EQT Corporation - 10-Q quarterly report FY2026 Q2

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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 JUNE 30, 2026

☐

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.)

2200 Energy Drive
Canonsburg, Pennsylvania						15317
(Address of principal executive offices)						(Zip Code)

(412) 553-5700

(Registrant's telephone number, including area code)

625 Liberty Avenue, Suite 1700, Pittsburgh, PA 15222

(Former name, former address and former fiscal year, if changed since last report)

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 July 14, 2026: 625,516

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED OPERATIONS (UNAUDITED)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands, except per share amounts)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,610,014	$	1,700,499	$	5,049,949	$	3,945,226
Gain (loss) on derivatives	44,640		719,964		(193,629)		41,045
Pipeline and other	155,286		137,256		332,356		311,298
Total operating revenues	1,809,940		2,557,719		5,188,676		4,297,569
Operating expenses:
Transportation and processing	385,017		389,116		785,356		767,325
Production	100,316		91,518		215,494		179,956
Operating and maintenance	60,220		53,983		115,088		101,280
Selling, general and administrative	106,438		81,586		202,189		173,050
Depreciation, depletion and amortization	689,592		623,471		1,344,384		1,244,246
Loss on sale/exchange of long-lived assets	3,577		2,990		3,552		3,221
Impairment and expiration of leases	6,232		3,254		10,055		5,915
Other operating expenses	64,510		177,763		82,560		192,288
Total operating expenses	1,415,902		1,423,681		2,758,678		2,667,281
Operating income	394,038		1,134,038		2,429,998		1,630,288
Income from investments	(44,732)		(67,174)		(122,241)		(93,636)
Other income	(3,404)		(2,616)		(3,522)		(3,239)
Loss on debt extinguishment	341		5,889		29,869		17,569
Interest expense, net	75,452		105,668		172,229		223,237
Income before income taxes	366,381		1,092,271		2,353,663		1,486,357
Income tax expense	84,933		235,615		518,285		314,283
Net income	281,448		856,656		1,835,378		1,172,074
Less: Net income attributable to noncontrolling interests	70,023		72,509		136,724		145,788
Net income attributable to EQT Corporation	$	211,425	$	784,147	$	1,698,654	$	1,026,286

Income per share of common stock attributable to EQT Corporation:
Basic:
Weighted average common stock outstanding	625,962		599,221		625,549		598,574
Net income attributable to EQT Corporation	$	0.34	$	1.31	$	2.72	$	1.71
Diluted (Note 10):
Weighted average common stock outstanding	629,049		602,924		629,070		602,896
Net income attributable to EQT Corporation	$	0.34	$	1.30	$	2.70	$	1.70

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands)
Net income	$	281,448	$	856,656	$	1,835,378	$	1,172,074
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax benefit (expense) of $38, $53, $(140) and $82	106		54		400		91
Comprehensive income	281,554		856,710		1,835,778		1,172,165
Less: Comprehensive income attributable to noncontrolling interests	70,023		72,509		136,724		145,788
Comprehensive income attributable to EQT Corporation	$	211,531	$	784,201	$	1,699,054	$	1,026,377

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	June 30, 2026		December 31, 2025

	(Thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	112,863	$	110,795
Accounts receivable (less allowance for credit losses: $3,844 and $3,088)	835,140		1,457,959
Derivative instruments, at fair value	138,943		202,390
Prepaid expenses and other	90,881		124,007
Total current assets	1,177,827		1,895,151

Property, plant and equipment	49,741,567		48,472,497
Less: Accumulated depreciation and depletion	16,188,972		14,914,689
Net property, plant and equipment	33,552,595		33,557,808

Investments in unconsolidated entities	3,946,497		3,630,577
Net intangible assets	193,100		200,486
Goodwill	2,062,462		2,062,462
Other assets	388,359		446,390
Total assets	$	41,320,840	$	41,792,874

LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	114,959	$	507,119
Accounts payable	1,166,963		1,367,431
Derivative instruments, at fair value	50,106		137,299
Accrued interest	103,785		137,505
Other current liabilities	314,466		335,487
Total current liabilities	1,750,279		2,484,841

Revolving credit facility borrowings	324,000		360,000
Senior notes	5,216,755		6,933,209
Deferred income taxes	3,963,965		3,472,010
Asset retirement obligations and other liabilities	1,202,444		1,182,666
Total liabilities	12,457,443		14,432,726

Equity:
Common stock, no par value, shares authorized: 1,280,000, shares issued: 625,513 and 624,076	19,529,362		19,517,761
Retained earnings	5,731,287		4,237,089
Accumulated other comprehensive loss	(1,773)		(2,173)
Total common shareholders' equity	25,258,876		23,752,677
Noncontrolling interests in consolidated subsidiaries	3,604,521		3,607,471
Total equity	28,863,397		27,360,148
Total liabilities and equity	$	41,320,840	$	41,792,874

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED)


	Six Months Ended June 30,
	2026		2025

	(Thousands)
Cash flows from operating activities:
Net income	$	1,835,378	$	1,172,074
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax expense	491,617		304,878
Depreciation, depletion and amortization	1,344,384		1,244,246
Loss on sale/exchange of long-lived assets	3,552		3,221
Impairment and expiration of leases	10,055		5,915
Income from investments	(122,241)		(93,636)
Loss on debt extinguishment	29,869		17,569
Share-based compensation expense	42,381		28,535
Distributions from equity method investments	121,323		132,881
Other	10,509		3,358
Loss (gain) on derivatives	193,629		(41,045)
Net cash settlements paid on derivatives	(231,048)		(193,350)

Changes in other assets and liabilities:
Accounts receivable	629,685		295,699
Accounts payable	(209,653)		10,253
Income tax receivable and payable	25,320		97,378
Other current assets	8,611		(1,459)
Other items, net	(80,312)		(3,651)
Net cash provided by operating activities	4,103,059		2,982,866
Cash flows from investing activities:
Capital expenditures	(1,248,676)		(1,049,289)
Cash paid for acquisitions	—		(100,167)
Net cash received (paid) for sale/exchange of assets	91		(6,284)
Cash paid for acquisitions of additional interests in equity method investments	(216,209)		—
Capital contributions to equity method investments	(56,520)		(42,047)
Other investing activities	(2,221)		(245)
Net cash used in investing activities	(1,523,535)		(1,198,032)
Cash flows from financing activities:
Proceeds from revolving credit facility borrowings	2,461,000		2,234,000
Repayment of revolving credit facility borrowings	(2,497,000)		(2,422,800)

Debt issuance costs	—		(7,238)
Repayment and retirement of debt	(2,122,944)		(813,017)
Net premiums paid on debt extinguishment	(22,631)		(24,802)
Dividends paid	(206,278)		(188,372)
Contribution from noncontrolling interests	98,357		—
Distributions to noncontrolling interests	(238,031)		(151,954)
Cash paid for taxes to net settle share-based incentive awards	(46,135)		(53,253)
Other financing activities	(3,794)		(3,999)
Net cash used in financing activities	(2,577,456)		(1,431,435)
Net change in cash and cash equivalents	2,068		353,399
Cash and cash equivalents at beginning of period	110,795		202,093
Cash and cash equivalents at end of period	$	112,863	$	555,492

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		Noncontrolling Interests in Consolidated Subsidiaries		Total Equity

	(Thousands, except per share amounts)
Balance at April 1, 2025	598,586	$	17,984,118	$	2,736,046	$	(2,284)	$	3,685,389	$	24,403,269
Comprehensive income, net of tax:
Net income				784,147				72,509		856,656
Other postretirement benefits liability adjustment, net of tax benefit of $53						54				54
Dividends ($0.1575 per share)				(94,461)						(94,461)
Share-based compensation plans	226	15,640								15,640
Distributions to noncontrolling interests								(83,308)		(83,308)

Balance at June 30, 2025	598,812	$	17,999,758	$	3,425,732	$	(2,230)	$	3,674,590	$	25,097,850

Balance at April 1, 2026	625,475	$	19,497,503	$	5,623,137	$	(1,879)	$	3,668,288	$	28,787,049
Comprehensive income, net of tax:
Net income				211,425				70,023		281,448
Other postretirement benefits liability adjustment, net of tax benefit of $38						106				106
Dividends ($0.165 per share)				(103,275)						(103,275)
Share-based compensation plans	38	31,859								31,859

Distributions to noncontrolling interests								(133,790)		(133,790)
Balance at June 30, 2026	625,513	$	19,529,362	$	5,731,287	$	(1,773)	$	3,604,521	$	28,863,397

For all periods presented, there were 3 million preferred shares authorized and no preferred shares issued or outstanding.

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)


	Common Stock
	Shares	Amount		Retained Earnings		Accumulated Other Comprehensive Loss		Noncontrolling Interests in Consolidated Subsidiaries		Total Equity

	(Thousands, except per share amounts)
Balance at January 1, 2025	596,870	$	18,014,711	$	2,585,238	$	(2,321)	$	3,680,508	$	24,278,136
Comprehensive income, net of tax:
Net income				1,026,286				145,788		1,172,074
Other postretirement benefits liability adjustment, net of tax benefit of $82						91				91
Dividends ($0.315 per share)				(185,792)						(185,792)
Share-based compensation plans	1,942	(15,328)								(15,328)
Distributions to noncontrolling interests								(151,954)		(151,954)
Other		375						248		623
Balance at June 30, 2025	598,812	$	17,999,758	$	3,425,732	$	(2,230)	$	3,674,590	$	25,097,850

Balance at January 1, 2026	624,076	$	19,517,761	$	4,237,089	$	(2,173)	$	3,607,471	$	27,360,148
Comprehensive income, net of tax:
Net income				1,698,654				136,724		1,835,378
Other postretirement benefits liability adjustment, net of tax expense of $(140)						400				400
Dividends ($0.33 per share)				(204,456)						(204,456)
Share-based compensation plans	1,437	11,601								11,601
Contribution from noncontrolling interests								98,357		98,357
Distributions to noncontrolling interests								(238,031)		(238,031)
Balance at June 30, 2026	625,513	$	19,529,362	$	5,731,287	$	(1,773)	$	3,604,521	$	28,863,397

For all periods presented, there were 3 million preferred shares authorized and no preferred shares issued or outstanding.

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

Table of Contents

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 company with upstream, gathering and transmission 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 to EQT Corporation and its consolidated subsidiaries, collectively, 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 Company's financial position as of June 30, 2026 and December 31, 2025, results of operations and changes in equity for the three and six months ended June 30, 2026 and 2025 and cash flows for the six months ended June 30, 2026 and 2025.

The Condensed Consolidated Balance Sheet at December 31, 2025 has been derived from the audited financial statements at that date. For further information, refer to the Consolidated Financial Statements and accompanying notes in EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

Principles of Consolidation and Noncontrolling Interests. The Condensed Consolidated Financial Statements include the accounts of EQT and all subsidiaries, ventures and partnerships in which EQT directly or indirectly owns a controlling interest and variable interest entities for which EQT is the primary beneficiary. Intercompany accounts and transactions have been eliminated in consolidation. The Company records noncontrolling interests in its Condensed Consolidated Financial Statements for any non-wholly owned consolidated subsidiary. See Note 9 for additional information on the Company's consolidation of the Midstream Joint Venture (defined in Note 9) and the allocation of the Midstream Joint Venture's income.

Reclassification. Certain previously reported amounts have been reclassified to conform to the current period's presentation. In addition, as discussed further in Note 2, effective December 31, 2025, the Company renamed its previously reported "Production" segment as the "Upstream" segment.

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.


	Six Months Ended June 30,
	2026		2025

	(Thousands)
Cash paid (received) during the period for:
Interest, net of amount capitalized	$	196,470	$	241,824
Income taxes, net	(280)		(78,931)

Non-cash activity during the period for:
Increase in asset retirement costs and obligations	$	25,103	$	15,185
Capitalization of non-cash equity share-based compensation	15,355		9,389
Right-of-use assets obtained in exchange for lease liabilities	8,782		5,095
Investments in unconsolidated entities	—		17,981

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Recently Issued Accounting Standards

In May 2026, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2026-02, Environmental Credits and Environmental Credit Obligations (Topic 818), to establish a new accounting model for environmental credits and related obligations, including guidance on their recognition, measurement, presentation and disclosure. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2027, including interim reporting periods within those annual periods. Early adoption is permitted. The Company is evaluating the impact ASU 2026-02 will have on its financial statements and related disclosures.

In December 2025, the FASB issued ASU 2025-12, Codification Improvements, to clarify guidance, correct technical errors, remove outdated language and improve consistency across various topics in the Accounting Standards Codification. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2026, including interim reporting periods within those annual periods. Early adoption is permitted. The Company is evaluating the impact ASU 2025-12 will have on its financial statements and related disclosures and does not expect its adoption to be material.

In December 2025, the FASB issued ASU 2025-11, Interim Reporting (Topic 270): Narrow-Scope Improvements, to clarify the scope and presentation requirements for interim GAAP financial statements and to consolidate interim disclosure requirements. Under this ASU, entities must disclose material events or changes occurring after year end that affect interim periods. The amendments in this ASU are effective for interim reporting periods within annual reporting periods beginning after December 15, 2027. Early adoption is permitted. The amendments may be applied either prospectively or retrospectively to any or all prior periods presented in the financial statements. The Company is evaluating the impact ASU 2025-11 will have on its financial statements and related disclosures.

In November 2024, the FASB issued ASU 2024-03, Disaggregation of Income Statement Expenses, to improve the disclosures about a public business entity's expenses and address requests from investors for more detailed information about the types of expenses (including purchases of inventory, employee compensation, depreciation, amortization and depletion) in commonly presented expense captions (such as cost of sales; selling, general and administrative expense; and research and development). This ASU is effective for annual reporting periods beginning after December 15, 2026 and interim reporting periods beginning after December 15, 2027. Early adoption is permitted. The requirements should be applied prospectively with the option for retrospective application. The Company is evaluating the impact ASU 2024-03 will have on its financial statements and related disclosures.

2. Financial Information by Business Segment

The Company has three reportable segments consisting of Upstream, Gathering and Transmission.

Effective December 31, 2025, the Company renamed its previously reported "Production" segment as the "Upstream" segment to better align with the nature of the Company's operations and the Company's internal reporting framework. This change had no impact on the structure of the Company's internal organization, including the composition of its reportable segments.

The Company's Upstream segment comprises the Company's natural gas, natural gas liquids (NGLs) and oil extraction, development and production business and supporting operations. The Company's Gathering segment owns and operates the Company's gathering system, which has extensive overlap with the Company's Upstream segment operations, and processing facility. The Company's Transmission segment operates the Company's Federal Energy Regulatory Commission (FERC) regulated interstate transmission and storage system, which has multiple interconnect points to other interstate pipelines and local distribution companies. In addition, the Company's investment in the MVP Joint Venture (defined in Note 8) is reported in its Transmission segment.

The accounting policies of the Company's segments are the same as those described in Note 1 to the Consolidated Financial Statements in EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

Items that are managed on a consolidated basis, including cash and cash equivalents, debt, income taxes and amounts related to the Company's corporate function, and items related to the Company's energy transition initiatives have not been allocated to the Company's reportable segments. These items are presented as "Other."

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

The Company's chief operating decision maker (the CODM), Toby Z. Rice, President and Chief Executive Officer, evaluates performance of, and allocates resources to, the Company's reportable segments using a profitability metric of operating income. The CODM compares each segment's operating income and return on assets when evaluating performance of the Company's reportable segments and considers actual-to-forecast variances in operating income when allocating capital and personnel to the Company's reportable segments. For the Company's Transmission segment, the CODM also reviews equity earnings recognized from, and the carrying value of, the Company's investment in the MVP Joint Venture.

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

Total segment operating income. The following tables present information about segment revenue, segment profit or loss and significant segment expenses and include a reconciliation of total segment amounts to the Company's consolidated totals.


	Three Months Ended June 30, 2026
	Upstream		Gathering		Transmission		Total Segment		Intersegment Eliminations and Other		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,610,014	$	—	$	—	$	1,610,014	$	—	$	1,610,014
Gain on derivatives	44,640		—		—		44,640		—		44,640
Pipeline and other	8,979		341,328		141,165		491,472		(336,186)		155,286
Total operating revenues	1,663,633		341,328		141,165		2,146,126		(336,186)		1,809,940
Operating expenses (a):
Transportation and processing	721,207		—		—		721,207		(336,190)		385,017
Production	100,316		—		—		100,316		—		100,316
Operating and maintenance	—		47,102		13,118		60,220		—		60,220
Selling, general and administrative	62,028		21,352		8,361		91,741		14,697		106,438
Depreciation, depletion and amortization	603,465		56,134		23,708		683,307		6,285		689,592
Loss (gain) on sale/exchange of long-lived assets	2,860		—		725		3,585		(8)		3,577
Impairment and expiration of leases	6,232		—		—		6,232		—		6,232
Other operating expenses	58,142		—		2,250		60,392		4,118		64,510
Total operating expenses	1,554,250		124,588		48,162		1,727,000		(311,098)		1,415,902
Operating income (loss)	$	109,383	$	216,740	$	93,003	$	419,126	$	(25,088)	$	394,038

(a)The significant expense categories and amounts presented align with information that is regularly provided to the CODM.

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


	Three Months Ended June 30, 2025
	Upstream		Gathering		Transmission		Total Segment		Intersegment Eliminations and Other		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,700,499	$	—	$	—	$	1,700,499	$	—	$	1,700,499
Gain on derivatives	719,964		—		—		719,964		—		719,964
Pipeline and other	79		320,269		134,583		454,931		(317,675)		137,256
Total operating revenues	2,420,542		320,269		134,583		2,875,394		(317,675)		2,557,719
Operating expenses (a):
Transportation and processing	706,139		—		—		706,139		(317,023)		389,116
Production	91,518		—		—		91,518		—		91,518
Operating and maintenance	—		40,597		13,386		53,983		—		53,983
Selling, general and administrative	46,708		12,921		8,107		67,736		13,850		81,586
Depreciation, depletion and amortization	540,918		54,032		22,732		617,682		5,789		623,471
Loss on sale/exchange of long-lived assets	2,688		—		302		2,990		—		2,990
Impairment and expiration of leases	3,254		—		—		3,254		—		3,254
Other operating expenses (b)	22,207		7,314		—		29,521		148,242		177,763
Total operating expenses	1,413,432		114,864		44,527		1,572,823		(149,142)		1,423,681
Operating income (loss)	$	1,007,110	$	205,405	$	90,056	$	1,302,571	$	(168,533)	$	1,134,038

(a)The significant expense categories and amounts presented align with information that is regularly provided to the CODM.

(b)Corporate other operating expenses consisted primarily of a legal reserve related to a securities class action settlement.

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


	Six Months Ended June 30, 2026
	Upstream		Gathering		Transmission		Total Segment		Intersegment Eliminations and Other		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	5,049,949	$	—	$	—	$	5,049,949	$	—	$	5,049,949
Loss on derivatives	(193,629)		—		—		(193,629)		—		(193,629)
Pipeline and other	13,752		676,303		302,617		992,672		(660,316)		332,356
Total operating revenues	4,870,072		676,303		302,617		5,848,992		(660,316)		5,188,676
Operating expenses (a):
Transportation and processing	1,445,686		—		—		1,445,686		(660,330)		785,356
Production	215,494		—		—		215,494		—		215,494
Operating and maintenance	—		89,213		25,875		115,088		—		115,088
Selling, general and administrative	117,076		40,098		16,039		173,213		28,976		202,189
Depreciation, depletion and amortization	1,171,171		111,949		48,703		1,331,823		12,561		1,344,384
Loss (gain) on sale/exchange of long-lived assets	2,835		—		725		3,560		(8)		3,552
Impairment and expiration of leases	10,055		—		—		10,055		—		10,055
Other operating expenses	72,096		35		2,250		74,381		8,179		82,560
Total operating expenses	3,034,413		241,295		93,592		3,369,300		(610,622)		2,758,678
Operating income (loss)	$	1,835,659	$	435,008	$	209,025	$	2,479,692	$	(49,694)	$	2,429,998

(a)The significant expense categories and amounts presented align with information that is regularly provided to the CODM.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


	Six Months Ended June 30, 2025
	Upstream		Gathering		Transmission		Total Segment		Intersegment Eliminations and Other		EQT Corporation

	(Thousands)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	3,945,226	$	—	$	—	$	3,945,226	$	—	$	3,945,226
Gain on derivatives	41,045		—		—		41,045		—		41,045
Pipeline and other	3,554		655,582		280,854		939,990		(628,692)		311,298
Total operating revenues	3,989,825		655,582		280,854		4,926,261		(628,692)		4,297,569
Operating expenses (a):
Transportation and processing	1,394,739		—		—		1,394,739		(627,414)		767,325
Production	179,956		—		—		179,956		—		179,956
Operating and maintenance	—		76,906		24,374		101,280		—		101,280
Selling, general and administrative	95,378		28,318		17,526		141,222		31,828		173,050
Depreciation, depletion and amortization	1,084,412		103,456		45,935		1,233,803		10,443		1,244,246
Loss on sale/exchange of long-lived assets	2,872		—		349		3,221		—		3,221
Impairment and expiration of leases	5,915		—		—		5,915		—		5,915
Other operating expenses (b)	27,657		10,296		(536)		37,417		154,871		192,288
Total operating expenses	2,790,929		218,976		87,648		3,097,553		(430,272)		2,667,281
Operating income (loss)	$	1,198,896	$	436,606	$	193,206	$	1,828,708	$	(198,420)	$	1,630,288

(a)The significant expense categories and amounts presented align with information that is regularly provided to the CODM.

(b)Corporate other operating expenses consisted primarily of a legal reserve related to a securities class action settlement.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Reconciliation of total segment operating income to consolidated income before income taxes.


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands)
Total segment operating income	$	419,126	$	1,302,571	$	2,479,692	$	1,828,708
Less:
Intersegment eliminations	—		687		—		1,389
Unallocated amounts:
Other revenues	(4)		(35)		(14)		(111)
Corporate selling, general and administrative	14,697		13,850		28,976		31,828
Corporate depreciation and amortization	6,285		5,789		12,561		10,443
Corporate other operating expenses (a)	4,118		148,242		8,179		154,871
Income from investments (b)	(44,732)		(67,174)		(122,241)		(93,636)
Other income	(3,404)		(2,616)		(3,522)		(3,239)
Loss on debt extinguishment	341		5,889		29,869		17,569
Interest expense, net	75,452		105,668		172,229		223,237
Income before income taxes	$	366,381	$	1,092,271	$	2,353,663	$	1,486,357

(a)For the three and six months ended June 30, 2025, corporate other operating expenses consisted primarily of a legal reserve related to a securities class action settlement.

(b)Income from investments included equity earnings from the Company's investment in the MVP Joint Venture of $45.0 million and $41.6 million for the three months ended June 30, 2026 and 2025, respectively, and $101.2 million and $66.0 million for the six months ended June 30, 2026 and 2025, respectively.

Total segment assets. The following table presents information about segment assets. The Company's investment in the MVP Joint Venture is presented in investments in unconsolidated entities in the Condensed Consolidated Balance Sheets.


	Upstream		Gathering		Transmission		Total Segment

	(Thousands)
June 30, 2026
Investment in the MVP Joint Venture	$	—	$	—	$	3,802,793	$	3,802,793
Goodwill	—		—		1,231,783		1,231,783
Other segment assets	23,398,395		8,837,023		2,841,484		35,076,902
Total assets	$	23,398,395	$	8,837,023	$	7,876,060	$	40,111,478

June 30, 2025
Investment in the MVP Joint Venture	$	—	$	—	$	3,503,025	$	3,503,025
Goodwill	—		—		1,231,783		1,231,783
Other segment assets	22,027,485		8,276,505		2,900,334		33,204,324
Total assets	$	22,027,485	$	8,276,505	$	7,635,142	$	37,939,132

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Reconciliation of total segment assets to consolidated total assets.


	June 30,
	2026		2025

	(Thousands)
Total segment assets	$	40,111,478	$	37,939,132
Intersegment eliminations	(222,688)		(256,941)
Unallocated amounts:
Cash and cash equivalents	112,863		555,492
Other property, plant and equipment, at cost less accumulated depreciation	120,168		103,687
Goodwill	830,679		830,679
Other	368,340		494,699
Total assets	$	41,320,840	$	39,666,748

Total segment capital expenditures. The following table presents information about segment capital expenditures.


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands)
Upstream	$	472,423	$	449,440	$	971,681	$	858,195
Gathering	171,586		86,083		263,040		158,187
Transmission	7,822		10,291		18,933		22,918
Total segment capital expenditures	651,831		545,814		1,253,654		1,039,300
Other corporate items	14,427		7,745		20,440		11,703
Total capital expenditures	$	666,258	$	553,559	$	1,274,094	$	1,051,003

3. Revenue from Contracts with Customers

Sales of natural gas, NGLs and oil. Under the Company's natural gas, 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. These performance obligations are satisfied at a point in time upon delivery to the designated sales point, at which time control transfers to the customer. 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 reports the revenue on a net basis.

Pipeline revenue. The Company provides gathering, transmission and storage services under firm and interruptible service contracts. Firm service contracts generally require the customer to pay a firm reservation fee, which is a fixed, monthly fee to reserve an agreed-upon amount of pipeline or storage capacity regardless of whether the customer uses the capacity. The Company recognizes firm reservation fee revenue evenly over the contract period as it satisfies its stand-ready obligation to provide capacity. Revenue from volumetric-based fees is recognized as services are performed based on volumes gathered, transported or stored, and the amount invoiced generally corresponds to the value of the Company's performance. Interruptible service contracts require the customer to pay volumetric-based fees and generally do not guarantee access to the pipeline or storage facility. Certain gathering agreements include minimum volume commitments (MVCs), for which revenue is recognized when the performance obligation is satisfied.

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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 and other revenues in the Statements of Condensed Consolidated Operations. Derivative contracts are also outside the scope of ASU 2014-09.


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands)
Revenues from contracts with customers:
Upstream sales
Natural gas	$	1,424,315	$	1,539,205	$	4,678,665	$	3,589,155
NGLs	152,906		145,104		310,015		318,920
Oil	32,793		16,190		61,269		37,151
Sales of natural gas, NGLs and oil	1,610,014		1,700,499		5,049,949		3,945,226

Gathering pipeline revenue
Firm reservation fees	171,030		169,597		334,112		336,288
Volumetric-based fees	170,298		150,672		342,191		319,294
Total Gathering pipeline revenue	341,328		320,269		676,303		655,582

Transmission pipeline revenue
Firm reservation fees	106,220		96,535		232,847		214,387
Volumetric-based fees	34,945		38,048		69,770		66,467
Total Transmission pipeline revenue	141,165		134,583		302,617		280,854

Intersegment eliminations and other	(336,186)		(317,675)		(660,316)		(628,692)
Total revenues from contracts with customers (a)	1,756,321		1,837,676		5,368,553		4,252,970

Other sources of revenue:
Gain (loss) on derivatives	44,640		719,964		(193,629)		41,045
Other revenues	8,979		79		13,752		3,554
Total other sources of revenue	53,619		720,043		(179,877)		44,599

Total operating revenues	$	1,809,940	$	2,557,719	$	5,188,676	$	4,297,569

(a)For revenue from contracts with customers for which the Company had satisfied its performance obligations and held an unconditional right to consideration, the Company recorded accounts receivable of $673.4 million and $1,159.0 million as of June 30, 2026 and December 31, 2025, respectively.

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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 June 30, 2026.


	2026 (a)		2027		2028		2029		2030		Thereafter		Total

	(Thousands)
Upstream natural gas sales	$	6,863	$	7,540	$	—	$	—	$	—	$	—	$	14,403

Gathering firm reservation fee revenue:
Third-party	47,078		86,260		86,260		86,260		86,260		288,112		680,230
Affiliate	50,927		101,508		97,701		97,701		103,978		1,403,698		1,855,513
Total	98,005		187,768		183,961		183,961		190,238		1,691,810		2,535,743

Gathering revenues from MVCs:
Third-party	51,765		96,926		87,901		74,032		63,236		140,649		514,509
Affiliate	206,989		410,621		411,740		410,622		408,323		1,634,129		3,482,424
Total	258,754		507,547		499,641		484,654		471,559		1,774,778		3,996,933

Transmission firm reservation fee revenue:
Third-party	90,284		178,467		172,539		169,923		166,411		662,365		1,439,989
Affiliate	132,082		262,637		260,776		260,445		260,445		1,704,604		2,880,989
Total	222,366		441,104		433,315		430,368		426,856		2,366,969		4,320,978

Total remaining performance obligations	$	585,988	$	1,143,959	$	1,116,917	$	1,098,983	$	1,088,653	$	5,833,557	$	10,868,057

(a)July 1 through December 31.

As of June 30, 2026, based on total projected contractual revenues, the Company's firm gathering contracts had weighted average remaining terms of approximately 10 years for third-party contracts and 12 years for affiliate contracts.

As of June 30, 2026, based on total projected contractual revenues, the Company's firm transmission and storage contracts had weighted average remaining terms of approximately 10 years for third-party contracts and 12 years for affiliate contracts.

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 New York Mercantile Exchange (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 (loss) 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. See Note 5 for a description of the fair value hierarchy and the valuation techniques and significant inputs used to estimate the fair value of the Company's derivative instruments.

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 900 billion cubic feet (Bcf) of natural gas and 4,615 thousand barrels (Mbbl) of NGLs as of June 30, 2026 and approximately 945 Bcf of natural gas and 4,022 Mbbl of NGLs as of December 31, 2025. The open positions at both June 30, 2026 and December 31, 2025 had maturities extending through December 2030.

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 June 30, 2026, 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 June 30, 2026 and December 31, 2025, the aggregate fair value of the Company's OTC derivative instruments with credit rating risk-related contingent features in a net liability position was $2.4 million and $4.4 million, respectively, for which no deposits were required or recorded in the Condensed Consolidated Balance Sheets.

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 June 30, 2026 and December 31, 2025, 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 June 30, 2026 and December 31, 2025, there was $22.9 million and $36.8 million, respectively, of such deposits recorded as a current asset 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)
June 30, 2026
Asset derivative instruments, at fair value	$	138,943	$	(27,447)	$	—	$	111,496
Liability derivative instruments, at fair value	50,106		(27,447)		(22,931)		(272)

December 31, 2025
Asset derivative instruments, at fair value	$	202,390	$	(79,250)	$	—	$	123,140
Liability derivative instruments, at fair value	137,299		(79,250)		(36,810)		21,239

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 and, when not available, valuation models that incorporate market-based inputs, including forward price curves, discount rates, volatilities and counterparty non-performance risk. 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)
June 30, 2026
Asset derivative instruments, at fair value	$	138,943	$	6,141	$	132,802	$	—
Liability derivative instruments, at fair value	50,106		8,450		41,656		—

December 31, 2025
Asset derivative instruments, at fair value	$	202,390	$	43,200	$	159,190	$	—
Liability derivative instruments, at fair value	137,299		39,164		98,135		—

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 and Eureka Midstream, LLC's (Eureka) revolving credit facilities 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 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 June 30, 2026 and December 31, 2025, the Company's senior notes had a fair value of approximately $5.4 billion and $7.7 billion, respectively, and a carrying value of approximately $5.3 billion and $7.4 billion, respectively, inclusive of any current portion. See Note 7 for further discussion of the Company's debt.

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 8 for a discussion of the fair value measurement of the Company's investment in the Investment Fund (defined in Note 8). See Note 1 to the Consolidated Financial Statements in EQT's Annual Report on Form 10-K for the year ended December 31, 2025 for a discussion of the fair value measurement and impairment assessments of the Company's property, plant and equipment, investments in unconsolidated entities, net intangible assets, goodwill and asset retirement obligations.

6. Income Taxes

For the six months ended June 30, 2026 and 2025, the Company calculated its 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. Any refinements to prior period taxes made in the current period due to new information are reflected as adjustments in the current period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the six months ended June 30, 2026.

The Midstream Joint Venture and Eureka Midstream Holdings, LLC (Eureka Holdings) are treated as partnerships for tax purposes. As a result, income attributable to noncontrolling interests is included in pre-tax income but not subject to income tax expense, which impacts the Company's effective tax rate.

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

For the six months ended June 30, 2026 and 2025, the Company recorded income tax expense at an effective tax rate of 22.0% and 21.1%, respectively. The Company's effective tax rate for the six months ended June 30, 2026 was higher compared to the U.S. federal statutory rate primarily as a result of state taxes net of valuation allowances, partly offset by income attributable to noncontrolling interests. The Company's effective tax rate for the six months ended June 30, 2025 was higher compared to the U.S. federal statutory rate primarily as a result of state taxes, partly offset by income attributable to noncontrolling interests and excess tax benefits from share-based payments.

7. Debt

The table below summarizes the Company's outstanding debt.


	June 30, 2026				December 31, 2025
	Principal Value		Carrying Value (a)		Principal Value		Carrying Value (a)

	(Thousands)
EQT's revolving credit facility maturing July 23, 2030	$	52,000	$	52,000	$	75,000	$	75,000
Eureka's revolving credit facility maturing November 13, 2027	272,000		272,000		285,000		285,000
EQT's senior notes and debentures:
3.125% notes due May 15, 2026	—		—		392,915		392,409
7.75% debentures due July 15, 2026	115,000		114,959		115,000		114,710
6.500% notes due July 1, 2027	—		—		344,921		346,255
3.900% notes due October 1, 2027	533,809		533,191		936,158		934,640
5.700% notes due April 1, 2028	500,000		496,037		500,000		494,905
5.500% notes due July 15, 2028	45,225		45,120		45,225		45,060
5.00% notes due January 15, 2029	318,494		316,780		318,494		316,448
4.50% notes due January 15, 2029	299,560		291,457		734,583		710,802
6.375% notes due April 1, 2029	48,989		49,447		596,725		602,840
7.000% notes due February 1, 2030 (b)	674,800		672,573		674,800		672,263
7.500% notes due June 1, 2030	494,086		519,593		494,086		522,749
4.75% notes due January 15, 2031	1,090,218		1,048,674		1,090,218		1,044,098
3.625% notes due May 15, 2031	435,165		431,834		435,165		431,496
5.750% notes due February 1, 2034	750,000		743,986		750,000		743,589
6.500% notes due July 15, 2048	67,196		68,063		67,196		68,064
Total debt	5,696,542		5,655,714		7,855,486		7,800,328
Less: Current portion of debt (c)	115,000		114,959		507,915		507,119
Long-term debt	$	5,581,542	$	5,540,755	$	7,347,571	$	7,293,209

(a)For EQT's and Eureka's revolving credit facilities, the principal value represents carrying value. For all other debt, the principal value less any applicable unamortized debt issuance costs, debt discounts and fair value adjustments represents carrying value.

(b)Interest rates for 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. For all other senior notes, interest rates do not fluctuate.

(c)As of June 30, 2026, the current portion of debt included EQT's 7.75% debentures. As of December 31, 2025, the current portion of debt included EQT's 3.125% senior notes and 7.75% debentures.

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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 six months ended June 30, 2026.


Debt Tranche	Principal		Premiums Paid (Discounts Received)		Accrued but Unpaid Interest		Total Cost

	(Thousands)
6.500% notes due July 1, 2027 (a)	$	344,921	$	5,695	$	5,293	$	355,909
3.900% notes due October 1, 2027 (b)	402,349		(2,350)		7,628		407,627
4.50% notes due January 15, 2029 (b)	435,023		(309)		3,861		438,575
6.375% notes due April 1, 2029 (b)	547,736		17,550		16,974		582,260
3.125% notes due May 15, 2026 (c)	392,915		—		6,139		399,054
Total	$	2,122,944	$	20,586	$	39,895	$	2,183,425

(a)On March 10, 2026, the Company issued a notice of full redemption to holders of EQT's outstanding 6.500% senior notes due July 1, 2027, and, on March 26, 2026, the Company redeemed such notes in full.

(b)On March 10, 2026, the Company announced the commencement of a tender offer to purchase for cash (the Tender Offer) certain of its outstanding senior notes. On March 26, 2026, the Company settled the Tender Offer, repurchasing approximately $1.4 billion aggregate principal amount of EQT's senior notes.

(c)Repaid at maturity.

On July 15, 2026, the Company repaid 115 million aggregate principal amount of EQT's 7.75% debentures at maturity.

EQT's Revolving Credit Facility. EQT has a $3.5 billion revolving credit facility.

As of both June 30, 2026 and December 31, 2025, the Company had approximately $2 million of letters of credit outstanding under EQT's revolving credit facility.

During the three months ended June 30, 2026 and 2025, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $462 million and $512 million, respectively, the average daily balance was approximately $155 million and $64 million, respectively, and interest was incurred at a weighted average annual interest rate of 5.2% and 5.9%, respectively. During the six months ended June 30, 2026 and 2025, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $530 million and $566 million, respectively, the average daily balance was approximately $128 million and $136 million, respectively, and interest was incurred at a weighted average annual interest rate of 5.2% and 5.9%, respectively. For all periods presented, EQT incurred commitment fees of 20 basis points on the undrawn portion of its revolving credit facility.

As of June 30, 2026, EQT was in compliance with all provisions and covenants of the credit agreement governing EQT's revolving credit facility.

Eureka's Revolving Credit Facility. Through its controlling interest in Eureka Holdings, the Company consolidates Eureka's $400 million senior secured revolving credit facility.

As of both June 30, 2026 and December 31, 2025, Eureka had no letters of credit outstanding under its revolving credit facility.

During the three months ended June 30, 2026 and 2025, under Eureka's revolving credit facility, the maximum amount of outstanding borrowings was $272 million and $285 million, respectively, the average daily balance was approximately $270 million and $284 million, respectively, and interest was incurred at a weighted average annual interest rate of 6.4% and 7.1%, respectively. During the six months ended June 30, 2026 and 2025, under Eureka's revolving credit facility, the maximum amount of outstanding borrowings was $285 million and $321 million, respectively, the average daily balance was approximately $276 million and $297 million, respectively, and interest was incurred at a weighted average annual interest rate of 6.4% and 7.1%, respectively.

As of June 30, 2026, Eureka was in compliance with all provisions and covenants of the credit agreement governing Eureka's revolving credit facility.

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

8. Investments in Unconsolidated Entities

Equity Method Investments

The table below summarizes the Company's equity method investments.


	June 30, 2026				December 31, 2025
	Ownership Interest		Carrying Value		Ownership Interest		Carrying Value
			(Thousands)				(Thousands)
MVP Joint Venture (a):
MVP A	53.2	%	$	3,289,264	49.3	%	$	3,097,754
MVP B	47.2	%	114,086		47.2	%	42,420
MVP C	53.2	%	399,443		49.3	%	374,629
Total MVP Joint Venture			3,802,793				3,514,803

Laurel Mountain Midstream, LLC (b)	31.0	%	46,932		31.0	%	47,037
Other			48,389				35,724
Total			$	3,898,114			$	3,597,564

(a)Mountain Valley Pipeline, LLC (the MVP Joint Venture) is a Delaware series limited liability company formed as a joint venture for the purpose of constructing and owning natural gas assets. The MVP Joint Venture has three series, as follows (with each term defined below): MVP A, which owns MVP Mainline; MVP B, which owns MVP Southgate; and MVP C, which owns certain assets associated with MVP Boost. A wholly owned subsidiary of the Company serves as the operator for each series of the MVP Joint Venture.

(b)Laurel Mountain Midstream, LLC is a midstream company formed as a joint venture among the Company, The Williams Companies, Inc. and certain other energy companies for the purpose of owning and operating gathering and processing assets.

MVP A. Series A of the MVP Joint Venture (MVP A) was formed for the purpose of constructing and owning the Mountain Valley Pipeline (MVP Mainline). As of June 30, 2026, MVP A's members consisted of the Midstream Joint Venture and affiliates of each of NextEra Energy, Inc. (NextEra), AltaGas Ltd. (AltaGas), RGC Resources, Inc. (RGC) and VED NPI IV, LLC (Vega). See "MVP A and MVP C Interest Acquisitions" below for a discussion of changes in ownership interests that occurred during the first quarter of 2026.

MVP Mainline is a 303-mile long, 42-inch diameter natural gas interstate pipeline with a total 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. MVP Mainline is in service and regulated by the FERC.

MVP B. Series B of the MVP Joint Venture (MVP B) was formed for the purpose of constructing and owning the MVP Southgate project (MVP Southgate). As of June 30, 2026, MVP B's members consisted of the Company and affiliates of NextEra, AltaGas and RGC.

MVP Southgate is an interstate pipeline project that is expected to extend approximately 31 miles from the terminus of MVP Mainline in Pittsylvania County, Virginia to planned new delivery points in Rockingham County, North Carolina using 30-inch diameter pipe, with a projected capacity of 0.55 Bcf per day.

The FERC authorized the MVP Joint Venture to proceed with construction of the MVP Southgate facilities in Virginia on March 23, 2026 and in North Carolina on June 18, 2026. MVP Southgate is expected to be placed into service by mid-2028. MVP Southgate is estimated to have a total cost of approximately $370 million to $430 million, excluding allowance for funds used during construction (AFUDC) and certain costs incurred for the originally certificated project. The Company will fund its proportionate share through capital contributions to MVP B.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Under the MVP Joint Venture's limited liability company agreement (the MVP LLC Agreement), the Company is required to provide performance assurance to fund its proportionate share of the construction budget for MVP Southgate. Under the MVP LLC Agreement, acceptable forms of performance assurance include a guarantee from the Company, a letter of credit or cash collateral. In July 2025, the Company issued a performance guarantee in favor of MVP B in the amount of $14.2 million. As a result of the FERC's March 23, 2026 authorization to proceed with construction of the MVP Southgate facilities in Virginia, the Company's existing performance guarantee was terminated and replaced with a new performance assurance equal to 33% of the Company's proportionate share of the remaining capital commitments under the most recently approved construction budget. Accordingly, in April 2026, the Company issued a new performance guarantee in favor of MVP B in the amount of $38.2 million.

MVP C. Series C of the MVP Joint Venture (MVP C) was formed on November 1, 2025 for the purpose of constructing and owning certain assets associated with the MVP Boost project (MVP Boost). As of June 30, 2026, MVP C's members consisted of the Company and affiliates of NextEra, AltaGas, RGC and Vega. See "MVP A and MVP C Interest Acquisitions" below for a discussion of changes in ownership interests that occurred during the first quarter of 2026.

MVP Boost is a contemplated project to add compression to MVP Mainline. MVP Boost is projected to increase the capacity on MVP Mainline by 0.6 Bcf per day. As designed, MVP Boost would add compression at three existing compressor stations in West Virginia and construct a new compressor station in Montgomery County, Virginia.

On October 23, 2025, the MVP Joint Venture filed an application with the FERC for authorization to construct MVP Boost. Pending receipt of regulatory approvals, MVP Boost is expected to be placed into service by mid-2028. MVP Boost is estimated to have a total cost of approximately $400 million to $540 million, excluding AFUDC. The Company will fund its proportionate share through capital contributions to MVP C.

Under the MVP LLC Agreement, the Company is required to provide performance assurance to fund its proportionate share of the construction budget for MVP Boost. Under the MVP LLC Agreement, acceptable forms of performance assurance include a guarantee from the Company, a letter of credit or cash collateral. In November 2025, the Company issued a performance guarantee in favor of MVP C in the amount of $14.8 million. In April 2026, as a result of the MVP C Interest Acquisition (defined below), the Company amended its existing performance guarantee, increasing the amount to $16.0 million. Following the FERC's initial authorization to proceed with construction of MVP Boost, the Company's existing performance guarantee will be terminated and the Company will be required to provide a new performance assurance equal to 33% of the Company's proportionate share of the remaining capital commitments under the most recently approved construction budget.

MVP A and MVP C Interest Acquisitions. On March 30, 2026, the Company completed its acquisition of an approximately 3.94% interest in MVP A (the MVP A Interest Acquisition) and an approximately 3.94% interest in MVP C (the MVP C Interest Acquisition and, together with the MVP A Interest Acquisition, the MVP A and MVP C Interest Acquisitions) from an affiliate of Con Edison Gas Pipeline and Storage, LLC (ConEd) pursuant to a preferential buy-out right under the MVP LLC Agreement. Total consideration, excluding transaction costs, was $213.9 million, consisting of $198.3 million for the MVP A Interest Acquisition, of which $98.4 million was funded by the BXCI Affiliate (defined in Note 9), and $15.6 million for the MVP C Interest Acquisition. The Company funded its share of the consideration for the MVP A and MVP C Interest Acquisitions with cash on hand. The MVP A and MVP C Interest Acquisitions increased the Company's unamortized basis differences, a portion of which is amortized in the Statements of Condensed Consolidated Operations.

In January 2026, NextEra completed its acquisition of an approximately 2.66% interest in each of MVP A and MVP C from ConEd pursuant to a similar preferential buy-out right under the MVP LLC Agreement. Following these acquisitions, ConEd is no longer a member of MVP A or MVP C.

Investments in Equity Securities

The Investment Fund. The Company holds an investment in a fund (the Investment Fund) that invests in companies that develop technology and operating solutions for exploration and production companies. As of June 30, 2026 and December 31, 2025, the fair value of the Company's investment in the Investment Fund was approximately $48 million and $33 million, respectively, and is presented in investments in unconsolidated entities in the Condensed Consolidated Balance Sheets. The Company computes the fair value of the Company's investment in the Investment Fund using, as a practical expedient, the net asset value provided in the financial statements received from fund managers.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

9. Midstream Joint Venture

PipeBox LLC (the Midstream Joint Venture) is a consolidated subsidiary of the Company in which Blackstone Credit & Insurance (the BXCI Affiliate) holds a noncontrolling interest. As of June 30, 2026, the Midstream Joint Venture's assets included approximately 950 miles of FERC-regulated interstate pipelines, the Hammerhead Pipeline System (a gathering header pipeline that connects production in Pennsylvania and West Virginia to MVP Mainline and other interstate pipelines) and a 53.2% ownership interest in MVP A.

Pursuant to the amended and restated limited liability company agreement of the Midstream Joint Venture (the JV Agreement), the Midstream Joint Venture is required to distribute available cash flow to its members at least quarterly. Under the JV Agreement, available cash flow is distributed 60% to the BXCI Affiliate (as the holder of the Class B units in the Midstream Joint Venture) and 40% to the Company (as the holder of Class A units in the Midstream Joint Venture) until the BXCI Affiliate achieves the Base Return (as defined in the JV Agreement).

During the six months ended June 30, 2026, the Midstream Joint Venture paid distributions of $238.0 million to the BXCI Affiliate. Distributions from the Midstream Joint Venture to the Company are eliminated in consolidation. As of June 30, 2026, the remaining amount required to achieve the Base Return was approximately $3.4 billion.

Based on the provisions of the JV Agreement, the Company allocates the Midstream Joint Venture's net income between the Company and the BXCI Affiliate based on changes in each member's claim on the Midstream Joint Venture's book value. The Company recognizes net income attributable to the noncontrolling interest based on the amounts that each member would hypothetically receive at the balance sheet date under the JV Agreement's liquidation provisions, assuming that the net assets of the Midstream Joint Venture were liquidated at their recorded amounts and after taking into account any capital transactions between the Company and the BXCI Affiliate.

MVP A Interest Acquisition. As discussed in Note 8, the Company completed the MVP A Interest Acquisition for total consideration of $198.3 million, excluding transaction costs, which was funded by the Midstream Joint Venture's members in proportion to each member's existing ownership interests in the Midstream Joint Venture through capital contributions. The BXCI Affiliate's capital contribution of $98.4 million is presented in contribution from noncontrolling interests in the Condensed Consolidated Financial Statements. In connection with such funding, the Midstream Joint Venture issued additional Class A units to the Company, as the Class A unitholder, and Class B units to the BXCI Affiliate, as the Class B unitholder, to maintain the members' relative ownership percentages. The capital contributions increased the BXCI Affiliate's claim on the Midstream Joint Venture's book value and, as a result, increased the remaining amount required to achieve the Base Return.

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

10. Income Per Share

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


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands, except per share amounts)
Net income attributable to EQT Corporation – Basic and diluted income available to shareholders	$	211,425	$	784,147	$	1,698,654	$	1,026,286

Weighted average common stock outstanding – Basic	625,962		599,221		625,549		598,574
Stock options, restricted stock and performance awards (a)	3,087		3,703		3,521		4,322
Weighted average common stock outstanding – Diluted	629,049		602,924		629,070		602,896

Income per share of common stock attributable to EQT Corporation:
Basic	$	0.34	$	1.31	$	2.72	$	1.71
Diluted	$	0.34	$	1.30	$	2.70	$	1.70

(a)Excludes securities that would have had an antidilutive effect on diluted income per share, which had a weighted average, in thousands, of 2,611 and 744 for the three months ended June 30, 2026 and 2025, respectively, and 1,311 and 570 for the six months ended June 30, 2026 and 2025, respectively. Such antidilutive securities included the stock options described in Note 11, which have exercise prices exceeding the average stock price of EQT common stock.

11. Share-Based Compensation Plans

Effective April 27, 2026, the Management Development and Compensation Committee of the Company's Board of Directors granted an aggregate total of 3,650,000 non-qualified stock options to EQT's executive officers under the EQT Corporation 2020 Long-Term Incentive Plan. The grant of stock options to each executive officer was allocated equally to three separate tranches, with each tranche having a strike price (i.e., an exercise price) set at a significant premium to the then-current market value of EQT common stock (specifically, the exercise price for these tranches was set at $90, $95 and $100 per share). Subject to the conditions set forth in the option award agreement, the three tranches vest and become exercisable on the third, fourth and fifth anniversary of the grant date, with the option award agreement expiring on April 27, 2033. Consistent with the objectives of the Company's executive compensation program, these stock options were designed to further align executive long-term incentive compensation opportunity with the long-term interests of the Company's shareholders and to support the retention of the Company's executive officers.

The fair value of the Company's stock option grants was estimated at the grant date using a lattice option-pricing model. The key assumptions used in the valuation are summarized in the table below.


	Option Tranche 1		Option Tranche 2		Option Tranche 3
Shares granted	1,216,667		1,216,667		1,216,666
Years to vesting	3		4		5
Stock price at grant date	$	58.64	$	58.64	$	58.64
Strike price	$	90.00	$	95.00	$	100.00





Expected term in years	6.46		6.65		6.81
Grant date fair value per share	$	20.51	$	20.20	$	19.80

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EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Across all three tranches, the valuation used the same blended volatility (45.86%), risk-free rate (4.09%) and dividend yield (1.09%). Expected volatility was based on an equal blend of the Company's historical and implied volatility. The risk-free rate was based on the U.S. Treasury yield curve in effect at the grant date. The dividend yield was based on the Company's three-month average expected dividend rate.

The aggregate grant-date fair value of the awards was $73.6 million. The Company recognized $3.4 million of compensation cost related to this grant during the three and six months ended June 30, 2026 and expects to recognize $70.2 million of unrecognized compensation cost over a weighted average remaining period of 3.8 years.

12. Blackline Midstream Acquisition

On July 21, 2026, the Company completed its acquisition (the Blackline Midstream Acquisition) of all of the operating subsidiaries of Blackline Midstream, LLC, an owner and operator of liquefied propane gas storage, distribution and marine terminal facilities and associated assets on the Piscataqua River in Newington, New Hampshire and Providence, Rhode Island. The purchase price for the Blackline Midstream Acquisition was approximately $77 million, subject to customary post-closing purchase price adjustments. The Company funded the consideration with borrowings under EQT's revolving credit facility.

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EQT CORPORATION AND SUBSIDIARIES

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 EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

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. 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" in Item 2., "Management's Discussion and Analysis of Financial Condition and Results of Operations," 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 natural gas liquids (NGLs) and liquefied natural gas (LNG) volumes and sales; the projected volume and timing of LNG offtake and tolling commitments subject to final investment decisions; potential curtailments and the anticipated volume and duration thereof; 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 projects; the cost, capacity and timing of obtaining regulatory approvals; our ability to successfully implement and execute our operational and organizational initiatives, and achieve the anticipated results of such initiatives; projected gathering and compression rates; potential 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 Company's acquisition of all of the operating subsidiaries of Blackline Midstream, LLC; the amount and timing of any repayments, redemptions or repurchases of EQT 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 are subject to 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, 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 or tariffs; 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

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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; and disruptions to our business due to recently completed divestitures, acquisitions and other significant strategic transactions. These and other risks and uncertainties are described under the "Risk Factors" section and elsewhere in EQT's Annual Report on Form 10-K for the year ended December 31, 2025, 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 and Significant Events

Blackline Midstream Acquisition

On July 21, 2026, we completed our acquisition (the Blackline Midstream Acquisition) of all of the operating subsidiaries of Blackline Midstream, LLC, an owner and operator of liquefied propane gas storage, distribution and marine terminal facilities and associated assets on the Piscataqua River in Newington, New Hampshire and Providence, Rhode Island. The purchase price for the Blackline Midstream Acquisition was approximately $77 million, subject to customary post-closing purchase price adjustments. We funded the consideration with borrowings under EQT's revolving credit facility.

MVP A and MVP C Interest Acquisitions

On March 30, 2026, we completed our acquisitions (the MVP A and MVP C Interest Acquisitions) of an approximately 3.94% interest in each of MVP A and MVP C (each defined in Note 8 to the Condensed Consolidated Financial Statements) from an affiliate of Con Edison Gas Pipeline and Storage, LLC pursuant to a preferential buy-out right under the MVP LLC Agreement (defined in Note 8 to the Condensed Consolidated Financial Statements). Total consideration for our acquisition of equity interests in MVP A (MVP A Interest Acquisition), excluding transaction costs, was $198.3 million, of which $98.4 million was funded by the BXCI Affiliate (defined in Note 9 to the Condensed Consolidated Financial Statements). Total consideration for our acquisition of equity interests in MVP C was $15.6 million. We funded our share of the consideration for the MVP A and MVP C Interest Acquisitions with cash on hand.

Olympus Energy Acquisition

Our financial results for 2026 reflect our operation of the assets acquired in our acquisition (the Olympus Energy Acquisition) of certain oil and gas properties and related upstream and midstream assets from Olympus Energy LLC, Hyperion Midstream LLC and Bow & Arrow Land Company LLC, which was completed on July 1, 2025.

Trends and Uncertainties

Commodity prices were volatile in the first half of 2026 and we expect commodity prices to continue to be volatile for the remainder of 2026 due to macroeconomic uncertainty, changes to the regulatory environment and geopolitical instability and tensions, including in the Middle East, Venezuela, Russia and Ukraine, and potential further imposition of domestic and foreign tariffs. 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.

In response to natural gas price volatility and to optimize in-basin pricing, we implement strategic curtailments from time to time. Strategic curtailments during the second quarter of 2026 were below our previously disclosed guidance and were not significant to our results. Low natural gas prices or volatility in the natural gas market may result in further adjustments to our 2026 planned development schedule and/or adjustments to the development schedule of non-operated wells in which we have a working interest. We cannot control or otherwise influence the development schedule of non-operated wells in which we have a working interest. Adjustments to our 2026 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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

On July 4, 2025, President Trump signed the One Big Beautiful Bill Act (OBBBA) into law. We expect the enactment of the OBBBA to favorably impact our future projected cash income tax obligations by deferring the payment of a significant portion of current federal income taxes.

President Trump has also executed several executive orders, some of which impact the oil and gas industry, and he and others in Congress have indicated the potential for further changes to regulations, many of which could impact the oil and gas industry, as well as the implementation of tariffs on foreign goods and services. It is uncertain to what extent such changes in regulations and tariffs will impact our business. Tariffs on foreign goods and services could result in other countries instituting tariffs on U.S. goods and services, which could impact the demand for and price of natural gas, increase the price of supplies and raw materials that we rely on to conduct our business, and impact interest rates. A changing regulatory environment and domestic or foreign tariffs could ultimately impact our future sales volume, operating revenues and expenses, per unit metrics and capital expenditures.

Consolidated Results of Operations

Net income attributable to EQT Corporation for the three months ended June 30, 2026 was approximately $211 million, $0.34 per diluted share, compared to approximately $784 million, $1.30 per diluted share, for the same period in 2025. The decrease was driven primarily by lower derivative gains and lower average realized natural gas prices, partly offset by lower income tax expense and lower legal reserves.

Net income attributable to EQT Corporation for the six months ended June 30, 2026 was approximately $1,699 million, $2.70 per diluted share, compared to approximately $1,026 million, $1.70 per diluted share, for the same period in 2025. The increase was driven primarily by higher natural gas sales, lower legal reserves and lower interest expense, partly offset by a loss on derivatives in 2026 compared to a gain in 2025, higher income tax expense and higher depreciation expense.

See "Average Realized Price Reconciliation" for a discussion and calculation of our average realized price, which is based on our Upstream segment's adjusted operating revenues (Upstream adjusted operating revenues), a non-GAAP supplemental financial measure that has been reconciled to total Upstream operating revenues in "Non-GAAP Financial Measures Reconciliation." See "Business Segment Results of Operations" for a discussion of segment operating revenues and expenses and "Other Income Statement Items" for a discussion of other 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 Upstream adjusted operating revenues, a non-GAAP supplemental financial measure. Upstream adjusted operating revenues is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Upstream adjusted operating revenues should not be considered as an alternative to total Upstream operating revenues. See "Non-GAAP Financial Measures Reconciliation" for a reconciliation of Upstream adjusted operating revenues to total Upstream operating revenues, the most directly comparable financial measure calculated in accordance with United States generally accepted accounting principles (GAAP).

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	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)	596,984		534,441		1,178,311		1,070,779
NYMEX price ($/MMBtu)	$	2.89	$	3.43	$	3.91	$	3.54
Btu uplift	0.16		0.20		0.21		0.19
Natural gas price ($/Mcf)	$	3.05	$	3.63	$	4.12	$	3.73

Basis ($/Mcf) (a)	$	(0.67)	$	(0.75)	$	(0.15)	$	(0.38)
Cash settled basis swaps ($/Mcf)	—		—		(0.16)		(0.04)
Average differential, including cash settled basis swaps ($/Mcf)	(0.67)		(0.75)		(0.31)		(0.42)
Average adjusted price ($/Mcf)	2.38		2.88		3.81		3.31
Cash settled derivatives ($/Mcf)	0.13		(0.19)		(0.03)		(0.13)
Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.51	$	2.69	$	3.78	$	3.18
Natural gas sales, including cash settled derivatives	$	1,499,693	$	1,438,682	$	4,448,390	$	3,400,873

LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)	20,751		22,475		41,309		43,347
Sales volume (Mbbl)	3,459		3,745		6,885		7,224
NGLs price ($/Bbl)	$	39.29	$	35.86	$	38.77	$	40.02
Cash settled derivatives ($/Bbl)	(0.80)		(0.22)		(0.11)		(0.70)
Average NGLs price, including cash settled derivatives ($/Bbl)	$	38.49	$	35.64	$	38.66	$	39.32
NGLs sales, including cash settled derivatives	$	133,121	$	133,488	$	266,153	$	284,023
Ethane:
Sales volume (MMcfe) (b)	13,934		9,432		26,638		20,602
Sales volume (Mbbl)	2,322		1,573		4,439		3,434
Ethane price ($/Bbl)	$	7.33	$	6.85	$	9.71	$	8.69
Ethane sales	$	17,021	$	10,775	$	43,089	$	29,829
Oil:
Sales volume (MMcfe) (b)	2,805		1,879		5,915		4,250
Sales volume (Mbbl)	468		313		986		708
Oil price ($/Bbl)	$	70.14	$	51.70	$	62.15	$	52.45
Oil sales	$	32,793	$	16,190	$	61,269	$	37,151

Total liquids sales volume (MMcfe) (b)	37,490		33,786		73,862		68,199
Total liquids sales volume (Mbbl)	6,249		5,631		12,310		11,366
Total liquids sales	$	182,935	$	160,453	$	370,511	$	351,003

TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,682,628	$	1,599,135	$	4,818,901	$	3,751,876
Total sales volume (MMcfe)	634,474		568,227		1,252,173		1,138,978
Average realized price ($/Mcfe)	$	2.65	$	2.81	$	3.85	$	3.29

(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 Upstream adjusted operating revenues, a non-GAAP supplemental financial measure.

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Non-GAAP Financial Measures Reconciliation

The table below reconciles Upstream adjusted operating revenues, a non-GAAP supplemental financial measure, to total Upstream 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 Upstream operating revenues to EQT Corporation operating revenues as reported in the Statements of Condensed Consolidated Operations.

Upstream 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. Upstream adjusted operating revenues is defined as total Upstream operating revenues, less the revenue impact of changes in the fair value of derivative instruments prior to settlement and Upstream other revenues. We believe that Upstream 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. Upstream 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 Upstream other revenues, which consists of costs of, and recoveries on, pipeline capacity releases and other revenues.


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Thousands, unless otherwise noted)
Total Upstream operating revenues	$	1,663,633	$	2,420,542	$	4,870,072	$	3,989,825
(Deduct) add:
Upstream (gain) loss on derivatives	(44,640)		(719,964)		193,629		(41,045)
Net cash settlements received (paid) on derivatives (a)	72,614		(101,364)		(231,048)		(193,350)
Upstream other revenues	(8,979)		(79)		(13,752)		(3,554)
Upstream adjusted operating revenues, a non-GAAP financial measure	$	1,682,628	$	1,599,135	$	4,818,901	$	3,751,876

Total sales volume (MMcfe)	634,474		568,227		1,252,173		1,138,978
Average sales price ($/Mcfe)	$	2.54	$	2.99	$	4.03	$	3.46
Average realized price ($/Mcfe)	$	2.65	$	2.81	$	3.85	$	3.29

(a)Net cash settlements received (paid) on derivatives are included in average realized price but may not be included in operating revenues. For the three months ended June 30, 2026, net cash settlements received on derivatives consisted of net cash settlements received on NYMEX natural gas hedge positions of approximately $76 million and net cash settlements paid on basis and liquids hedge positions of approximately $3 million. For the three months ended June 30, 2025, net cash settlements paid on derivatives consisted of net cash settlements paid on NYMEX natural gas hedge positions of approximately $102 million and net cash settlements received on basis and liquids hedge positions of approximately $1 million.

For the six months ended June 30, 2026, net cash settlements paid on derivatives consisted of net cash settlements paid on NYMEX natural gas hedge positions of approximately $38 million and net cash settlements paid on basis and liquids hedge positions of approximately $193 million. For the six months ended June 30, 2025, net cash settlements paid on derivatives consisted of net cash settlements paid on NYMEX natural gas hedge positions of approximately $145 million and net cash settlements paid on basis and liquids hedge positions of approximately $48 million.

Business Segment Results of Operations

We have three reportable segments consisting of Upstream, Gathering and Transmission.

Effective December 31, 2025, we renamed our previously reported "Production" segment as the "Upstream" segment to better align with the nature of our operations and our internal reporting framework. This change had no impact on the structure of our internal organization, including the composition of our reportable segments.

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

Items that are managed on a consolidated basis, including cash and cash equivalents, debt, income taxes and amounts related to our corporate function, and items related to our energy transition initiatives have not been allocated to our reportable segments. These items are discussed under "Other Income Statement Items."

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Upstream Results of Operations


	Three Months Ended June 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Total sales volume (MMcfe)	634,474		568,227		66,247		11.7
Average daily sales volume (MMcfe/d)	6,972		6,244		728		11.7
Average sales price ($/Mcfe)	$	2.54	$	2.99	$	(0.45)	(15.1)

Operating revenues:
Sales of natural gas, NGLs and oil	$	1,610,014	$	1,700,499	$	(90,485)	(5.3)
Gain on derivatives	44,640		719,964		(675,324)		(93.8)
Other revenues	8,979		79		8,900		11,265.8
Total operating revenues	1,663,633		2,420,542		(756,909)		(31.3)
Operating expenses:
Transportation and processing:
Gathering	57,991		48,077		9,914		20.6
Transmission	253,844		257,724		(3,880)		(1.5)
Processing	73,182		83,315		(10,133)		(12.2)
Transportation and processing to affiliate (a)	336,190		317,023		19,167		6.0
Total transportation and processing	721,207		706,139		15,068		2.1
Lease operating expense (LOE)	62,837		51,792		11,045		21.3
Production taxes	37,479		39,726		(2,247)		(5.7)
Selling, general and administrative	62,028		46,708		15,320		32.8
Production depletion	602,301		539,804		62,497		11.6
Other depreciation and depletion	1,164		1,114		50		4.5
Loss on sale/exchange of long-lived assets	2,860		2,688		172		6.4
Impairment and expiration of leases	6,232		3,254		2,978		91.5
Other operating expenses	58,142		22,207		35,935		161.8
Total operating expenses	1,554,250		1,413,432		140,818		10.0
Operating income	$	109,383	$	1,007,110	$	(897,727)	(89.1)

Per Unit ($/Mcfe):
Gathering	$	0.09	$	0.08	$	0.01	12.5
Transmission	0.40		0.45		(0.05)		(11.1)
Processing	0.12		0.15		(0.03)		(20.0)
Transportation and processing to affiliate (a)	0.53		0.56		(0.03)		(5.4)
LOE	0.10		0.09		0.01		11.1
Production taxes	0.06		0.07		(0.01)		(14.3)
Selling, general and administrative	0.10		0.08		0.02		25.0
Production depletion	0.95		0.95		—		—

(a)Transportation and processing to affiliate represents intercompany transactions with our Gathering and Transmission segments, which are eliminated in consolidation.

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Sales of Natural Gas, NGLs and Oil. Sales of natural gas, NGLs and oil decreased by approximately $90 million for the three months ended June 30, 2026 compared to the same period in 2025, reflecting a decrease of approximately $288 million from lower average sales price, partly offset by approximately $198 million from increased sales volumes.

Average sales price decreased for the three months ended June 30, 2026 compared to the same period for 2025 due primarily to a lower NYMEX price, partly offset by a favorable basis differential and higher liquids prices. Sales volume increased for the three months ended June 30, 2026 compared to the same period for 2025 due primarily to a 48 billion cubic feet equivalent (Bcfe) increase from the assets acquired in the Olympus Energy Acquisition, increases from wells turned-in-line since the second quarter of 2025 and increases from well performance optimization.

Gain on Derivatives. For the three months ended June 30, 2026, we recognized a gain on derivatives of approximately $45 million related primarily to increases in the fair market value of our NYMEX swaps and options of approximately $37 million due to decreases in NYMEX forward prices and increases in the fair market value of our basis and liquids swaps of approximately $8 million. For the three months ended June 30, 2025, we recognized a gain on derivatives of approximately $720 million related primarily to increases in the fair market value of our NYMEX swaps and options of approximately $682 million due to decreases in NYMEX forward prices and increases in the fair market value of our basis and liquids swaps of approximately $38 million.

Gathering Expense. Gathering expense increased on an absolute and per Mcfe basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to higher volumes gathered by third parties from wells turned-in-line in the first quarter of 2026.

Processing Expense. Processing expense decreased on an absolute and per Mcfe basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to decreased production of gas that requires processing. In addition, on a per Mcfe basis, processing expense decreased due primarily to higher sales volume.

Transportation and Processing Expense to Affiliate. Affiliate transportation and processing expense increased on an absolute basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to our Gathering segment's ownership of the gathering assets acquired in the Olympus Energy Acquisition, partly offset by the declining rate structures under a certain gas gathering agreement with our Gathering segment. On a per Mcfe basis, affiliate transportation and processing expense decreased due primarily to higher sales volume as well as the declining rate structures under a certain gas gathering agreement with our Gathering segment.

Lease Operating Expense. Lease operating expense increased on an absolute and per Mcfe basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to costs from the assets acquired in the Olympus Energy Acquisition as well as higher water network and winter maintenance expenses.

Selling, General and Administrative Expense. Selling, general and administrative expense increased on an absolute basis and per Mcfe basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to higher long-term incentive compensation costs and higher professional service costs.

Production Depletion Expense. Production depletion expense increased on an absolute basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to higher sales volumes, partly offset by a lower annual depletion rate.

Other Operating Expenses. Other operating expenses increased on an absolute basis for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to increased expense from changes in legal and environmental reserves, including from settlements.

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	Six Months Ended June 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Total sales volume (MMcfe)	1,252,173		1,138,978		113,195		9.9
Average daily sales volume (MMcfe/d)	6,918		6,293		625		9.9
Average sales price ($/Mcfe)	$	4.03	$	3.46	$	0.57	16.5

Operating revenues:
Sales of natural gas, NGLs and oil	$	5,049,949	$	3,945,226	$	1,104,723	28.0
(Loss) gain on derivatives	(193,629)		41,045		(234,674)		(571.7)
Other revenues	13,752		3,554		10,198		286.9
Total operating revenues	4,870,072		3,989,825		880,247		22.1
Operating expenses:
Transportation and processing:
Gathering	113,805		92,914		20,891		22.5
Transmission	517,320		508,588		8,732		1.7
Processing	154,231		165,823		(11,592)		(7.0)
Transportation and processing to affiliate (a)	660,330		627,414		32,916		5.2
Total transportation and processing	1,445,686		1,394,739		50,947		3.7
LOE	116,549		93,592		22,957		24.5
Production taxes	98,945		86,364		12,581		14.6
Selling, general and administrative	117,076		95,378		21,698		22.7
Production depletion	1,168,825		1,082,139		86,686		8.0
Other depreciation and depletion	2,346		2,273		73		3.2
Loss on sale/exchange of long-lived assets	2,835		2,872		(37)		(1.3)
Impairment and expiration of leases	10,055		5,915		4,140		70.0
Other operating expenses	72,096		27,657		44,439		160.7
Total operating expenses	3,034,413		2,790,929		243,484		8.7
Operating income	$	1,835,659	$	1,198,896	$	636,763	53.1

Per Unit ($/Mcfe):
Gathering	$	0.09	$	0.08	$	0.01	12.5
Transmission	0.41		0.45		(0.04)		(8.9)
Processing	0.12		0.15		(0.03)		(20.0)
Transportation and processing to affiliate (a)	0.53		0.55		(0.02)		(3.6)
LOE	0.09		0.08		0.01		12.5
Production taxes	0.08		0.08		—		—
Selling, general and administrative	0.09		0.08		0.01		12.5
Production depletion	0.93		0.95		(0.02)		(2.1)

(a)Transportation and processing to affiliate represents intercompany transactions with our Gathering and Transmission segments, which are eliminated in consolidation.

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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 increased by approximately $1,105 million for the six months ended June 30, 2026 compared to the same period in 2025, reflecting an increase of approximately $713 million from higher average sales price and approximately $392 million from increased sales volumes.

Average sales price increased for the six months ended June 30, 2026 compared to the same period for 2025 due primarily to a higher NYMEX price and a favorable basis differential, partly offset by lower NGL prices. Sales volume increased for the six months ended June 30, 2026 compared to the same period for 2025 due primarily to a 96 Bcfe increase from the assets acquired in the Olympus Energy Acquisition, increases from wells turned-in-line since the second quarter of 2025 and increases from well performance optimization.

(Loss) Gain on Derivatives. For the six months ended June 30, 2026, we recognized a loss on derivatives of approximately $194 million related primarily to decreases in the fair market value of our basis and liquids swaps of approximately $157 million and decreases in the fair market value of our NYMEX swaps and options of approximately $37 million due to increases in NYMEX forward prices. For the six months ended June 30, 2025, we recognized a gain on derivatives of approximately $41 million related primarily to increases in the fair market value of our basis and liquids swaps of approximately $142 million, partly offset by decreases in the fair market value of our NYMEX swaps and options of approximately $101 million due to increases in NYMEX forward prices.

Gathering Expense. Gathering expense increased on an absolute and per Mcfe basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher volumes gathered by third parties from wells turned-in-line in the first quarter of 2026.

Transmission Expense. Transmission expense increased on an absolute basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to additional short-term capacity contracted on MVP Mainline (defined in Note 8 to the Condensed Consolidated Financial Statements) of approximately $12 million and higher rates for capacity on the Rockies Express Pipeline, partly offset by expired capacity on the Columbia Gas Transmission system. On a per Mcfe basis, transmission expense decreased due primarily to higher sales volume, partly offset by the additional capacity and higher capacity charges.

Processing Expense. Processing expense decreased on an absolute and per Mcfe basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to decreased production of gas that requires processing. In addition, on a per Mcfe basis, processing expense decreased due primarily to higher sales volume.

Transportation and Processing Expense to Affiliate. Affiliate transportation and processing expense increased on an absolute basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to our Gathering segment's ownership of the gathering assets acquired in the Olympus Energy Acquisition, partly offset by the declining rate structures under a certain gas gathering agreement with our Gathering segment. On a per Mcfe basis, affiliate transportation and processing expense decreased due primarily to higher sales volume as well as the declining rate structures under a certain gas gathering agreement with our Gathering segment.

Lease Operating Expense. Lease operating expense increased on an absolute and per Mcfe basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to costs from the assets acquired in the Olympus Energy Acquisition as well as higher water network and winter maintenance expenses.

Production Taxes. Production tax expense increased on an absolute basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher severance taxes of approximately $9 million driven by higher sales volumes and higher sales prices.

Selling, General and Administrative Expense. Selling, general and administrative expense increased on an absolute basis and per Mcfe basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher long-term incentive compensation costs and higher professional service costs.

Production Depletion Expense. Production depletion expense increased on an absolute basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher sales volumes, partly offset by a lower annual depletion rate. On a per Mcfe basis, production depletion expense decreased due primarily to the lower depletion rate.

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Other Operating Expenses. Other operating expenses increased on an absolute basis for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to increased expense from changes in legal and environmental reserves, including from settlements.

Gathering Results of Operations


	Three Months Ended June 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Gathered volume (British thermal unit (BBtu)/d):
Firm capacity (a)	5,920		5,096		824		16.2
Volumetric-based volumes (a)	4,955		4,731		224		4.7
Total gathered volume	10,875		9,827		1,048		10.7

Operating revenues:
Firm reservation fees	$	171,030	$	169,597	$	1,433	0.8
Volumetric-based fees	170,298		150,672		19,626		13.0
Total operating revenues	341,328		320,269		21,059		6.6
Operating expenses:
Operating and maintenance	47,102		40,597		6,505		16.0
Selling, general and administrative	21,352		12,921		8,431		65.3
Depreciation	56,134		54,032		2,102		3.9

Other operating expenses	—		7,314		(7,314)		(100.0)
Total operating expenses	124,588		114,864		9,724		8.5
Operating income	$	216,740	$	205,405	$	11,335	5.5

(a)For agreements structured with minimum volume commitments (MVCs), firm capacity includes volumes up to the contractual MVC and volumetric-based volumes includes volumes in excess of the contractual MVC.

Volumetric-Based Fees. Volumetric-based fee revenue increased for the three months ended June 30, 2026 compared to the same period in 2025 due to increased affiliate revenue, partly offset by decreased third-party revenue. Affiliate revenue increased approximately $25 million due primarily to the gathering assets acquired in the Olympus Energy Acquisition. Third-party revenue decreased approximately $6 million due primarily to lower usage.

Operating and Maintenance Expense. Operating and maintenance expense increased for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to higher personnel costs.

Selling, General and Administrative Expense. Selling, general and administrative expense increased for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to higher long-term incentive compensation costs and higher professional service costs.

Other Operating Expense. During the three months ended June 30, 2025, we recognized other operating expenses related to environmental reserves.

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	Six Months Ended June 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Gathered volume (British thermal unit (BBtu)/d):
Firm capacity (a)	5,817		5,116		701		14
Volumetric-based volumes (a)	4,904		4,746		158		3
Total gathered volume	10,721		9,862		859		9

Operating revenues:
Firm reservation fees	$	334,112	$	336,288	$	(2,176)	(1)
Volumetric-based fees	342,191		319,294		22,897		7
Total operating revenues	676,303		655,582		20,721		3
Operating expenses:
Operating and maintenance	89,213		76,906		12,307		16
Selling, general and administrative	40,098		28,318		11,780		42
Depreciation	111,949		103,456		8,493		8

Other operating expenses	35		10,296		(10,261)		(100)
Total operating expenses	241,295		218,976		22,319		10
Operating income	$	435,008	$	436,606	$	(1,598)	—

(a)For agreements structured with MVCs, firm capacity includes volumes up to the contractual MVC and volumetric-based volumes includes volumes in excess of the contractual MVC.

Firm Reservation Fees. Firm reservation fee revenue decreased for the six months ended June 30, 2026 compared to the same period in 2025 due to decreased affiliate revenue, partly offset by increased third-party revenue. Affiliate revenue decreased approximately $12 million due primarily to declining rate structures under certain gas gathering agreements with our Upstream segment of approximately $19 million, partly offset by additional capacity acquired under certain gas gathering agreements with our Upstream segment. Third-party revenues increased approximately $10 million due primarily to increased contracted MVCs.

Volumetric-Based Fees. Volumetric-based fee revenue increased for the six months ended June 30, 2026 compared to the same period in 2025 due to increased affiliate revenue, partly offset by decreased third-party revenue. Affiliate revenue increased approximately $31 million due primarily to the gathering assets acquired in the Olympus Energy Acquisition of approximately $46 million, partly offset by lower usage under certain gas gathering agreements with our Upstream segment. Third-party revenue decreased approximately $8 million due primarily to lower usage.

Operating and Maintenance Expense. Operating and maintenance expense increased for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher personnel costs and higher repairs and maintenance expense.

Selling, General and Administrative Expense. Selling, general and administrative expense increased for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher long-term incentive compensation costs and higher professional service costs.

Other Operating Expense. During the six months ended June 30, 2025, we recognized other operating expenses related to environmental reserves.

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EQT CORPORATION AND SUBSIDIARIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Transmission Results of Operations


	Three Months Ended June 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Transmission pipeline throughput (BBtu/d):
Firm capacity (a)	4,700		4,229		471		11.1
Interruptible capacity	20		50		(30)		(60.0)
Total transmission pipeline throughput	4,720		4,279		441		10.3

Average firm transmission reservation commitments (BBtu/d)	4,967		4,474		493		11.0

Operating revenues:
Firm reservation fees	$	106,220	$	96,535	$	9,685	10.0
Volumetric-based fees	34,945		38,048		(3,103)		(8.2)
Total operating revenues	141,165		134,583		6,582		4.9
Operating expenses:
Operating and maintenance	13,118		13,386		(268)		(2.0)
Selling, general and administrative	8,361		8,107		254		3.1
Depreciation	20,375		19,399		976		5.0
Amortization of intangible assets	3,333		3,333		—		—
Loss on sale/exchange of long-lived assets	725		302		423		140.1
Other operating expenses	2,250		—		2,250		100.0
Total operating expenses	48,162		44,527		3,635		8.2
Operating income	$	93,003	$	90,056	$	2,947	3.3

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

Firm Reservation Fees. Firm reservation fee revenue increased for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to increased affiliate revenue of approximately $8 million related to an increase in contracted firm reservation capacity and higher average reservation rates under certain agreements with our Upstream segment.

Other Operating Expense. During the three months ended June 30, 2026, we recognized other operating expenses related to legal and environmental reserves, including from settlements.

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EQT CORPORATION AND SUBSIDIARIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS


	Six Months Ended June 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Transmission pipeline throughput (BBtu/d):
Firm capacity (a)	4,695		4,184		511		12
Interruptible capacity	24		49		(25)		(51)
Total transmission pipeline throughput	4,719		4,233		486		11

Average firm transmission reservation commitments (BBtu/d)	5,333		4,909		424		9

Operating revenues:
Firm reservation fees	$	232,847	$	214,387	$	18,460	9
Volumetric-based fees	69,770		66,467		3,303		5
Total operating revenues	302,617		280,854		21,763		8
Operating expenses:
Operating and maintenance	25,875		24,374		1,501		6
Selling, general and administrative	16,039		17,526		(1,487)		(8)
Depreciation	42,037		39,269		2,768		7
Amortization of intangible assets	6,666		6,666		—		—
Loss on sale/exchange of long-lived assets	725		349		376		108
Other operating expenses	2,250		(536)		2,786		(520)
Total operating expenses	93,592		87,648		5,944		7
Operating income	$	209,025	$	193,206	$	15,819	8

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

Firm Reservation Fees. Firm reservation fee revenue increased for the six months ended June 30, 2026 compared to the same period in 2025 due to increased affiliate and third-party revenue. Affiliate revenue increased $13 million due primarily to increased firm reservation capacity and higher average reservation rates under certain agreements with our Upstream segment. Third-party revenue increased approximately $5 million due primarily to increased short-term firm reservation winter capacity and higher average reservation rates under certain agreements with third parties.

Other Operating Expense. Other operating expenses increased for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to expense from changes in legal and environmental reserves, including from settlements.

Other Income Statement Items

Other operating expenses. During the three months ended June 30, 2025, we recognized approximately $134 million of corporate other operating expense, net of expected insurance recoveries, for estimated loss contingencies related to a securities class action.

Income from Investments. Income from investments decreased for the three months ended June 30, 2026 compared to the same period in 2025 due primarily to lower equity earnings from our investment in Laurel Mountain Midstream, LLC (LMM). Income from investments increased for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to higher equity earnings from our investment in the MVP Joint Venture (defined in Note 8 to the Condensed Consolidated Financial Statements) of approximately $35 million and an increase in the fair value of our investment in the Investment Fund (defined in Note 8 to the Condensed Consolidated Financial Statements) of approximately $15 million, partly offset by lower equity earnings from our investment in LMM.

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EQT CORPORATION AND SUBSIDIARIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Loss on Debt Extinguishment. Loss on debt extinguishment increased by approximately $12 million for the six months ended June 30, 2026 compared to the same period in 2025 due primarily to the derecognition of unamortized fair value adjustments associated with debt redemptions, which resulted in a net loss of approximately $7 million in 2026 compared to a net gain of approximately $8 million in 2025, as well as higher net cash premiums, partly offset by lower financing fees. See Note 7 to the Condensed Consolidated Financial Statements for discussion of debt repayments during the six months ended June 30, 2026.

Interest Expense, Net. Net interest expense decreased for both the three and six months ended June 30, 2026 compared to the same period in 2025 due primarily to the redemptions and repurchases of senior notes since the second quarter of 2025.

Income Tax Expense. See Note 6 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, including, 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, Capital Contributions and Sales Volume

In the third quarter of 2026, we expect to spend approximately $710 million to $820 million in total capital expenditures. 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 2026 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 the third quarter of 2026, we expect to make approximately $60 million to $70 million of capital contributions to our equity method investments, including the MVP Joint Venture.

In the third quarter of 2026, we expect our sales volume to be 570 Bcfe to 620 Bcfe.

Material Cash Requirements

We have contractual commitments under our debt agreements, including interest payments and principal repayments. See Note 7 to the Condensed Consolidated Financial Statements for a summary of such contractual commitments, including maturity dates.

Through our controlling interest in the Midstream Joint Venture (defined in Note 9 to the Condensed Consolidated Financial Statements), we are required to distribute available cash flow to the BXCI Affiliate as the holder of the Midstream Joint Venture's Class B units at least quarterly, including to satisfy the Base Return (as defined in the amended and restated limited liability company agreement of the Midstream Joint Venture). See Note 9 to the Condensed Consolidated Financial Statements for further discussion.

In January 2026, we entered into an agreement with a third-party owner and operator of LNG vessels pursuant to which we will lease two vessels for a 10-year term, with lease commencement expected in 2028. The leases are anticipated to result in undiscounted future minimum lease payments of approximately $295 million per vessel. The leases have not been recognized in the Condensed Consolidated Balance Sheet as they have not yet commenced.

On July 21, 2026, we funded the consideration for the Blackline Midstream Acquisition of approximately $77 million with borrowings under EQT's revolving credit facility. See Note 12 to the Condensed Consolidated Financial Statements for discussion of the Blackline Midstream Acquisition.

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EQT CORPORATION AND SUBSIDIARIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Sources and Uses of Cash

Operating Activities. Net cash provided by operating activities was approximately $4,103 million and $2,983 million for the six months ended June 30, 2026 and 2025, respectively. The increase was due primarily to higher cash operating revenues and lower net interest expense, partly offset by higher net cash settlements paid on derivatives and unfavorable changes in working capital.

Our cash flows from operating activities, including changes in working capital, 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 Item 1A., "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 EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

Investing Activities. Net cash used in investing activities was approximately $1,524 million and $1,198 million for the six months ended June 30, 2026 and 2025, respectively. The increase was attributable primarily to cash paid for the MVP A and MVP C Interest Acquisitions, including the portion paid by the BXCI Affiliate, and increased capital expenditures, partly offset by cash paid for the Olympus Energy Acquisition in 2025.

The following table summarizes our capital expenditures by segment.


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025

	(Millions)
Upstream:
Reserve development	$	369	$	383	$	781	$	731
Land and lease	45		30		81		49
Other upstream infrastructure	29		11		48		28
Capitalized overhead, capitalized interest and other	30		25		62		50
Total Upstream	473		449		972		858
Gathering	171		86		263		158
Transmission	8		10		19		23
Other corporate items	14		9		20		12
Total capital expenditures	666		554		1,274		1,051
Deduct: Non-cash items (a)	(16)		(5)		(25)		(2)
Total cash capital expenditures	$	650	$	549	$	1,249	$	1,049

(a)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.

Financing Activities. Net cash used in financing activities was approximately $2,577 million and $1,431 million for the six months ended June 30, 2026 and 2025, respectively. For the six months ended June 30, 2026, the primary uses of financing cash flows were the repayment and retirement of debt, distributions to the BXCI Affiliate and payment of dividends. The primary sources of financing cash flows for the six months ended June 30, 2026 were capital contributions from the BXCI Affiliate related to the MVP A Interest Acquisition of approximately $98 million. For the six months ended June 30, 2025, the primary uses of financing cash flows were the repayment and retirement of debt, repayment of revolving credit facility borrowings, payment of dividends and distributions to the BXCI Affiliate.

See Note 9 to the Condensed Consolidated Financial Statements for further discussion of cash flows to and from the BXCI Affiliate.

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EQT CORPORATION AND SUBSIDIARIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

On July 15, 2026, our Board of Directors declared a quarterly cash dividend of $0.165 per share of EQT common stock, payable on September 1, 2026, to shareholders of record at the close of business on August 5, 2026.

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.

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 and Eureka Midstream, LLC's (Eureka) revolving credit facilities, 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 contains financial covenants that require us to have a total debt to total capitalization ratio no greater than 65%. As of June 30, 2026, we were in compliance with all provisions and covenants under our debt agreements. See Note 7 to the Condensed Consolidated Financial Statements for a discussion of borrowings under EQT's and Eureka's revolving credit facilities.

Security Ratings

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 July 14, 2026.

Rating agency

Senior notes

Outlook

Moody's Investors Service, Inc. (Moody's)

Baa3

Positive

S&P Global Ratings (S&P)

BBB–

Stable

Fitch Ratings Service (Fitch)

BBB

Stable

Changes in our credit ratings may affect our access to the capital markets, the cost of short-term debt through interest rates and fees under our revolving credit facilities, the interest rate on our senior notes with adjustable rates, the rates available on new 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

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 July 14, 2026. 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.


	Q3 2026 (a)		Q4 2026		Q1 2027		Q2 2027		Q3 2027		Q4 2027
Hedged Volume (MMDth)	125		108		62		138		140		47
Hedged Volume (MMDth/d)	1.4		1.2		0.7		1.5		1.5		0.5



Swaps – Short
Volume (MMDth)	—		—		—		65		66		22
Avg. Price ($/Dth)	$	—	$	—	$	—	$	3.16	$	3.16	$	3.16



Calls – Short
Volume (MMDth)	125		108		62		73		74		25
Avg. Strike ($/Dth)	$	4.94	$	5.13	$	5.77	$	4.51	$	4.51	$	4.51
Puts – Long
Volume (MMDth)	125		108		62		73		74		25
Avg. Strike ($/Dth)	$	3.50	$	3.72	$	3.65	$	3.00	$	3.00	$	3.00
Puts – Short
Volume (MMDth)	—		—		25		73		74		25
Avg. Strike ($/Dth)	$	—	$	—	$	2.50	$	2.50	$	2.50	$	2.50

(a)July 1 through September 30.

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 Part I, Item 3., "Quantitative and Qualitative Disclosures About Market Risk" and Note 4 to the Condensed Consolidated Financial Statements for further discussion of our hedging program.

Commitments and Contingencies

We evaluate our legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrue a liability when we determine, based on historical experience and matter-specific facts, 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 to us is probable but the amount of the loss cannot be reasonably estimated, or (ii) a loss to us is less likely than probable but is reasonably possible, then we are required to disclose the matter in EQT's 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.

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EQT CORPORATION AND SUBSIDIARIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

See Note 13 to the Consolidated Financial Statements in EQT's Annual Report on Form 10-K for the year ended December 31, 2025 for a discussion of our commitments and contingencies.

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.

Recently Issued Accounting Standards

See Note 1 to the Condensed Consolidated Financial Statements for a description of recently issued accounting standards.

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 EQT's Annual Report on Form 10-K for the year ended December 31, 2025. 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.

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, which can affect our operating results. We use derivative commodity instruments to hedge our cash flows from sales of produced natural gas and NGLs. 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., "Management's Discussion and Analysis of Financial Condition and Results of Operations."

A hypothetical decrease of 10% in the NYMEX natural gas price on June 30, 2026 and December 31, 2025 would increase the fair value of our natural gas derivative commodity instruments by approximately $124 million and $100 million, respectively. A hypothetical increase of 10% in the NYMEX natural gas price on June 30, 2026 and December 31, 2025 would decrease the fair value of our natural gas derivative commodity instruments by approximately $117 million and $93 million, respectively. For purposes of this analysis, we applied the 10% change in the NYMEX natural gas price on June 30, 2026 and December 31, 2025 to our natural gas derivative commodity instruments as of June 30, 2026 and December 31, 2025 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.

Interest Rate Risk. As of June 30, 2026, there have been no material changes to our interest rate risk exposures described in the "Quantitative and Qualitative Disclosures About Market Risk – Interest Rate Risk" section of EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

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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. Approximately 76%, or $133 million, of our OTC derivative contracts outstanding at June 30, 2026 had a positive fair value. Approximately 62%, or $159 million, of our OTC derivative contracts outstanding at December 31, 2025 had a positive fair value. Otherwise, as of June 30, 2026, there have been no material changes to our market risk exposures described in the "Quantitative and Qualitative Disclosures About Market Risk – Other Market Risks" section of EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

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

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 second quarter of 2026 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

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 accrue legal and other direct costs related to loss contingencies when actually incurred. We have established reserves in amounts that we believe to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, we believe that the ultimate outcome of any pending matter involving us will not materially affect our financial position, results of operations or liquidity.

There are no material updates to the matters previously disclosed in the "Legal Proceedings" section of our Annual Report on Form 10-K for the year ended December 31, 2025 and in the "Legal Proceedings" section of our Quarterly Report on Form 10 -Q for the period ended March 31, 2026.

Item 1A. Risk Factors

There are no material changes to the risk factors previously disclosed in the "Risk Factors" section of EQT's Annual Report on Form 10-K for the year ended December 31, 2025.

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

Recent Sales of Unregistered Equity Securities

None.

Issuer Purchases of Equity Securities

We did not repurchase any equity securities registered under Section 12 of the Exchange Act during the second quarter of 2026.

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 EQT 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 EQT common stock for an aggregate purchase price of up to $2 billion, excluding fees, commissions and expenses. 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. Further, on December 18, 2024, we announced that our Board of Directors approved an additional two-year extension of the Share Repurchase Program. As a result of the most recent extension, the Share Repurchase Program will expire on December 31, 2026, but it may be suspended, modified or discontinued at any time without prior notice. Repurchases under the Share Repurchase Program may be made from time to time in amounts at prices we deem appropriate and will be subject to a variety of factors, including the market price of EQT common stock, general market and economic conditions, applicable legal requirements and other considerations. As of June 30, 2026, 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 June 30, 2026, 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

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

Amended and Restated Bylaws of EQT Corporation (Amended through October 16, 2025).

Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-3551) filed on October 20, 2025.

10.01*

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

Incorporated herein by reference to Exhibit 99.4 to Form S-8 (#333-295077) filed on April 15, 2026.

10.02*

Form of Participant Award Agreement (Stock Options) – 2026 Grants.

Filed herewith as Exhibit 10.02.

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.

*Management contract or compensatory arrangement.

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SIGNATURES

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


						EQT CORPORATION
						(Registrant)


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

Date: July 22, 2026

EQT Corporation - 10-Q quarterly report FY2026 Q2

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PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Statements of Condensed Consolidated Operations	3
	Statements of Condensed Consolidated Comprehensive 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	29
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	47
Item 4.	Controls and Procedures	48

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	48
Item 1A.	Risk Factors	48
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	49
Item 5.	Other Information	49
Item 6.	Exhibits	50

Signatures		51