.6 million and 6.0 million, respectively, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share.

In addition, prior to EQT's redemption of the Convertible Notes, the Company used the if-converted method to calculate the impact of the Convertible Notes on diluted (loss) income per share. For the nine months ended September 30, 2024, such if-converted securities of approximately 0.5 million as well as the related add back of interest expense on the Convertible Notes, net of tax, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share.

v3.24.3

Equitrans Midstream Merger (Tables)
9 Months Ended

Sep. 30, 2024

Business Combination, Asset Acquisition, and Joint Venture Formation [Abstract]

Schedule of Purchase Price Allocation The Company expects to complete the purchase price allocation once it has received all necessary information, at which time the value of the assets acquired and liabilities assumed will be revised if necessary.
Preliminary Purchase Price Allocation
(Thousands)
Consideration:
Equity $ 5,548,608
Cash (paid in lieu of fractional shares) 29
Redemption of Equitrans Midstream preferred stock 685,337
Settlement of pre-existing relationships (237,662)
Total consideration $ 5,996,312
Fair value of assets acquired:
Cash and cash equivalents $ 58,767
Accounts receivable, net 85,308
Income tax receivable 2,192
Prepaid expenses and other 22,048
Property, plant and equipment 9,387,823
Investment in the MVP Joint Venture 3,222,311
Net intangible assets 250,000
Other assets 240,248
Noncontrolling interest in consolidated subsidiaries (144,894)
Amount attributable to assets acquired $ 13,123,803
Fair value of liabilities assumed:
Current portion of debt $ 699,837
Accounts payable 65,761
Accrued interest 47,996
Other current liabilities 76,563
Revolving credit facility borrowings 1,035,000
Senior notes 6,273,941
Deferred income taxes 961,894
Other liabilities and credits 144,735
Amount attributable to liabilities assumed $ 9,305,727
Goodwill $ 2,178,236

Schedule of Post-Acquisition Operating Results The table below summarizes amounts contributed by the assets acquired in the Equitrans Midstream Merger, inclusive of intercompany eliminations, to the Company's consolidated results for the period beginning on July 22, 2024 and ending on September 30, 2024.
July 22, 2024 through September 30, 2024
(Thousands)
Loss on derivatives $ (5,673)
Pipeline, net marketing services and other 110,403
Total operating revenues $ 104,730
Net loss $ (159,313)
Less: Net income attributable to noncontrolling interests 3,687
Net loss attributable to EQT Corporation $ (163,000)
Such unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Equitrans Midstream Merger occurred on January 1, 2023 nor are they indicative of future consolidated results of operations.
Nine Months Ended
September 30,
2024 2023
(Thousands, except per share amounts)
Pro forma operating revenues:
Pro forma sales of natural gas, NGLs and oil $ 3,293,174 $ 3,680,566
Pro forma gain on derivatives 201,228 1,221,557
Pro forma pipeline, net marketing services and other 454,136 456,082
Pro forma total operating revenues $ 3,948,538 $ 5,358,205
Pro forma net income $ 19,543 $ 1,677,891
Less: Pro forma net income attributable to noncontrolling interests 17,696 21,891
Pro forma net income attributable to EQT Corporation $ 1,847 $ 1,656,000
Pro forma income per share of common stock attributable to EQT Corporation:
Pro forma net income attributable to EQT Corporation – Basic $ 0.00 $ 4.49
Pro forma net income attributable to EQT Corporation – Diluted $ 0.00 $ 4.14

v3.24.3

Commitment and Contingencies (Tables)
9 Months Ended

Sep. 30, 2024

Commitments and Contingencies Disclosure [Abstract]

Schedule of Purchase Commitment
The following table summarizes the Company's commitments to pay demand charges under long-term contracts and binding precedent agreements with various pipelines and charges for processing capacity. The table presents the year or years in which such commitments are to be paid as of September 30, 2024 and December 31, 2023.

As of September 30, 2024 As of December 31, 2023
(Billions)
2024 (a) $ 0.2 $ 1.8
2025 0.8 1.8
2026 0.7 1.7
2027 0.7 1.7
2028 0.6 1.4
Thereafter 4.2 13.6
Total $ 7.2 $ 22.0
(a)As of September 30, 2024, the noted amount represented commitments payable for the three months ended December 31, 2024; as of December 31, 2023, the noted amount represented commitments payable for the year ended December 31, 2024.

The following table summarizes the Company's commitments to pay for services related to its operations, including electric hydraulic fracturing services, and purchase equipment, materials and sand. The table presents the year or years in which such commitments are to be paid as of September 30, 2024 and December 31, 2023.

As of September 30, 2024 As of December 31, 2023
(Millions)
2024 (a) $ 60.7 $ 228.8
2025 194.6 164.5
2026 148.4 138.0
2027 88.2 111.0
2028 37.9 72.9
Thereafter — 107.9
Total $ 529.8 $ 823.1
(a)As of September 30, 2024, the noted amount represented commitments payable for the three months ended December 31, 2024; as of December 31, 2023, the noted amount represented commitments payable for the year ended December 31, 2024.

v3.24.3

Financial Statements - Narrative (Details)
2 Months Ended 7 Months Ended

Sep. 30, 2024

reportable_segment

shares

Jul. 21, 2024

reportable_segment

Jul. 22, 2024

Jul. 18, 2024

shares

Jul. 17, 2024

shares

Dec. 31, 2023

shares

Sep. 30, 2023

shares

Subsequent Event [Line Items]

Number of reportable segments | reportable_segment 3 1

Common stock, authorized shares (in shares) | shares 1,280,000,000 1,280,000,000 640,000,000 640,000,000 640,000,000

Eureka Midstream Holdings L L C | Variable Interest Entity, Primary Beneficiary

Subsequent Event [Line Items]

Ownership interest (in percent) 60.00%

v3.24.3

Financial Statements - Schedule of Cash Flow, Supplemental Disclosures (Details) - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Cash paid during the period for:

Interest, net of amount capitalized $ 196,632 $ 145,787

Income taxes, net 4,850 13,441

Non-cash activity during the period for:

Equity issued as consideration for acquisition 5,548,608 2,152,631

Issuance of EQT Corporation common stock for Convertible Notes settlement $ 16 285,608 98

NEPA Non-Operated Asset Divestiture 155,241 0

Increase in right-of-use assets and lease liabilities, net 11,501 25,849

Increase in asset retirement costs and obligations 7,947 5,216

Capitalization of non-cash equity share-based compensation 5,273 4,587

Investments in nonconsolidated entities 17,598 0

Dissolution of consolidated variable interest entity $ 0 $ 25,227

v3.24.3

Financial Information by Business Segment - Narrative (Details)
$ in Millions
2 Months Ended 7 Months Ended

Feb. 26, 2020

Bcf / d

Sep. 30, 2024

USD ($)

business

segment

reportable_segment

Jul. 21, 2024

reportable_segment

Dec. 31, 2023

USD ($)

Operating segments information

Number of reportable segments | reportable_segment 3 1

Number of operating segments | segment 3

Number of lines of business | business 3

Henry hub cash bonus

Operating segments information

Cash bonus payment period 36 months

Derivative liability | $ $ 15 $ 48

EQT Producer

Operating segments information

Annual minimum volume (in Bcf per day) | Bcf / d 3.0

v3.24.3

Financial Information by Business Segment - Schedule of Segment Assets (Details) - USD ($)
$ in Thousands

Sep. 30, 2024

Dec. 31, 2023

Sep. 30, 2023

Segment assets:

Investment in the MVP Joint Venture $ 3,358,346 $ 0

Goodwill 2,178,236 0

Other segment assets 34,409,007

Total assets 39,945,589 $ 25,285,098 $ 24,554,988

Operating Segments

Segment assets:

Investment in the MVP Joint Venture

Goodwill

Other segment assets

Total assets

Other and intersegment eliminations

Segment assets:

Investment in the MVP Joint Venture 0

Goodwill 888,477

Other segment assets 368,621

Total assets 1,257,098 248,869

Production | Operating Segments

Segment assets:

Investment in the MVP Joint Venture 0

Goodwill 0

Other segment assets 22,890,299

Total assets 22,890,299 23,138,353

Gathering | Operating Segments

Segment assets:

Investment in the MVP Joint Venture 0

Goodwill 0

Other segment assets 8,187,601

Total assets 8,187,601 $ 1,167,766

Transmission | Operating Segments

Segment assets:

Investment in the MVP Joint Venture 3,358,346

Goodwill 1,289,759

Other segment assets 2,962,486

Total assets $ 7,610,591

v3.24.3

Financial Information by Business Segment - Schedule of Capital Expenditures By Segment (Details) - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Capital expenditures:

Total capital expenditures $ 557,889 $ 444,585 $ 1,683,011 $ 1,386,736

Mineral Company

Capital expenditures:

Total capital expenditures 8,500

Eureka Midstream Holdings L L C

Capital expenditures:

Total capital expenditures 1,600 1,600

Operating Segments | Production

Capital expenditures:

Total capital expenditures 454,772 435,646 1,539,904 1,366,669

Operating Segments | Gathering

Capital expenditures:

Total capital expenditures 79,597 6,941 111,644 11,521

Operating Segments | Transmission

Capital expenditures:

Total capital expenditures 10,118 0 10,118 0

Other and intersegment eliminations

Capital expenditures:

Total capital expenditures $ 13,402 $ 1,998 $ 21,345 $ 8,546

v3.24.3

Derivative Instruments - Narrative (Details)
9 Months Ended 12 Months Ended

Sep. 30, 2024

USD ($)

Bcf

Sep. 30, 2024

USD ($)

MBbls

Sep. 30, 2024

USD ($)

Dec. 31, 2023

USD ($)

Bcf

Dec. 31, 2023

USD ($)

MBbls

Derivative Instruments, Gain (Loss)

Maximum additional collateral as percentage of derivative liability (in percent) 100.00%

Aggregate fair value of derivative instruments with credit-risk related contingencies $ 0 $ 0 $ 0 $ 6,400,000 $ 6,400,000

Collateral posted 0 0 0 0 0

OTC Derivative Instrument Contracts

Derivative Instruments, Gain (Loss)

Aggregate fair value of derivative instruments with credit-risk related contingencies 0 0 0 0 0

Exchange traded natural gas contracts

Derivative Instruments, Gain (Loss)

Collateral posted $ 17,500,000 $ 17,500,000 $ 17,500,000 $ 13,000,000 $ 13,000,000

Cash flow hedging | Commodity derivatives

Derivative Instruments, Gain (Loss)

Volume of derivative instruments (in Bcf, Mbbls) 2,574 1,464 2,045 1,049

v3.24.3

Fair Value Measurements - Narrative (Details) - USD ($)
$ in Thousands

Sep. 30, 2024

Dec. 31, 2023

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis

Net carrying value of convertible notes $ 13,793,548 $ 5,795,113

Senior Notes

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis

Net carrying value of convertible notes 11,000,000 4,500,000

Senior Notes | Significant other observable inputs (Level 2)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis

Estimated fair value of long-term debt 11,200,000 4,900,000

Notes payable to EQM | Note payable to EQM

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis

Net carrying value of convertible notes $ 0 88,483

Notes payable to EQM | Significant unobservable inputs (Level 3) | Note payable to EQM

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis

Estimated fair value of long-term debt $ 91,000

v3.24.3

Income Taxes (Details)
9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Income Tax Disclosure [Abstract]

Effective income tax expense (in percent) 40.30% 15.00%

v3.24.3

Debt - Debt Instrument Redemption (Details) - USD ($)
$ in Thousands

Sep. 30, 2024

Dec. 31, 2023

Apr. 30, 2020

Senior Notes

Debt Instrument [Line Items]

Principal $ 1,652,104

Premiums 1,178

Accrued but Unpaid Interest 19,944

Total Cost $ 1,673,226

EQM 4.00% notes due August 1, 2024 | Senior Notes

Debt Instrument [Line Items]

Interest rate, stated percentage (in percent) 4.00% 4.00%

Principal $ 300,000

Premiums 0

Accrued but Unpaid Interest 6,000

Total Cost $ 306,000

6.125% notes due February 1, 2025 | Senior Notes

Debt Instrument [Line Items]

Interest rate, stated percentage (in percent) 6.125% 6.125%

Principal $ 601,521

Premiums 1,178

Accrued but Unpaid Interest 13,612

Total Cost 616,311

Term Loan Facility due June 30, 2025 | Loans Payable

Debt Instrument [Line Items]

Principal 750,000

Premiums 0

Accrued but Unpaid Interest 332

Total Cost $ 750,332

1.75% convertible notes due May 1, 2026 | Senior Notes

Debt Instrument [Line Items]

Interest rate, stated percentage (in percent) 1.75% 1.75% 1.75%

Principal $ 583

Premiums 0

Accrued but Unpaid Interest 0

Total Cost $ 583

v3.24.3

(Loss) Income Per Share (Details) - USD ($)
$ / shares in Units, shares in Thousands, $ in Thousands
3 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2023

Sep. 30, 2024

Sep. 30, 2023

Earnings Per Share Reconciliation [Abstract]

Net (loss) income attributable to EQT Corporation – Basic (loss) income available to shareholders $ (300,823) $ 81,255 $ (187,818) $ 1,233,177

Add back: Interest expense on Convertible Notes, net of tax 0 2,042 0 6,117

Diluted (loss) income available to shareholders $ (300,823) $ 83,297 $ (187,818) $ 1,239,294

Weighted Average Number of Shares Outstanding Reconciliation [Abstract]

Weighted average common stock outstanding - basic (in shares) 559,603 383,359 480,354 368,936

Weighted average common stock outstanding - diluted (in shares) 559,603 416,190 480,354 401,859

(Loss) income per share of common stock attributable to EQT Corporation:

Basic (in dollars per share) $ (0.54) $ 0.21 $ (0.39) $ 3.34

Diluted (in dollars per share) $ (0.54) $ 0.20 $ (0.39) $ 3.08

Options, restricted stock, performance awards, and stock appreciation rights

(Loss) income per share of common stock attributable to EQT Corporation:

Shares excluded from potentially dilutive securities (in shares) 7,600 6,000

Convertible notes

(Loss) income per share of common stock attributable to EQT Corporation:

Shares excluded from potentially dilutive securities (in shares) 500

Options, restricted stock, performance awards, and stock appreciation rights

Weighted Average Number of Shares Outstanding Reconciliation [Abstract]

Potentially dilutive securities included in the calculation of diluted earnings (in shares) 0 4,398 0 4,606

Convertible notes

Weighted Average Number of Shares Outstanding Reconciliation [Abstract]

Potentially dilutive securities included in the calculation of diluted earnings (in shares) 0 28,433 0 28,317

v3.24.3

Share-based Compensation (Details) - shares
9 Months Ended

Sep. 30, 2024

Jul. 22, 2024

Restricted Stock Units (RSUs)

Share-based Compensation Arrangement by Share-based Payment Award

Shares granted (in shares) 995,620

Vesting period 3 years

Restricted Stock Units (RSUs) | Equitrans Midstream Merger

Share-based Compensation Arrangement by Share-based Payment Award

Outstanding shares (in shares) 5,175,814

Incentive Performance Share Unit Program | Performance shares

Share-based Compensation Arrangement by Share-based Payment Award

Shares granted (in shares) 371,500

Incentive Performance Share Unit Program | Performance shares | Minimum

Share-based Compensation Arrangement by Share-based Payment Award

Payout percentage (in percent) 0.00%

Incentive Performance Share Unit Program | Performance shares | Maximum

Share-based Compensation Arrangement by Share-based Payment Award

Payout percentage (in percent) 200.00%

v3.24.3

Acquisitions and Divestitures - Narrative (Details) - USD ($)
$ in Thousands
3 Months Ended 9 Months Ended

Oct. 29, 2024

May 31, 2024

Apr. 11, 2024

Aug. 22, 2023

Sep. 30, 2024

Sep. 30, 2024

Sep. 30, 2023

Apr. 10, 2024

Dec. 31, 2023

Business Acquisition [Line Items]

Cash payments to acquire business $ 864,242 $ 2,288,201

6.125% notes due February 1, 2025 | Senior Notes

Business Acquisition [Line Items]

Interest rate, stated percentage (in percent) 6.125% 6.125% 6.125%

NEPA Non Operated Asset Divestiture | Disposal Group, Disposed of by Sale, Not Discontinued Operations

Business Acquisition [Line Items]

Percentage of natural gas asset interest sold (percent) 40.00%

Carrying amount of divestiture $ 522,000

Property, plant and equipment, carrying value 549,000

Other current liabilities, carrying value 7,000

Other liabilities, carrying value 20,000

Proceeds from sale of oil and gas property and equipment $ 500,000

Equity interest to be received upon disposal (percent) 16.25%

Gain (loss) on sale of long-lived assets $ (8,000) $ 312,000

Divestiture cost $ 8,000

NEPA Non Operated Asset Divestiture | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Subsequent Event

Business Acquisition [Line Items]

Percentage of natural gas asset interest sold (percent) 60.00%

Proceeds from divestiture of interest $ 1,250,000

NEPA Non Operated Asset Divestiture | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Fair value | Significant unobservable inputs (Level 3)

Business Acquisition [Line Items]

Fair value of consideration received, net of liabilities assumed $ 842,000

Property plant and equipment $ 413,000

Tug Hill and XcL Midstream

Business Acquisition [Line Items]

Equity interest issued or issuable, number of shares (in shares) 49,599,796

Cash payments to acquire business $ 2,400,000

NEPA Gathering System Acquisition

Business Acquisition [Line Items]

Percentage of operates and owns interest (percent) 50.00%

Ownership interest acquired (percent) 33.75%

Consideration to be paid $ 205,000

v3.24.3

Equitrans Midstream Merger (Details)
$ / shares in Units, $ in Thousands
3 Months Ended 9 Months Ended

Jul. 22, 2024

USD ($)

$ / shares

shares

Sep. 30, 2024

USD ($)

Sep. 30, 2024

USD ($)

Sep. 30, 2023

USD ($)

Business Combination, Separately Recognized Transactions [Line Items]

Equity issued as consideration for acquisition $ 5,548,608 $ 2,152,631

Equitrans Midstream Merger

Business Combination, Separately Recognized Transactions [Line Items]

Number of shares issuable for each existing share converted (in shares) 0.3504

Equity interest issued or issuable, number of shares (in shares) | shares 152,427,848

Equity issued as consideration for acquisition $ 5,548,608

Share price (in dollars per share) | $ / shares $ 35.88

Purchase and redemption price $ 685,337

Proxy, transaction and reorganization $ 274,600 $ 298,700

Intangible asset, useful life 15 years

Goodwill attributed to synergies expected from the vertical integration of the business $ 1,300,000

Goodwill attributable to additional tax liabilities arising from the difference between preliminary purchase price allocation and tax basis 900,000

Goodwill tax deductible amount 647,200

Equitrans Midstream Merger | Employees Of Equitrans Midstream

Business Combination, Separately Recognized Transactions [Line Items]

Equity issued as consideration for acquisition $ 79,500

v3.24.3

Equitrans Midstream Merger - Purchase Price Allocation (Details) - USD ($)
$ in Thousands
9 Months Ended

Jul. 22, 2024

Sep. 30, 2024

Sep. 30, 2023

Dec. 31, 2023

Consideration:

Equity $ 5,548,608 $ 2,152,631

Cash (paid in lieu of fractional shares) 864,242 $ 2,288,201

Fair value of liabilities assumed:

Goodwill $ 2,178,236 $ 0

Equitrans Midstream Merger

Consideration:

Equity $ 5,548,608

Cash (paid in lieu of fractional shares) 29

Redemption of Equitrans Midstream preferred stock 685,337

Settlement of pre-existing relationships (237,662)

Total consideration 5,996,312

Fair value of assets acquired:

Cash and cash equivalents 58,767

Accounts receivable, net 85,308

Income tax receivable 2,192

Prepaid expenses and other 22,048

Property, plant and equipment 9,387,823

Investment in the MVP Joint Venture 3,222,311

Net intangible assets 250,000

Other assets 240,248

Noncontrolling interest in consolidated subsidiaries (144,894)

Amount attributable to assets acquired 13,123,803

Fair value of liabilities assumed:

Current portion of debt 699,837

Accounts payable 65,761

Accrued interest 47,996

Other current liabilities 76,563

Revolving credit facility borrowings 1,035,000

Senior notes 6,273,941

Deferred income taxes 961,894

Other liabilities and credits 144,735

Amount attributable to liabilities assumed 9,305,727

Goodwill $ 2,178,236

v3.24.3

Equitrans Midstream Merger - Post-Acquisition Operating Results (Details) - Equitrans Midstream Merger - USD ($)
$ in Thousands
2 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2024

Sep. 30, 2023

Business Acquisition [Line Items]

Loss on derivatives $ (5,673)

Pipeline, net marketing services and other 110,403

Total operating revenues 104,730

Net loss (159,313)

Less: Net income attributable to noncontrolling interests 3,687 $ 17,696 $ 21,891

Net loss attributable to EQT Corporation $ (163,000)

v3.24.3

Equitrans Midstream Merger - Unaudited Pro Forma Information (Details) - Equitrans Midstream Merger - USD ($)
$ / shares in Units, $ in Thousands
2 Months Ended 9 Months Ended

Sep. 30, 2024

Sep. 30, 2024

Sep. 30, 2023

Pro forma operating revenues:

Pro forma sales of natural gas, NGLs and oil $ 3,293,174 $ 3,680,566

Pro forma gain on derivatives 201,228 1,221,557

Pro forma pipeline, net marketing services and other 454,136 456,082

Pro forma total operating revenues 3,948,538 5,358,205

Pro forma net income 19,543 1,677,891

Less: Pro forma net income attributable to noncontrolling interests $ 3,687 17,696 21,891

Pro forma net income attributable to EQT Corporation $ 1,847 $ 1,656,000

Pro forma net income attributable to EQT Corporation – Basic (in dollars per share) $ 0.00 $ 4.49

Pro forma net income attributable to EQT Corporation – Diluted (in dollars per share) $ 0.00 $ 4.14

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Cover - shares shares in Thousands	9 Months Ended
Cover - shares shares in Thousands	Sep. 30, 2024	Oct. 25, 2024
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2024
Document Transition Report	false
Entity File Number	001-03551
Entity Registrant Name	EQT CORPORATION
Entity Incorporation, State or Country Code	PA
Entity Tax Identification Number	25-0464690
Entity Address, Street	625 Liberty Avenue
Entity Address, Suite	Suite 1700
Entity Address, City or Town	Pittsburgh
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	15222
City Area Code	412
Local Phone Number	553-5700
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	EQT
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		596,684
Entity Central Index Key	0000033213
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q3
Amendment Flag	false

STATEMENTS OF CONDENSED CONSOLIDATED OPERATIONS (UNAUDITED) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Operating revenues:
Gain on derivatives	$ 66,816	$ 177,906	$ 234,660	$ 1,167,144
Total operating revenues	1,283,802	1,186,102	3,648,582	4,865,924
Operating expenses:
Transportation and processing	440,845	554,788	1,529,093	1,592,934
Production	93,842	62,858	273,042	163,963
Operating and maintenance	40,518	4,235	65,824	6,108
Exploration	282	447	2,576	2,602
Selling, general and administrative	88,470	56,942	228,730	168,999
Depreciation, depletion and amortization	589,299	446,886	1,542,031	1,230,255
Loss (gain) on sale/exchange of long-lived assets	10,117	1,511	(309,865)	17,814
Impairment and expiration of leases	12,095	6,419	58,963	22,290
Other operating expenses	290,174	36,209	354,337	69,265
Total operating expenses	1,565,642	1,170,295	3,744,731	3,274,230
Operating (loss) income	(281,840)	15,807	(96,149)	1,591,694
(Income) loss from investments	(34,242)	546	(36,674)	(5,310)
Other income	(3,960)	(132)	(23,596)	(869)
Loss (gain) on debt extinguishment	365	1,089	5,651	(55)
Interest expense, net	158,299	60,427	268,390	146,856
(Loss) income before income taxes	(402,302)	(46,123)	(309,920)	1,451,072
Income tax (benefit) expense	(104,870)	(126,853)	(124,790)	217,975
Net (loss) income	(297,432)	80,730	(185,130)	1,233,097
Less: Net income (loss) attributable to noncontrolling interests	3,391	(525)	2,688	(80)
Net (loss) income attributable to EQT Corporation	$ (300,823)	$ 81,255	$ (187,818)	$ 1,233,177
(Loss) income per share of common stock attributable to EQT Corporation:
Weighted average common stock outstanding - Basic (in shares)	559,603	383,359	480,354	368,936
Net (loss) income attributable to EQT Corporation - Basic (in dollars per share)	$ (0.54)	$ 0.21	$ (0.39)	$ 3.34
Weighted average common stock outstanding - Diluted (in shares)	559,603	416,190	480,354	401,859
Net (loss) income attributable to EQT Corporation - Diluted (in dollars per share)	$ (0.54)	$ 0.20	$ (0.39)	$ 3.08
Sales of natural gas, NGLs and oil
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$ 1,099,752	$ 1,001,883	$ 3,293,174	$ 3,680,566
Pipeline, net marketing services and other
Operating revenues:
Pipeline, net marketing services and other	$ 117,234	$ 6,313	$ 120,748	$ 18,214

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 88,980	$ 80,977
Accounts receivable (less provision for doubtful accounts: $9,135 and $663)	577,599	823,695
Derivative instruments, at fair value	251,657	978,634
Income tax receivable	92,791	91,414
Prepaid expenses and other	71,265	38,255
Total current assets	1,082,292	2,012,975
Property, plant and equipment	44,884,752	33,817,169
Less: Accumulated depreciation and depletion	12,338,210	10,866,999
Net property, plant and equipment	32,546,542	22,950,170
Investment in the MVP Joint Venture	3,358,346	0
Net intangible assets	268,308	22,595
Goodwill	2,178,236	0
Other assets	511,865	299,358
Total assets	39,945,589	25,285,098
Current liabilities:
Current portion of debt	400,150	292,432
Accounts payable	1,042,393	1,272,522
Derivative instruments, at fair value	197,712	186,363
Accrued interest	189,965	80,520
Other current liabilities	283,730	205,003
Total current liabilities	2,113,950	2,036,840
Revolving credit facility borrowings	2,297,000	0
Term Loan Facility borrowings	497,970	1,244,265
Senior notes	10,598,428	4,176,180
Note payable to EQM Midstream Partners, LP	0	82,236
Deferred income taxes	2,746,292	1,904,821
Other liabilities and credits	1,203,631	1,059,939
Total liabilities	19,457,271	10,504,281
Equity:
Common stock, no par value, shares authorized: 1,280,000 and 640,000, shares issued: 596,268 and 419,896	18,076,243	12,093,986
Retained earnings	2,261,086	2,681,898
Accumulated other comprehensive loss	(2,570)	(2,684)
Total common shareholders' equity	20,334,759	14,773,200
Noncontrolling interest in consolidated subsidiaries	153,559	7,617
Total equity	20,488,318	14,780,817
Total liabilities and equity	$ 39,945,589	$ 25,285,098

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023
Statement of Financial Position [Abstract]
Provision for doubtful accounts	$ 9,135	$ 663
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, authorized shares (in shares)	1,280,000,000	640,000,000
Common stock, shares issued (in shares)	596,268,000	419,896,000

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Cash flows from operating activities:
Net (loss) income	$ (185,130)	$ 1,233,097
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Deferred income tax (benefit) expense	(123,725)	227,701
Depreciation, depletion and amortization	1,542,031	1,230,255
Gain/loss on sale/exchange of long-lived assets and impairments	(250,902)	40,104
Income from investments	(36,674)	(5,310)
Loss (gain) on debt extinguishment	5,651	(55)
Share-based compensation expense	141,578	38,179
Distributions from equity method investments	11,187	18,073
Other	13,160	12,022
Gain on derivatives	(234,660)	(1,167,144)
Net cash settlements received on derivatives	1,037,321	625,051
Net premiums paid on derivatives	(41,970)	(231,343)
Changes in other assets and liabilities:
Accounts receivable	331,452	1,122,843
Accounts payable	(122,252)	(515,879)
Other current assets	(10,150)	91,946
Other items, net	(6,220)	(165,076)
Net cash provided by operating activities	2,070,697	2,554,464
Cash flows from investing activities:
Capital expenditures	(1,662,112)	(1,485,898)
Cash paid for acquisitions	(864,242)	(2,288,201)
Proceeds from sale/exchange of assets	451,906	4,831
Capital contributions to equity method investments	(87,804)	(5,000)
Other investing activities	(80)	159
Net cash used in investing activities	(2,162,332)	(3,774,109)
Cash flows from financing activities:
Proceeds from revolving credit facility borrowings	3,578,000	313,000
Repayment of revolving credit facility borrowings	(2,316,000)	(313,000)
Proceeds from issuance of debt	750,000	1,250,000
Proceeds from net settlement of capped call transactions	93,290	0
Debt issuance costs	(18,854)	(5,336)
Repayment and retirement of debt	(1,655,706)	(1,014,346)
(Premiums paid) discounts received on debt extinguishment	(1,543)	5,313
Dividends paid	(232,603)	(162,567)
Repurchase and retirement of common stock	0	(201,029)
Net distribution to noncontrolling interest	(1,640)	(7,322)
Cash paid for taxes to net settle share-based incentive awards	(92,492)	(41,238)
Other financing activities	(2,814)	2,276
Net cash provided by (used in) financing activities	99,638	(174,249)
Net change in cash and cash equivalents	8,003	(1,393,894)
Cash and cash equivalents at beginning of period	80,977	1,458,644
Cash and cash equivalents at end of period	$ 88,980	$ 64,750

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2024
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes For the nine months ended September 30, 2024 and 2023, the Company calculated the provision for income taxes by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the nine months ended September 30, 2024. For the nine months ended September 30, 2024 and 2023, the Company recorded income tax (benefit) expense at an effective tax rate of 40.3% and 15.0%, respectively. The Company's effective tax rate for the nine months ended September 30, 2024 was higher compared to the U.S. federal statutory rate primarily as a result of recognition of tax benefits related to higher losses on the Company's state tax-paying entities and the utilization of some its capital loss carryforwards with the capital gain generated from the NEPA Non-Operated Asset Divestiture, which resulted in the release of the associated valuation allowance. The Company's effective tax rate for the nine months ended September 30, 2023 was lower compared to the U.S. federal statutory rate due primarily to the release of valuation allowances limiting certain state deferred tax assets and net state deferred tax benefits related to a rate reduction from a Pennsylvania tax law change enacted in July 2022 and the Tug Hill and XcL Midstream Acquisition.

Investment in the MVP Joint Venture	9 Months Ended
Investment in the MVP Joint Venture	Sep. 30, 2024
Equity Method Investments and Joint Ventures [Abstract]
Investment in the MVP Joint Venture	Investment in the MVP Joint Venture The MVP Joint Venture. Upon the closing of the Equitrans Midstream Merger, the Company acquired an equity method investment in the MVP Joint Venture. The MVP. The Company owned a 49.2% interest in the MVP as of September 30, 2024 and is the operator of the MVP. The MVP is a 303-mile long, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that spans from the Company's transmission and storage system in Wetzel County, West Virginia to Pittsylvania County, Virginia. Following receipt of authorization from the Federal Energy Regulatory Commission (the FERC), the MVP entered into service on June 14, 2024 and became available for interruptible or short-term firm transportation service. On July 1, 2024, the MVP commenced long-term firm capacity obligations. Estimated total project cost of the MVP is approximately $8.1 billion, excluding allowance for funds used during construction. As of September 30, 2024, the Company had a negative basis difference between the carrying value of its equity method investment and its proportionate share of the MVP's net assets, which are composed of fixed assets. The basis difference is accreted over the life of the fixed assets and presented in income from investments in the Company's Statements of Condensed Consolidated Operations. In September 2024, the MVP Joint Venture issued a capital call notice for the funding of the MVP project to the Company for $15.2 million, which was paid in October 2024. The capital contributions payable, which is presented in other current liabilities, and corresponding increase to the investment asset are included in the Condensed Consolidated Balance Sheet as of September 30, 2024. MVP Southgate. As of September 30, 2024, the Company owned a 47.2% interest in MVP Southgate. MVP Southgate is a contemplated interstate pipeline that was approved by the FERC and was initially designed to extend approximately 75 miles from the MVP in Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina using 24-inch and 16-inch diameter pipe. In December 2023, the MVP Joint Venture entered into precedent agreements with Public Service Company of North Carolina, Inc. and Duke Energy Carolinas, LLC. The precedent agreements contemplate an amended project and, among other things, describe certain conditions precedent to the parties' respective obligations regarding MVP Southgate. As amended, the natural gas interstate pipeline would extend approximately 31 miles from the terminus of the MVP in Pittsylvania County, Virginia to planned new delivery points in Rockingham County, North Carolina using 30-inch diameter pipe and have a targeted capacity of 550,000 dekatherms per day. Completion of the MVP Southgate pipeline is targeted for June 2028. The Company expects to operate the MVP Southgate pipeline. Pursuant to the MVP Joint Venture's limited liability company agreement and upon the closing of the Equitrans Midstream Merger, the Company is obligated to provide performance assurances with respect to MVP Southgate that may take the form of a guarantee from EQM (provided that, in accordance with the requirements of the MVP Joint Venture's limited liability company agreement, EQM's debt is assigned an investment grade credit rating), a letter of credit or cash collateral. Upon receipt of the FERC's initial release to begin construction of the MVP Southgate project, the Company will be obligated to provide performance assurance in an amount equal to 33% of its share of MVP Southgate's remaining capital commitments.

Share-based Compensation	9 Months Ended
Share-based Compensation	Sep. 30, 2024
Share-Based Payment Arrangement [Abstract]
Share-based Compensation	Share-based Compensation In 2024, the Management Development and Compensation Committee of the Company's Board of Directors (the Compensation Committee) adopted the 2024 Incentive Performance Share Unit Program (2024 Incentive PSU Program) under the 2020 Long-Term Incentive Plan. During the nine months ended September 30, 2024, a total of 371,500 share units were granted under the 2024 Incentive PSU Program. The payout of the share units will vary between zero and 200% of the number of outstanding units contingent upon the Company's absolute total shareholder return and total shareholder return relative to a predefined peer group over the period of January 1, 2024 through December 31, 2026. During the nine months ended September 30, 2024, the Compensation Committee granted 995,620 restricted stock unit equity awards that follow a three-year graded vesting schedule commencing with the date of grant, assuming continued employment through each vesting date. The share total includes the Company's "equity-for-all" program, instituted in 2021, pursuant to which the Company grants equity awards to all permanent employees. In conjunction with the Equitrans Midstream Merger, the Company assumed all outstanding and unvested share-based compensation awards of Equitrans Midstream Corporation (Equitrans Midstream) and converted those assumed awards into 5,175,814 restricted stock unit equity awards that maintained the assumed awards' prior vesting schedules, assuming continued employment through each vesting date.

Acquisitions and Divestitures	9 Months Ended
Acquisitions and Divestitures	Sep. 30, 2024
Business Combination, Asset Acquisition, and Joint Venture Formation [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures Tug Hill and XcL Midstream Acquisition. On August 22, 2023, the Company completed its acquisition (the Tug Hill and XcL Midstream Acquisition) of the upstream assets from THQ Appalachia I, LLC and the gathering and processing assets from THQ-XcL Holdings I, LLC through the acquisition of all of the issued and outstanding membership interests of each of THQ Appalachia I Midco, LLC and THQ-XcL Holdings I Midco, LLC. The purchase price for the Tug Hill and XcL Midstream Acquisition consisted of 49,599,796 shares of EQT common stock and approximately $2.4 billion in cash, subject to customary post-closing adjustments. The Company accounted for the Tug Hill and XcL Midstream Acquisition as a business combination using the acquisition method. The Company completed the purchase price allocation for the Tug Hill and XcL Midstream Acquisition during the first quarter of 2024. The purchase accounting adjustments recorded in 2024 were not material. NEPA Gathering System Acquisition. The Company operates and has historically owned a 50% interest in gathering assets located in Northeast Pennsylvania (collectively, the NEPA Gathering System). On April 11, 2024, the Company completed its acquisition of a minority equity partner's 33.75% interest in the NEPA Gathering System for a purchase price of approximately $205 million (the NEPA Gathering System Acquisition), subject to customary post-closing adjustments. The NEPA Gathering System Acquisition was accounted for as an asset acquisition and, as such, its purchase price was allocated to property, plant and equipment. NEPA Non-Operated Asset Divestiture. On May 31, 2024, the Company completed the divestiture (the NEPA Non-Operated Asset Divestiture) of an undivided 40% interest in the Company's non-operated natural gas assets in Northeast Pennsylvania with a carrying amount of approximately $522 million to Equinor USA Onshore Properties Inc. and its affiliates (collectively, the Equinor Parties). The carrying value was composed of approximately $549 million of property, plant and equipment, approximately $7 million of other current liabilities and approximately $20 million of other liabilities and credits. In exchange, as consideration, the Company received from the Equinor Parties cash of $500 million, subject to customary post-closing purchase price adjustments, certain upstream assets and the remaining 16.25% equity interest in the NEPA Gathering System. The total fair value of consideration received, net of liabilities assumed, was approximately $842 million, subject to customary post-closing purchase price adjustments, and included $413 million of property, plant and equipment. As a result of the NEPA Non-Operated Asset Divestiture, for the nine months ended September 30, 2024, the Company recognized a gain of approximately $312 million in loss (gain) on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations, inclusive of an $8 million loss recognized for the three months ended September 30, 2024. The gain was calculated as the carrying value of divested assets less the fair value of consideration received, net of liabilities assumed and divestiture costs incurred of approximately $8 million. Cash proceeds from the NEPA Non-Operated Asset Divestiture were used to partly fund EQT's redemption of its 6.125% senior notes. The fair values of the natural gas properties received as consideration for the NEPA Non-Operated Asset Divestiture were measured using discounted cash flow valuation techniques based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include future commodity prices, projections of estimated quantities of reserves, estimated future rates of production, projected reserve recovery factors, timing and amount of future development and operating costs and a weighted average cost of capital. The fair value of the undeveloped properties received as consideration for the NEPA Non-Operated Asset Divestiture were measured using the guideline transaction method based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include future development plans from a market participant perspective. The fair value of the interest in the NEPA Gathering System received as consideration for the NEPA Non-Operated Asset Divestiture was measured using the cost approach based on inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. Significant inputs include replacement cost for similar assets, relative age of the assets and potential economic or functional obsolescence. See Note 5 for a description of the fair value hierarchy. In addition, subsequent to the completion of the NEPA Non-Operated Asset Divestiture, the Company and the Equinor Parties entered into a gas buy-back agreement with respect to the assets received by the Company as consideration for the NEPA Non-Operated Asset Divestiture, whereby the Equinor Parties agreed to purchase a specified amount of natural gas from the Company through the first quarter of 2028. Remaining NEPA Non-Operated Assets Divestiture. On October 29, 2024, the Company entered into an agreement with the Equinor Parties, pursuant to which the Company agreed to sell to the Equinor Parties the Company's remaining, undivided 60% interest in the Company's non-operated natural gas assets in Northeast Pennsylvania. In exchange, the Company will receive from the Equinor Parties $1.25 billion of cash (the Remaining NEPA Non-Operated Assets Divestiture). The Company intends to use the proceeds from the Remaining NEPA Non-Operated Assets Divestiture for repayment of the Company's debt. The Remaining NEPA Non-Operated Assets Divestiture is subject to customary closing adjustments, required regulatory approvals and clearances.

Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Thousands	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Pay vs Performance Disclosure
Net Income (Loss)	$ (300,823)	$ 81,255	$ (187,818)	$ 1,233,177

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Sep. 30, 2024
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

Financial Statements (Policies)	9 Months Ended
Financial Statements (Policies)	Sep. 30, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation. The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all information and notes required by GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of the Company as of September 30, 2024 and December 31, 2023, the results of its operations and equity for the three and nine month periods ended September 30, 2024 and 2023 and its cash flows for the nine month periods ended September 30, 2024 and 2023. Certain previously reported amounts have been reclassified to conform to the current period presentation. In addition, as discussed further in Note 2, certain prior period amounts have been recast to reflect the Company's change in reportable segments from one reportable segment to three reportable segments consisting of Production, Gathering and Transmission.
Principles of Consolidation	Principles of Consolidation. The Condensed Consolidated Financial Statements include the accounts of EQT and all subsidiaries, ventures and partnerships in which EQT directly or indirectly holds a controlling interest. Intercompany accounts and transactions have been eliminated in consolidation.
Recently Issued Accounting Standards	Recently Issued Accounting Standards In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures to improve reportable segment disclosure requirements, primarily through the requirement of enhanced disclosure of significant segment expenses. In addition, this ASU enhances interim disclosure requirements, clarifies circumstances in which an entity can disclose multiple segment measures of profit or loss and provides new segment disclosure requirements for entities with a single reportable segment. This ASU is effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-07 to have a material impact on its currently-presented financial statements and related disclosures. In December 2023, the FASB issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures to improve its income tax disclosure requirements. Under this ASU, public business entities must annually (1) disclose specific categories in the rate reconciliation and (2) provide additional information for reconciling items that meet a quantitative threshold. This ASU is effective for fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company does not expect adoption of ASU 2023-09 to have a material impact on its financial statements and related disclosures.

Financial Statements - Narrative (Details)	2 Months Ended	7 Months Ended
Financial Statements - Narrative (Details)	Sep. 30, 2024 reportable_segment shares	Jul. 21, 2024 reportable_segment	Jul. 22, 2024	Jul. 18, 2024 shares	Jul. 17, 2024 shares	Dec. 31, 2023 shares	Sep. 30, 2023 shares
Subsequent Event [Line Items]
Number of reportable segments \| reportable_segment	3	1
Common stock, authorized shares (in shares) \| shares	1,280,000,000			1,280,000,000	640,000,000	640,000,000	640,000,000
Eureka Midstream Holdings L L C \| Variable Interest Entity, Primary Beneficiary
Subsequent Event [Line Items]
Ownership interest (in percent)			60.00%

Financial Information by Business Segment - Narrative (Details) $ in Millions		2 Months Ended	7 Months Ended
	Feb. 26, 2020 Bcf / d	Sep. 30, 2024 USD ($) business segment reportable_segment	Jul. 21, 2024 reportable_segment	Dec. 31, 2023 USD ($)
Operating segments information
Number of reportable segments \| reportable_segment		3	1
Number of operating segments \| segment		3
Number of lines of business \| business		3
Henry hub cash bonus
Operating segments information
Cash bonus payment period		36 months
Derivative liability \| $		$ 15		$ 48
EQT Producer
Operating segments information
Annual minimum volume (in Bcf per day) \| Bcf / d	3.0

Financial Information by Business Segment - Schedule of Segment Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023	Sep. 30, 2023
Segment assets:
Investment in the MVP Joint Venture	$ 3,358,346	$ 0
Goodwill	2,178,236	0
Other segment assets	34,409,007
Total assets	39,945,589	$ 25,285,098	$ 24,554,988
Operating Segments
Segment assets:
Investment in the MVP Joint Venture
Goodwill
Other segment assets
Total assets
Other and intersegment eliminations
Segment assets:
Investment in the MVP Joint Venture	0
Goodwill	888,477
Other segment assets	368,621
Total assets	1,257,098		248,869
Production \| Operating Segments
Segment assets:
Investment in the MVP Joint Venture	0
Goodwill	0
Other segment assets	22,890,299
Total assets	22,890,299		23,138,353
Gathering \| Operating Segments
Segment assets:
Investment in the MVP Joint Venture	0
Goodwill	0
Other segment assets	8,187,601
Total assets	8,187,601		$ 1,167,766
Transmission \| Operating Segments
Segment assets:
Investment in the MVP Joint Venture	3,358,346
Goodwill	1,289,759
Other segment assets	2,962,486
Total assets	$ 7,610,591

Derivative Instruments - Narrative (Details)	9 Months Ended			12 Months Ended
Derivative Instruments - Narrative (Details)	Sep. 30, 2024 USD ($) Bcf	Sep. 30, 2024 USD ($) MBbls	Sep. 30, 2024 USD ($)	Dec. 31, 2023 USD ($) Bcf	Dec. 31, 2023 USD ($) MBbls
Derivative Instruments, Gain (Loss)
Maximum additional collateral as percentage of derivative liability (in percent)			100.00%
Aggregate fair value of derivative instruments with credit-risk related contingencies	$ 0	$ 0	$ 0	$ 6,400,000	$ 6,400,000
Collateral posted	0	0	0	0	0
OTC Derivative Instrument Contracts
Derivative Instruments, Gain (Loss)
Aggregate fair value of derivative instruments with credit-risk related contingencies	0	0	0	0	0
Exchange traded natural gas contracts
Derivative Instruments, Gain (Loss)
Collateral posted	$ 17,500,000	$ 17,500,000	$ 17,500,000	$ 13,000,000	$ 13,000,000
Cash flow hedging \| Commodity derivatives
Derivative Instruments, Gain (Loss)
Volume of derivative instruments (in Bcf, Mbbls)	2,574	1,464		2,045	1,049

Derivative Instruments - Impact of Netting Agreements and Margin Deposits (Details) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023
Asset derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	$ 251,657	$ 978,634
Liability derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	197,712	186,363
Commodity derivatives
Asset derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	251,657	978,634
Derivative instruments subject to master netting agreements	(152,115)	(112,203)
Margin requirements with counterparties	0	0
Net derivative instruments	99,542	866,431
Liability derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	197,712	186,363
Derivative instruments subject to master netting agreements	(152,115)	(112,203)
Margin requirements with counterparties	(17,488)	(13,017)
Net derivative instruments	$ 28,109	$ 61,143

Fair Value Measurements - Derivative Instrument Assets and Liabilities Measured at Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	$ 251,657	$ 978,634
Liability derivative instruments, at fair value	197,712	186,363
Recurring \| Quoted prices in active markets for identical assets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	41,772	66,302
Liability derivative instruments, at fair value	17,402	42,218
Recurring \| Significant other observable inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	209,885	912,332
Liability derivative instruments, at fair value	180,310	144,145
Recurring \| Significant unobservable inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	0	0
Liability derivative instruments, at fair value	0	0
Recurring \| Fair value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	251,657	978,634
Liability derivative instruments, at fair value	$ 197,712	$ 186,363

Fair Value Measurements - Narrative (Details) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Net carrying value of convertible notes	$ 13,793,548	$ 5,795,113
Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Net carrying value of convertible notes	11,000,000	4,500,000
Senior Notes \| Significant other observable inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Estimated fair value of long-term debt	11,200,000	4,900,000
Notes payable to EQM \| Note payable to EQM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Net carrying value of convertible notes	$ 0	88,483
Notes payable to EQM \| Significant unobservable inputs (Level 3) \| Note payable to EQM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Estimated fair value of long-term debt		$ 91,000

Income Taxes (Details)	9 Months Ended
Income Taxes (Details)	Sep. 30, 2024	Sep. 30, 2023
Income Tax Disclosure [Abstract]
Effective income tax expense (in percent)	40.30%	15.00%

Debt - Debt Instrument Redemption (Details) - USD ($) $ in Thousands	Sep. 30, 2024	Dec. 31, 2023	Apr. 30, 2020
Senior Notes
Debt Instrument [Line Items]
Principal	$ 1,652,104
Premiums	1,178
Accrued but Unpaid Interest	19,944
Total Cost	$ 1,673,226
EQM 4.00% notes due August 1, 2024 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	4.00%	4.00%
Principal	$ 300,000
Premiums	0
Accrued but Unpaid Interest	6,000
Total Cost	$ 306,000
6.125% notes due February 1, 2025 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	6.125%	6.125%
Principal	$ 601,521
Premiums	1,178
Accrued but Unpaid Interest	13,612
Total Cost	616,311
Term Loan Facility due June 30, 2025 \| Loans Payable
Debt Instrument [Line Items]
Principal	750,000
Premiums	0
Accrued but Unpaid Interest	332
Total Cost	$ 750,332
1.75% convertible notes due May 1, 2026 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	1.75%	1.75%	1.75%
Principal	$ 583
Premiums	0
Accrued but Unpaid Interest	0
Total Cost	$ 583

Debt - Narrative (Details)							1 Months Ended				2 Months Ended	3 Months Ended		9 Months Ended
Debt - Narrative (Details)	Jul. 22, 2024 USD ($) extension	Jan. 22, 2024 USD ($)	Jan. 19, 2024 USD ($)	Jan. 17, 2024 USD ($)	Jan. 12, 2024 USD ($) shares	Aug. 21, 2023 USD ($)	Jan. 31, 2024 USD ($) $ / shares shares	Jan. 17, 2024	Sep. 30, 2023	Apr. 30, 2020 USD ($) $ / shares	Sep. 30, 2024 USD ($)	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)
Line of Credit Facility
Repayments of long-term debt														$ 1,655,706,000	$ 1,014,346,000
Debt instrument, face amount											$ 13,852,877,000	$ 13,852,877,000		13,852,877,000		$ 5,836,058,000
Debt issuance costs														18,854,000	5,336,000
Issuance of EQT Corporation common stock for Convertible Notes settlement													$ 16,000	285,608,000	98,000
Aggregate proceeds from capped call termination payment														93,290,000	0
Call Option
Line of Credit Facility
Aggregate proceeds from capped call termination payment		$ 93,300,000
Senior Notes
Line of Credit Facility
Long-term maturity, remainder of fiscal year											0	0		0
Long-term maturity, year one											400,000,000	400,000,000		400,000,000
Long-term debt, maturity, year two											500,000,000	500,000,000		500,000,000
Long-term debt, maturity, year three											1,400,000,000	1,400,000,000		1,400,000,000
Long-term debt, maturity, year four											850,000,000	850,000,000		850,000,000
Long-term debt, maturity, year five											1,400,000,000	1,400,000,000		1,400,000,000
Long-term debt, maturity, after year five											2,150,000,000	$ 2,150,000,000		$ 2,150,000,000
Strike price (in dollars per share) \| $ / shares										$ 15.00
Capped price (in dollars per share) \| $ / shares										$ 18.75
Senior Notes \| Call Option
Line of Credit Facility
Capped call transaction										$ 32,500,000
EQM Term Loan Facility \| Notes payable to EQM \| Equitrans Midstream
Line of Credit Facility
Repayments of long-term debt	$ 705,000,000
Payments of interest and fees	4,500,000
Term Loan Facility Due June 2025 \| Loans Payable
Line of Credit Facility
Proceeds from issuance of debt						$ 1,250,000,000
Proceeds from debt, net of issuance costs						$ 1,242,900,000
Term Loan Facility due June 30, 2025 \| Loans Payable
Line of Credit Facility
Weighted average interest rates (percent)									7.00%			6.90%		6.90%
Repayments of long-term debt			$ 750,000,000
Debt instrument, face amount											$ 500,000,000	$ 500,000,000		$ 500,000,000		$ 1,250,000,000
EQT's 5.750% notes due February 1, 2034 \| Senior Notes
Line of Credit Facility
Interest rate, stated percentage (in percent)			5.75%								5.75%	5.75%		5.75%		5.75%
Debt instrument, face amount			$ 750,000,000								$ 750,000,000	$ 750,000,000		$ 750,000,000		$ 0
Proceeds from issuance of debt			742,000,000
Debt issuance costs			$ 8,000,000
1.75% convertible notes due May 1, 2026 \| Senior Notes
Line of Credit Facility
Interest rate, stated percentage (in percent)										1.75%	1.75%	1.75%		1.75%		1.75%
Debt instrument, face amount										$ 500,000,000	$ 0	$ 0		$ 0		$ 290,177,000
Effective interest rate (in percent)				2.40%				2.40%
Conversion ratio					0.0690364
Debt principal redeemed				$ 600,000
Convertible Debt Settled January 2024 \| Senior Notes
Line of Credit Facility
Redemption price (percent)								100.00%
Debt conversion, converted instrument, amount					$ 289,600,000
Shares issued (in shares) \| shares					19,992,482
Issuance of EQT Corporation common stock for Convertible Notes settlement					$ 285,600,000
Convertible Debt Settled January 2024, Including Exercise Notices Received In December 2023 \| Senior Notes
Line of Credit Facility
Debt conversion, converted instrument, amount							$ 290,200,000
Shares issued (in shares) \| shares							20,036,639
Debt instrument, convertible, average conversion price (in USD per share) \| $ / shares							$ 38.03
Revolving credit facility \| EQT Fourth A& R Revolving Credit Facility
Line of Credit Facility
Line of credit facility, maximum borrowing capacity	$ 3,500,000,000										3,500,000,000	3,500,000,000		3,500,000,000
Number of extensions \| extension	2
Extension term	1 year
Commitment amount	$ 1,000,000,000
Letters of credit outstanding under revolving credit facility											1,000,000	1,000,000		1,000,000		$ 15,000,000
Maximum amount of outstanding short-term loans at any time during the period												2,301,000,000	158,000,000	2,301,000,000	158,000,000
Average daily balance of short-term loans outstanding during the period												$ 1,608,000,000	$ 28,000,000	$ 551,000,000	$ 9,000,000
Weighted average interest rates (percent)												6.90%	6.90%	6.90%	6.90%
Revolving credit facility \| EQT Fourth A& R Revolving Credit Facility \| SOFR
Line of Credit Facility
Credit spread adjustment (percent)	0.10%
Revolving credit facility \| EQT Fourth A& R Revolving Credit Facility \| Minimum \| Base Rate
Line of Credit Facility
Basis spread on variable rate (percent)	0.125%
Revolving credit facility \| EQT Fourth A& R Revolving Credit Facility \| Minimum \| SOFR
Line of Credit Facility
Basis spread on variable rate (percent)	1.125%
Revolving credit facility \| EQT Fourth A& R Revolving Credit Facility \| Maximum \| Base Rate
Line of Credit Facility
Basis spread on variable rate (percent)	1.00%
Revolving credit facility \| EQT Fourth A& R Revolving Credit Facility \| Maximum \| SOFR
Line of Credit Facility
Basis spread on variable rate (percent)	2.00%
Revolving credit facility \| Eureka Revolving Credit Facility
Line of Credit Facility
Line of credit facility, maximum borrowing capacity											400,000,000	$ 400,000,000		$ 400,000,000
Letters of credit outstanding under revolving credit facility											0	$ 0		$ 0
Maximum amount of outstanding short-term loans at any time during the period											330,000,000
Average daily balance of short-term loans outstanding during the period											$ 330,000,000
Weighted average interest rates (percent)											8.10%

Investment in the MVP Joint Venture - Narrative (Details) Dekatherm in Thousands, $ in Millions	1 Months Ended		9 Months Ended
	Sep. 30, 2024 USD ($) mi in	Dec. 31, 2023 Dekatherm mi in	Sep. 30, 2024 Bcf / d mi in	Jul. 01, 2024 USD ($)
MVP Joint Venture
Schedule of Equity Method Investments [Line Items]
Capital call notice \| $	$ 15.2
MVP Joint Venture \| Alamance County, North Carolina
Schedule of Equity Method Investments [Line Items]
Pipeline diameter (in inches)	16		16
MVP Joint Venture \| Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Natural gas interstate pipeline (in miles) \| mi	303		303
Pipeline diameter (in inches)	42		42
Annual minimum volume (in Bcf per day) \| Bcf / d			2.0
Estimated total project costs, excluding allowance for funds used \| $				$ 8,100.0
MVP Joint Venture \| MVP Southgate Project
Schedule of Equity Method Investments [Line Items]
Pipeline diameter (in inches)		30
Annual minimum volume (in Bcf per day) \| Dekatherm		550
MVP Joint Venture \| MVP Southgate Project \| Pittsylvania
Schedule of Equity Method Investments [Line Items]
Natural gas interstate pipeline (in miles) \| mi	75	31	75
MVP Joint Venture \| MVP Southgate Project \| Rockingham County, North Carolina
Schedule of Equity Method Investments [Line Items]
Pipeline diameter (in inches)	24		24
MVP Joint Venture \| Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Ownership percentage (percent)	49.20%		49.20%
MVP Joint Venture \| MVP Southgate Project
Schedule of Equity Method Investments [Line Items]
Ownership percentage (percent)	47.20%		47.20%
Remaining capital obligation, percentage		33.00%

Share-based Compensation (Details) - shares	9 Months Ended
Share-based Compensation (Details) - shares	Sep. 30, 2024	Jul. 22, 2024
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award
Shares granted (in shares)	995,620
Vesting period	3 years
Restricted Stock Units (RSUs) \| Equitrans Midstream Merger
Share-based Compensation Arrangement by Share-based Payment Award
Outstanding shares (in shares)		5,175,814
Incentive Performance Share Unit Program \| Performance shares
Share-based Compensation Arrangement by Share-based Payment Award
Shares granted (in shares)	371,500
Incentive Performance Share Unit Program \| Performance shares \| Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Payout percentage (in percent)	0.00%
Incentive Performance Share Unit Program \| Performance shares \| Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Payout percentage (in percent)	200.00%

Acquisitions and Divestitures - Narrative (Details) - USD ($) $ in Thousands					3 Months Ended	9 Months Ended
	Oct. 29, 2024	May 31, 2024	Apr. 11, 2024	Aug. 22, 2023	Sep. 30, 2024	Sep. 30, 2024	Sep. 30, 2023	Apr. 10, 2024	Dec. 31, 2023
Business Acquisition [Line Items]
Cash payments to acquire business						$ 864,242	$ 2,288,201
6.125% notes due February 1, 2025 \| Senior Notes
Business Acquisition [Line Items]
Interest rate, stated percentage (in percent)					6.125%	6.125%			6.125%
NEPA Non Operated Asset Divestiture \| Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition [Line Items]
Percentage of natural gas asset interest sold (percent)		40.00%
Carrying amount of divestiture		$ 522,000
Property, plant and equipment, carrying value		549,000
Other current liabilities, carrying value		7,000
Other liabilities, carrying value		20,000
Proceeds from sale of oil and gas property and equipment		$ 500,000
Equity interest to be received upon disposal (percent)		16.25%
Gain (loss) on sale of long-lived assets					$ (8,000)	$ 312,000
Divestiture cost						$ 8,000
NEPA Non Operated Asset Divestiture \| Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Subsequent Event
Business Acquisition [Line Items]
Percentage of natural gas asset interest sold (percent)	60.00%
Proceeds from divestiture of interest	$ 1,250,000
NEPA Non Operated Asset Divestiture \| Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Fair value \| Significant unobservable inputs (Level 3)
Business Acquisition [Line Items]
Fair value of consideration received, net of liabilities assumed		$ 842,000
Property plant and equipment		$ 413,000
Tug Hill and XcL Midstream
Business Acquisition [Line Items]
Equity interest issued or issuable, number of shares (in shares)				49,599,796
Cash payments to acquire business				$ 2,400,000
NEPA Gathering System Acquisition
Business Acquisition [Line Items]
Percentage of operates and owns interest (percent)								50.00%
Ownership interest acquired (percent)			33.75%
Consideration to be paid			$ 205,000

Equitrans Midstream Merger (Details) $ / shares in Units, $ in Thousands		3 Months Ended	9 Months Ended
	Jul. 22, 2024 USD ($) $ / shares shares	Sep. 30, 2024 USD ($)	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)
Business Combination, Separately Recognized Transactions [Line Items]
Equity issued as consideration for acquisition			$ 5,548,608	$ 2,152,631
Equitrans Midstream Merger
Business Combination, Separately Recognized Transactions [Line Items]
Number of shares issuable for each existing share converted (in shares)	0.3504
Equity interest issued or issuable, number of shares (in shares) \| shares	152,427,848
Equity issued as consideration for acquisition	$ 5,548,608
Share price (in dollars per share) \| $ / shares	$ 35.88
Purchase and redemption price	$ 685,337
Proxy, transaction and reorganization		$ 274,600	$ 298,700
Intangible asset, useful life	15 years
Goodwill attributed to synergies expected from the vertical integration of the business	$ 1,300,000
Goodwill attributable to additional tax liabilities arising from the difference between preliminary purchase price allocation and tax basis	900,000
Goodwill tax deductible amount	647,200
Equitrans Midstream Merger \| Employees Of Equitrans Midstream
Business Combination, Separately Recognized Transactions [Line Items]
Equity issued as consideration for acquisition	$ 79,500

Commitment and Contingencies - Schedule of Purchase Commitment (Details) - USD ($) $ in Billions	Sep. 30, 2024	Dec. 31, 2023
Demand Charge Payments \| Pipeline Demand Charges
Long-Term Purchase Commitment [Line Items]
Other commitment, to be paid, remainder of fiscal year	$ 0.2
Other commitment, to be paid, year one	0.8	$ 1.8
Other commitment, to be paid, year two	0.7	1.8
Other commitment, to be paid, year three	0.7	1.7
Other commitment, to be paid, year four	0.6	1.7
Other commitment, to be paid, after year four	4.2
Other commitment, to be paid, year five		1.4
Other commitment, to be paid, after year five		13.6
Total	7.2	22.0
Services and Materials Payment Commitment \| Frac Sand and Equipment
Long-Term Purchase Commitment [Line Items]
Other commitment, to be paid, remainder of fiscal year	60.7
Other commitment, to be paid, year one	194.6	228.8
Other commitment, to be paid, year two	148.4	164.5
Other commitment, to be paid, year three	88.2	138.0
Other commitment, to be paid, year four	37.9	111.0
Other commitment, to be paid, after year four	0.0
Other commitment, to be paid, year five		72.9
Other commitment, to be paid, after year five		107.9
Total	$ 529.8	$ 823.1