EQT Corporation - 10-Q quarterly report FY2026 Q3

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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 SEPTEMBER 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)

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

Title of each class

Trading symbol(s)

Name of each exchange on which registered

Common Stock, no par value

EQT

New York Stock Exchange

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

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

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

The number of shares of common stock, no par value, of the registrant outstanding (in thousands) as of October 20, 2026: 625,549

Table of Contents

TABLE OF CONTENTS

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements


EQT CORPORATION AND SUBSIDIARIES
STATEMENTS OF CONDENSED CONSOLIDATED OPERATIONS (UNAUDITED)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands, except per share amounts)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,507,808	$	1,677,617	$	6,557,757	$	5,622,843
Gain (loss) on derivatives	100,287		135,784		(93,342)		176,829
Pipeline and other	162,299		145,170		494,655		456,468
Total operating revenues	1,770,394		1,958,571		6,959,070		6,256,140
Operating expenses:
Transportation and processing	370,791		377,133		1,156,147		1,144,458
Production	92,079		98,302		307,573		278,258
Operating and maintenance	60,376		60,302		175,464		161,582
Purchased commodities	8,183		—		8,183		—
Selling, general and administrative	116,083		98,720		318,272		271,770
Depreciation, depletion and amortization	639,783		688,382		1,984,167		1,932,628
(Gain) loss on sale/exchange of long-lived assets	(2,893)		(5,623)		659		(2,402)
Impairment and expiration of leases	6,007		3,476		16,062		9,391
Other operating expenses	20,524		34,669		103,084		226,957
Total operating expenses	1,310,933		1,355,361		4,069,611		4,022,642
Operating income	459,461		603,210		2,889,459		2,233,498
Income from investments	(43,688)		(44,638)		(165,929)		(138,274)
Other income	(780)		(472)		(4,302)		(3,711)
Loss on debt extinguishment	18		1,909		29,887		19,478
Interest expense, net	72,152		109,929		244,381		333,166
Income before income taxes	431,759		536,482		2,785,422		2,022,839
Income tax expense	86,682		129,266		604,967		443,549
Net income	345,077		407,216		2,180,455		1,579,290
Less: Net income attributable to noncontrolling interests	66,386		71,354		203,110		217,142
Net income attributable to EQT Corporation	$	278,691	$	335,862	$	1,977,345	$	1,362,148

Income per share of common stock attributable to EQT Corporation:
Basic:
Weighted average common stock outstanding	625,991		624,532		625,696		607,245
Net income attributable to EQT Corporation	$	0.45	$	0.54	$	3.16	$	2.24
Diluted (Note 10):
Weighted average common stock outstanding	629,172		628,324		628,992		611,427
Net income attributable to EQT Corporation	$	0.44	$	0.53	$	3.14	$	2.23

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 September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands)
Net income	$	345,077	$	407,216	$	2,180,455	$	1,579,290
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax benefit (expense) of $38, $54, $(102) and $136	(16)		60		384		151
Comprehensive income	345,061		407,276		2,180,839		1,579,441
Less: Comprehensive income attributable to noncontrolling interests	66,386		71,354		203,110		217,142
Comprehensive income attributable to EQT Corporation	$	278,675	$	335,922	$	1,977,729	$	1,362,299

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)




	September 30, 2026		December 31, 2025

	(Thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	78,715	$	110,795
Accounts receivable (less allowance for credit losses: $5,830 and $3,088)	725,938		1,457,959
Derivative instruments, at fair value	185,211		202,390

Prepaid expenses and other	120,636		124,007
Total current assets	1,110,500		1,895,151

Property, plant and equipment	50,113,651		48,472,497
Less: Accumulated depreciation and depletion	16,446,632		14,914,689
Net property, plant and equipment	33,667,019		33,557,808

Investments in unconsolidated entities	3,960,861		3,630,577
Net intangible assets	189,407		200,486
Goodwill	2,062,462		2,062,462
Other assets	451,610		446,390
Total assets	$	41,441,859	$	41,792,874

LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	—	$	507,119
Accounts payable	1,138,859		1,367,431
Derivative instruments, at fair value	62,860		137,299
Accrued interest	82,657		137,505
Other current liabilities	285,515		335,487
Total current liabilities	1,569,891		2,484,841

Revolving credit facility borrowings	333,000		360,000
Senior notes	5,219,552		6,933,209
Deferred income taxes	4,048,587		3,472,010
Asset retirement obligations and other liabilities	1,251,527		1,182,666
Total liabilities	12,422,557		14,432,726

Equity:
Common stock, no par value, shares authorized: 1,280,000, shares issued: 625,547 and 624,076	19,560,596		19,517,761
Retained earnings	5,906,699		4,237,089
Accumulated other comprehensive loss	(1,789)		(2,173)
Total common shareholders' equity	25,465,506		23,752,677
Noncontrolling interests in consolidated subsidiaries	3,553,796		3,607,471
Total equity	29,019,302		27,360,148
Total liabilities and equity	$	41,441,859	$	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)



	Nine Months Ended September 30,
	2026		2025

	(Thousands)
Cash flows from operating activities:
Net income	$	2,180,455	$	1,579,290
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax expense	576,339		446,674
Depreciation, depletion and amortization	1,984,167		1,932,628
Loss (gain) on sale/exchange of long-lived assets	659		(2,402)
Impairment and expiration of leases	16,062		9,391
Income from investments	(165,929)		(138,274)
Loss on debt extinguishment	29,887		19,478
Share-based compensation expense	67,659		43,824
Distributions from equity method investments	187,083		202,560
Other	16,468		7,836
Loss (gain) on derivatives	93,342		(176,829)
Net cash settlements paid on derivatives	(160,527)		(118,390)

Changes in other assets and liabilities:
Accounts receivable	732,853		296,345
Accounts payable	(238,941)		(4,487)
Income tax receivable and payable	16,050		97,378
Other current assets	6,534		42,697
Other items, net	(155,829)		(237,154)
Net cash provided by operating activities	5,186,332		4,000,565
Cash flows from investing activities:
Capital expenditures	(1,896,087)		(1,675,691)
Cash paid for acquisitions, net of cash acquired	(79,560)		(484,807)
Net cash received (paid) for sale/exchange of assets	450		(8,603)
Cash paid for acquisitions of additional interests in equity method investments	(216,209)		—
Capital contributions to equity method investments	(117,438)		(44,406)
Other investing activities	(2,221)		(10,388)
Net cash used in investing activities	(2,311,065)		(2,223,895)
Cash flows from financing activities:
Proceeds from revolving credit facility borrowings	4,518,500		3,018,000
Repayment of revolving credit facility borrowings	(4,545,500)		(3,210,800)

Debt issuance costs	—		(9,623)
Repayment and retirement of debt	(2,237,944)		(905,698)
Net premiums paid on debt extinguishment	(22,649)		(29,507)
Dividends paid	(309,490)		(286,662)
Contribution from noncontrolling interests	98,357		—
Distributions to noncontrolling interests	(355,142)		(259,217)

Cash paid for taxes to net settle share-based incentive awards	(47,398)		(53,830)
Other financing activities	(6,081)		(5,690)
Net cash used in financing activities	(2,907,347)		(1,743,027)
Net change in cash and cash equivalents	(32,080)		33,643
Cash and cash equivalents at beginning of period	110,795		202,093
Cash and cash equivalents at end of period	$	78,715	$	235,736

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

See Note 1 for supplemental cash flow information.

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 July 1, 2025	598,812	$	17,999,758	$	3,425,732	$	(2,230)	$	3,674,590	$	25,097,850
Comprehensive income, net of tax:
Net income				335,862				71,354		407,216
Other postretirement benefits liability adjustment, net of tax benefit of $54						60				60
Dividends ($0.1575 per share)				(98,458)						(98,458)
Share-based compensation plans	23	19,533								19,533




Olympus Energy Acquisition (Note 11)	25,229	1,471,365								1,471,365


Distributions to noncontrolling interests								(107,263)		(107,263)






Balance at September 30, 2025	624,064	$	19,490,656	$	3,663,136	$	(2,170)	$	3,638,681	$	26,790,303

Balance at July 1, 2026	625,513	$	19,529,362	$	5,731,287	$	(1,773)	$	3,604,521	$	28,863,397
Comprehensive income, net of tax:
Net income				278,691				66,386		345,077
Other postretirement benefits liability adjustment, net of tax benefit of $38						(16)				(16)
Dividends ($0.165 per share)				(103,279)						(103,279)
Share-based compensation plans	34	31,234								31,234







Distributions to noncontrolling interests								(117,111)		(117,111)






Balance at September 30, 2026	625,547	$	19,560,596	$	5,906,699	$	(1,789)	$	3,553,796	$	29,019,302

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				1,362,148				217,142		1,579,290
Other postretirement benefits liability adjustment, net of tax benefit of $136						151				151
Dividends ($0.4725 per share)				(284,250)						(284,250)
Share-based compensation plans	1,965	4,205								4,205




Olympus Energy Acquisition (Note 11)	25,229	1,471,365								1,471,365


Distributions to noncontrolling interests								(259,217)		(259,217)


Other		375						248		623



Balance at September 30, 2025	624,064	$	19,490,656	$	3,663,136	$	(2,170)	$	3,638,681	$	26,790,303

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				1,977,345				203,110		2,180,455
Other postretirement benefits liability adjustment, net of tax expense of $(102)						384				384
Dividends ($0.495 per share)				(307,735)						(307,735)
Share-based compensation plans	1,471	42,835								42,835







Contribution from noncontrolling interests								98,357		98,357
Distributions to noncontrolling interests								(355,142)		(355,142)





Balance at September 30, 2026	625,547	$	19,560,596	$	5,906,699	$	(1,789)	$	3,553,796	$	29,019,302

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 September 30, 2026 and December 31, 2025, results of operations and changes in equity for the three and nine months ended September 30, 2026 and 2025 and cash flows for the nine months ended September 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.


	Nine Months Ended September 30,
	2026		2025

	(Thousands)
Cash paid (received) during the period for:
Interest, net of amount capitalized	$	285,718	$	355,666
Income taxes, net	9,930		(79,001)

Non-cash activity during the period for:
Right-of-use assets obtained in exchange for lease liabilities	$	82,816	$	20,322
Increase in asset retirement costs and obligations	26,633		22,267
Capitalization of non-cash equity share-based compensation	22,573		14,211
Investments in unconsolidated entities	6,015		17,981
Issuance of EQT common stock as consideration for acquisition (Note 11)	—		1,471,365

Table of Contents

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 September 2025, the FASB issued ASU 2025-07, Derivatives and Hedging (Topic 815) and Revenue from Contracts with Customers (Topic 606), to exclude from the scope of derivative accounting certain contracts with underlyings based on the operations or activities of one of the contracting parties. The amendments also clarify the accounting for share-based non-cash consideration received from a customer in a revenue contract. The Company early adopted ASU 2025-07 effective January 1, 2026 on a prospective basis. The Company's adoption of both the derivative scope refinements and the share-based non-cash consideration amendments did not result in a cumulative-effect adjustment to opening retained earnings and did not have an effect on the Company's consolidated financial statements.

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.

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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.

Cash and cash equivalents, debt, income taxes, amounts related to the Company's corporate function and other items managed on a consolidated basis as well as items related to the Company's downstream liquefied propane gas business, new ventures and energy transition initiatives have not been allocated to the Company's reportable segments. These items are presented as "Other."

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 September 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	$	1,516,267	$	—	$	—	$	1,516,267	$	(8,459)	$	1,507,808
Gain (loss) on derivatives	104,913		—		—		104,913		(4,626)		100,287
Pipeline and other	8,998		331,728		130,046		470,772		(308,473)		162,299
Total operating revenues	1,630,178		331,728		130,046		2,091,952		(321,558)		1,770,394
Operating expenses (a):
Transportation and processing	688,089		—		—		688,089		(317,298)		370,791
Production	92,079		—		—		92,079		—		92,079
Operating and maintenance	—		40,682		17,870		58,552		1,824		60,376
Purchased commodities	—		—		—		—		8,183		8,183
Selling, general and administrative	62,217		26,169		8,246		96,632		19,451		116,083
Depreciation, depletion and amortization	549,962		56,382		26,110		632,454		7,329		639,783
Gain on sale/exchange of long-lived assets	(2,868)		(9)		—		(2,877)		(16)		(2,893)
Impairment and expiration of leases	6,007		—		—		6,007		—		6,007
Other operating expenses	15,052		39		—		15,091		5,433		20,524
Total operating expenses	1,410,538		123,263		52,226		1,586,027		(275,094)		1,310,933
Operating income (loss)	$	219,640	$	208,465	$	77,820	$	505,925	$	(46,464)	$	459,461

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


	Three Months Ended September 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	$	1,677,617	$	—	$	—	$	1,677,617	$	—	$	1,677,617
Gain on derivatives	135,784		—		—		135,784		—		135,784
Pipeline and other	2,365		321,152		136,713		460,230		(315,060)		145,170
Total operating revenues	1,815,766		321,152		136,713		2,273,631		(315,060)		1,958,571
Operating expenses (a):
Transportation and processing	691,517		—		—		691,517		(314,384)		377,133
Production	98,302		—		—		98,302		—		98,302
Operating and maintenance	—		44,519		15,783		60,302		—		60,302

Selling, general and administrative	58,579		15,750		8,728		83,057		15,663		98,720
Depreciation, depletion and amortization	601,553		53,642		26,815		682,010		6,372		688,382
Gain on sale/exchange of long-lived assets	(5,589)		(12)		—		(5,601)		(22)		(5,623)
Impairment and expiration of leases	3,476		—		—		3,476		—		3,476
Other operating expenses	(2,409)		4,624		—		2,215		32,454		34,669
Total operating expenses	1,445,429		118,523		51,326		1,615,278		(259,917)		1,355,361
Operating income (loss)	$	370,337	$	202,629	$	85,387	$	658,353	$	(55,143)	$	603,210

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


	Nine Months Ended September 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	$	6,566,216	$	—	$	—	$	6,566,216	$	(8,459)	$	6,557,757
Loss on derivatives	(88,716)		—		—		(88,716)		(4,626)		(93,342)
Pipeline and other	22,750		1,008,031		432,663		1,463,444		(968,789)		494,655
Total operating revenues	6,500,250		1,008,031		432,663		7,940,944		(981,874)		6,959,070
Operating expenses (a):
Transportation and processing	2,133,775		—		—		2,133,775		(977,628)		1,156,147
Production	307,573		—		—		307,573		—		307,573
Operating and maintenance	—		129,895		43,745		173,640		1,824		175,464
Purchased commodities	—		—		—		—		8,183		8,183
Selling, general and administrative	179,293		66,267		24,285		269,845		48,427		318,272
Depreciation, depletion and amortization	1,721,133		168,331		74,813		1,964,277		19,890		1,984,167
(Gain) loss on sale/exchange of long-lived assets	(33)		(9)		725		683		(24)		659
Impairment and expiration of leases	16,062		—		—		16,062		—		16,062
Other operating expenses	87,148		74		2,250		89,472		13,612		103,084
Total operating expenses	4,444,951		364,558		145,818		4,955,327		(885,716)		4,069,611
Operating income (loss)	$	2,055,299	$	643,473	$	286,845	$	2,985,617	$	(96,158)	$	2,889,459

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


	Nine Months Ended September 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	$	5,622,843	$	—	$	—	$	5,622,843	$	—	$	5,622,843
Gain on derivatives	176,829		—		—		176,829		—		176,829
Pipeline and other	5,919		976,734		417,567		1,400,220		(943,752)		456,468
Total operating revenues	5,805,591		976,734		417,567		7,199,892		(943,752)		6,256,140
Operating expenses (a):
Transportation and processing	2,086,256		—		—		2,086,256		(941,798)		1,144,458
Production	278,258		—		—		278,258		—		278,258
Operating and maintenance	—		121,425		40,157		161,582		—		161,582

Selling, general and administrative	153,957		44,068		26,254		224,279		47,491		271,770
Depreciation, depletion and amortization	1,685,965		157,098		72,750		1,915,813		16,815		1,932,628
(Gain) loss on sale/exchange of long-lived assets	(2,717)		(12)		349		(2,380)		(22)		(2,402)
Impairment and expiration of leases	9,391		—		—		9,391		—		9,391
Other operating expenses	25,248		14,920		(536)		39,632		187,325		226,957
Total operating expenses	4,236,358		337,499		138,974		4,712,831		(690,189)		4,022,642
Operating income (loss)	$	1,569,233	$	639,235	$	278,593	$	2,487,061	$	(253,563)	$	2,233,498

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands)
Total segment operating income	$	505,925	$	658,353	$	2,985,617	$	2,487,061
Less:
Intersegment eliminations	8,459		686		8,459		2,075
Unallocated amounts:
Loss on derivatives	4,626		—		4,626		—
Other revenues	(8,825)		(10)		(8,839)		(121)
Operating and maintenance	1,824		—		1,824		—
Purchased commodities	8,183		—		8,183		—
Selling, general and administrative	19,451		15,663		48,427		47,491
Depreciation and amortization	7,329		6,372		19,890		16,815
Gain on sale/exchange of long-lived assets	(16)		(22)		(24)		(22)
Other operating expenses (a)	5,433		32,454		13,612		187,325
Income from investments (b)	(43,688)		(44,638)		(165,929)		(138,274)
Other income	(780)		(472)		(4,302)		(3,711)
Loss on debt extinguishment	18		1,909		29,887		19,478
Interest expense, net	72,152		109,929		244,381		333,166
Income before income taxes	$	431,759	$	536,482	$	2,785,422	$	2,022,839

(a)For the three months ended September 30, 2025, unallocated other operating expenses consisted primarily of transaction costs related to the Olympus Energy Acquisition (defined in Note 11) and costs related to the Company's new ventures and energy transition initiatives. In addition, for the nine months ended September 30, 2025, unallocated other operating expenses included expense, net of insurance recoveries, 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 $44.7 million and $42.9 million for the three months ended September 30, 2026 and 2025, respectively, and $145.9 million and $108.9 million for the nine months ended September 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)
September 30, 2026
Investment in the MVP Joint Venture	$	—	$	—	$	3,818,891	$	3,818,891
Goodwill	—		—		1,231,783		1,231,783
Other segment assets	23,321,140		8,909,675		2,822,864		35,053,679
Total assets	$	23,321,140	$	8,909,675	$	7,873,538	$	40,104,353

September 30, 2025
Investment in the MVP Joint Venture	$	—	$	—	$	3,481,773	$	3,481,773
Goodwill	—		—		1,231,783		1,231,783
Other segment assets	23,641,401		8,601,123		2,896,820		35,139,344
Total assets	$	23,641,401	$	8,601,123	$	7,610,376	$	39,852,900

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Reconciliation of total segment assets to consolidated total assets.


	September 30,
	2026		2025

	(Thousands)
Total segment assets	$	40,104,353	$	39,852,900
Intersegment eliminations	(203,958)		(246,454)
Unallocated amounts:
Cash and cash equivalents	78,715		235,736

Other property, plant and equipment, at cost less accumulated depreciation	212,960		109,136
Goodwill	830,679		830,679

Other	419,110		413,293
Total assets	$	41,441,859	$	41,195,290

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands)
Upstream	$	457,956	$	490,874	$	1,429,637	$	1,349,069
Gathering	151,152		104,998		414,192		263,185
Transmission	5,447		13,000		24,380		35,918
Total segment capital expenditures	614,555		608,872		1,868,209		1,648,172
Other corporate items	23,209		9,021		43,649		20,724
Total capital expenditures	$	637,764	$	617,893	$	1,911,858	$	1,668,896

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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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 September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands)
Revenues from contracts with customers:
Upstream sales
Natural gas	$	1,346,005	$	1,514,172	$	6,024,670	$	5,103,327
NGLs	144,954		139,326		454,969		458,246
Oil	25,308		24,119		86,577		61,270
Sales of natural gas, NGLs and oil	1,516,267		1,677,617		6,566,216		5,622,843

Gathering pipeline revenue
Firm reservation fees	179,724		144,259		513,836		480,547
Volumetric-based fees	152,004		176,893		494,195		496,187
Total Gathering pipeline revenue	331,728		321,152		1,008,031		976,734

Transmission pipeline revenue
Firm reservation fees	106,404		101,914		339,251		316,301
Volumetric-based fees	23,642		34,799		93,412		101,266
Total Transmission pipeline revenue	130,046		136,713		432,663		417,567

Intersegment eliminations	(325,757)		(315,070)		(986,087)		(943,873)
Other revenues	8,825		10		8,839		121
Total revenues from contracts with customers (a)	1,661,109		1,820,422		7,029,662		6,073,392

Other sources of revenue:
Gain (loss) on derivatives	100,287		135,784		(93,342)		176,829
Other revenues	8,998		2,365		22,750		5,919
Total other sources of revenue	109,285		138,149		(70,592)		182,748

Total operating revenues	$	1,770,394	$	1,958,571	$	6,959,070	$	6,256,140

(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 $530.8 million and $1,159.0 million as of September 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 September 30, 2026.


	2026 (a)		2027		2028		2029		2030		Thereafter		Total

	(Thousands)
Upstream natural gas sales	$	7,887	$	13,648	$	3,973	$	—	$	—	$	—	$	25,508

Gathering firm reservation fee revenue:
Third-party	22,560		86,615		86,260		86,260		86,260		288,112		656,067
Affiliate	25,464		101,508		97,701		97,701		103,978		1,403,698		1,830,050
Total	48,024		188,123		183,961		183,961		190,238		1,691,810		2,486,117

Gathering revenues from MVCs:
Third-party	25,530		96,894		87,869		76,187		66,445		149,334		502,259
Affiliate	103,571		410,929		412,049		410,930		408,322		1,634,128		3,379,929
Total	129,101		507,823		499,918		487,117		474,767		1,783,462		3,882,188

Transmission firm reservation fee revenue:
Third-party	51,749		178,560		172,626		169,923		166,411		661,778		1,401,047
Affiliate	66,041		262,637		260,777		260,445		260,445		1,704,604		2,814,949
Total	117,790		441,197		433,403		430,368		426,856		2,366,382		4,215,996

Other revenues	2,664		4,358		—		—		—		—		7,022
Total remaining performance obligations	$	305,466	$	1,155,149	$	1,121,255	$	1,101,446	$	1,091,861	$	5,841,654	$	10,616,831

(a)October 1 through December 31.

As of September 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 September 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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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 1,000 billion cubic feet (Bcf) of natural gas and 4,605 thousand barrels (Mbbl) of NGLs as of September 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 September 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 long-term debt securities' 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 long-term debt securities' credit rating assigned by Moody's, S&P or Fitch is below the agreed-upon credit rating threshold and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the Company can require the counterparty to deposit collateral with the Company. Such collateral can be up to 100% of the derivative liability. Investment grade refers to the quality of a company's credit as assessed by one or more credit rating agencies. To be considered investment grade, a company must be rated "Baa3" or higher by Moody's, "BBB–" or higher by S&P and "BBB–" or higher by Fitch. Anything below these ratings is considered non-investment grade. As of September 30, 2026, EQT's senior notes (i.e., its long-term debt securities) were rated "Baa3" by Moody's, "BBB–" by S&P and "BBB" by Fitch.

When the net fair value of any of the Company's OTC derivative instrument contracts represents a liability to the Company that is in excess of the agreed-upon dollar threshold for the Company's then-applicable credit rating, the counterparty has the right to require the Company to remit funds as a margin deposit in an amount equal to the portion of the derivative liability that is in excess of the dollar threshold amount. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. As of September 30, 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 $4.2 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 September 30, 2026 and December 31, 2025, there were no such deposits recorded in the Condensed Consolidated Balance Sheets.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

When the Company enters into exchange traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good faith deposits to guard against the risks associated with changing market conditions. The Company is required to make such deposits based on an established initial margin requirement and the net liability position, if any, of the fair value of the associated contracts. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. When the fair value of such contracts is in a net asset position, the broker may remit funds to the Company. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the contract. The margin requirements are subject to change at the exchanges' discretion. As of September 30, 2026 and December 31, 2025, there was $25.3 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)
September 30, 2026
Asset derivative instruments, at fair value	$	185,211	$	(37,600)	$	—	$	147,611
Liability derivative instruments, at fair value	62,860		(37,600)		(25,260)		—

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, Secured Overnight Financing Rate (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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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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


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

	(Thousands)
September 30, 2026
Asset derivative instruments, at fair value	$	185,211	$	18,012	$	167,199	$	—
Liability derivative instruments, at fair value	62,860		16,860		46,000		—

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 September 30, 2026 and December 31, 2025, the Company's senior notes had a fair value of approximately $5.2 billion and $7.7 billion, respectively, and a carrying value of approximately $5.2 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 nine months ended September 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 nine months ended September 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.

For the nine months ended September 30, 2026 and 2025, the Company recorded income tax expense at an effective tax rate of 21.7% and 21.9%, respectively. The Company's effective tax rate for the nine months ended September 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 nine months ended September 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.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

7. Debt

The table below summarizes the Company's outstanding debt.


	September 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	$	63,000	$	63,000		$	75,000	$	75,000
Eureka's revolving credit facility maturing November 13, 2027	270,000		270,000			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		114,710
6.500% notes due July 1, 2027	—		—			344,921		346,255
3.900% notes due October 1, 2027	533,809		533,314			936,158		934,640
5.700% notes due April 1, 2028	500,000		496,603			500,000		494,905
5.500% notes due July 15, 2028	45,225		45,133			45,225		45,060
5.00% notes due January 15, 2029	318,494		316,946			318,494		316,448
4.50% notes due January 15, 2029	299,560		292,255			734,583		710,802
6.375% notes due April 1, 2029	48,989		49,405			596,725		602,840
7.000% notes due February 1, 2030 (b)	674,800		672,729			674,800		672,263
7.500% notes due June 1, 2030	494,086		517,965			494,086		522,749
4.75% notes due January 15, 2031	1,090,218		1,050,961			1,090,218		1,044,098
3.625% notes due May 15, 2031	435,165		432,004			435,165		431,496
5.750% notes due February 1, 2034	750,000		744,184			750,000		743,589
6.500% notes due July 15, 2048	67,196		68,053			67,196		68,064
Total debt	5,590,542		5,552,552			7,855,486		7,800,328
Less: Current portion of debt (c)	—		—			507,915		507,119
Long-term debt	$	5,590,542	$	5,552,552		$	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 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 nine months ended September 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
7.75% debentures due July 15, 2026 (c)	115,000		—		4,456		119,456
Total	$	2,237,944	$	20,586	$	44,351	$	2,302,881

(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.

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

As of both September 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 September 30, 2026 and 2025, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $616 million and $283 million, respectively, the average daily balance was approximately $283 million and $88 million, respectively, and interest was incurred at a weighted average annual interest rate of 5.3% and 5.9%, respectively. During the nine months ended September 30, 2026 and 2025, under EQT's revolving credit facility, the maximum amount of outstanding borrowings was $616 million and $566 million, respectively, the average daily balance was approximately $180 million and $120 million, respectively, and interest was incurred at a weighted average annual interest rate of 5.3% 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 September 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 September 30, 2026 and December 31, 2025, Eureka had no letters of credit outstanding under its revolving credit facility.

During the three months ended September 30, 2026 and 2025, under Eureka's revolving credit facility, the maximum amount of outstanding borrowings was $272 million and $282 million, respectively, the average daily balance was approximately $270 million and $280 million, respectively, and interest was incurred at a weighted average annual interest rate of 6.5% and 6.9%, respectively. During the nine months ended September 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 $274 million and $291 million, respectively, and interest was incurred at a weighted average annual interest rate of 6.5% and 7.1%, respectively.

As of September 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)

EQT's Commercial Paper Program. On October 7, 2026, EQT established a commercial paper program (the Commercial Paper Program) pursuant to which EQT may issue unsecured commercial paper notes (Commercial Paper Notes) in an aggregate principal amount outstanding at any time not to exceed $3.5 billion. The Commercial Paper Notes may have maturities of up to 397 days from the date of issuance and are expected to be sold at a discount from par or, if interest bearing, at par. The net proceeds of the issuances of the Commercial Paper Notes are expected to be used for general corporate purposes, including, but not limited to, funding working capital, capital expenditures, acquisitions and repayment of other indebtedness. EQT expects to use its revolving credit facility as a liquidity backstop for any issuance under the Commercial Paper Program, and EQT intends to maintain available capacity under its revolving credit facility in an amount at least equal to the aggregate principal amount of Commercial Paper Notes outstanding under the Commercial Paper Program. As of October 20, 2026, EQT had not issued any Commercial Paper Notes under the Commercial Paper Program.

8. Investments in Unconsolidated Entities

Equity Method Investments

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


	September 30, 2026				December 31, 2025
	Ownership Interest		Carrying Value		Ownership Interest		Carrying Value

			(Thousands)				(Thousands)
MVP Joint Venture (a):
MVP A	53.2	%	$	3,266,104	49.3	%	$	3,097,754
MVP B	47.2	%	146,063		47.2	%	42,420
MVP C	53.2	%	406,724		49.3	%	374,629
Total MVP Joint Venture			3,818,891				3,514,803

Laurel Mountain Midstream, LLC (b)	31.0	%	46,814		31.0	%	47,037
Other			47,246				35,724
Total			$	3,912,951			$	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 September 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 September 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.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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.

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. In October 2026, based on the remaining capital commitments, the Company's performance guarantee in favor of MVP B was reduced to $14.2 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 September 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.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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 September 30, 2026 and December 31, 2025, the fair value of the Company's investment in the Investment Fund was approximately $46 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.

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 September 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 nine months ended September 30, 2026, the Midstream Joint Venture paid distributions of $355.1 million to the BXCI Affiliate. Distributions from the Midstream Joint Venture to the Company are eliminated in consolidation. As of September 30, 2026, the remaining amount required to achieve the Base Return was approximately $3.3 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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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 September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands, except per share amounts)
Net income attributable to EQT Corporation – Basic and diluted income available to shareholders	$	278,691	$	335,862	$	1,977,345	$	1,362,148




Weighted average common stock outstanding – Basic	625,991		624,532		625,696		607,245
Stock options, restricted stock and performance awards (a)	3,181		3,792		3,296		4,182

Weighted average common stock outstanding – Diluted	629,172		628,324		628,992		611,427

Income per share of common stock attributable to EQT Corporation:
Basic	$	0.45	$	0.54	$	3.16	$	2.24
Diluted	$	0.44	$	0.53	$	3.14	$	2.23

(a)Excludes securities that would have had an antidilutive effect on diluted income per share, which had a weighted average, in thousands, of 3,654 and 702 for the three months ended September 30, 2026 and 2025, respectively, and 2,099 and 615 for the nine months ended September 30, 2026 and 2025, respectively. Such antidilutive securities included the stock options described in Note 12, which have exercise prices exceeding the average stock price of EQT common stock.

11. Acquisitions

Range Merger

On October 25, 2026, EQT, EQT Holdings LLC, a Delaware limited liability company and an indirect wholly owned subsidiary of EQT, Rhino Merger Sub Inc., a Delaware corporation and an indirect wholly owned subsidiary of EQT (Merger Sub), and Rhino Merger Sub LLC, a Delaware limited liability company and an indirect wholly owned subsidiary of EQT (LLC Sub), entered into an Agreement and Plan of Merger (the Merger Agreement) with Range Resources Corporation, a Delaware corporation (Range). Upon the terms and subject to the conditions set forth in the Merger Agreement, Merger Sub will merge with and into Range (the First Merger), with Range surviving as an indirect wholly owned subsidiary of EQT (the First Step Surviving Corporation), and as the second step in a single integrated transaction with the First Merger, the First Step Surviving Corporation will merge with and into LLC Sub (the Second Merger and, together with the First Merger, the Range Merger), with LLC Sub surviving the Second Merger as an indirect wholly owned subsidiary of EQT.

As a result of the Range Merger, except as otherwise provided in the Merger Agreement, among other things, each share of common stock, par value $0.01 per share, of Range (Range common stock) that is issued and outstanding immediately prior to the effective time of the First Merger (including Range restricted stock awards but excluding Excluded Shares (as defined in the Merger Agreement)) will be converted into the right to receive, without interest, 0.987 shares of EQT common stock (with cash in lieu of fractional shares). It is currently expected that, upon closing of the Range Merger, EQT's existing shareholders will own approximately 73% of the combined company and Range's existing shareholders will own approximately 27% of the combined company on a fully diluted basis. Also upon closing of the Range Merger, two representatives from Range, including Range's current Chief Executive Officer and President, will join EQT's Board of Directors.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

The transaction is currently expected to close during the first quarter of 2027 and is subject to the satisfaction or waiver of certain closing conditions, including (i) the adoption of the Merger Agreement by the holders of a majority of the voting power of the outstanding shares of Range common stock entitled to vote thereon, (ii) the approval of the issuance of the shares of EQT common stock in connection with the First Merger by a majority of the votes cast at the special meeting of EQT's shareholders to be held in connection with the Range Merger, (iii) there being no law, injunction, order or decree prohibiting consummation of the transaction and (iv) the expiration or termination of (a) all waiting periods (and any extensions thereof) applicable to the transaction under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and (b) any commitment to, or any agreement with, any governmental entity to delay the consummation of the transaction or to not consummate the transaction before a certain date (such condition, the HSR Act Condition).

The Merger Agreement contains certain termination rights for both EQT and Range, including the right of either party, subject to certain limitations specified therein, to terminate the Merger Agreement if the First Merger is not consummated on or prior to October 25, 2027, which date will be automatically extended until April 25, 2028 if all of the conditions to closing, other than the condition relating to the absence of law, injunction, order or decree prohibiting consummation of the Range Merger or the HSR Act Condition, have been satisfied or waived. Upon termination of the Merger Agreement under certain circumstances specified therein, (i) Range will be required to pay EQT a termination fee equal to $423 million, and (ii) EQT will be required to pay Range a termination fee equal to $1,148 million.

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 majority of the purchase price was allocated to property, plant and equipment. The Company funded the consideration with borrowings under EQT's revolving credit facility.

Olympus Energy Acquisition

On July 1, 2025, the Company completed its 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. The purchase price for the Olympus Energy Acquisition consisted of 25,229,166 shares of EQT common stock, with an aggregate value of approximately $1,471 million, and approximately $473 million in cash, each as adjusted pursuant to customary purchase price adjustments and final post-closing purchase price adjustments.

12. 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.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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

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. During the three and nine months ended September 30, 2026, the Company recognized $4.9 million and $8.3 million, respectively, of compensation cost related to this grant. The Company expects to recognize $65.3 million of unrecognized compensation cost over a weighted average remaining period of 3.6 years.

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

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

The following discussion and analysis of financial condition and results of operations should be read in conjunction with the Condensed Consolidated Financial Statements and the notes thereto included in this report. Unless the context otherwise indicates, all references in this report to "EQT" are to EQT Corporation and all references in this report to the "Company," "we," "us," or "our" are to EQT Corporation and its consolidated subsidiaries, collectively. For certain industry specific terms used in this Quarterly Report on Form 10-Q, please see "Glossary of Commonly Used Terms, Abbreviations and Measurements" in 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; pending and potential acquisitions or other strategic transactions, including the Range Merger (defined in Note 11 to the Condensed Consolidated Financial Statements), 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 our 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

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

venture arrangements; government regulation or action, including regulations pertaining to methane and other greenhouse gas emissions; negative public perception of the fossil fuels industry; increased consumer demand for alternatives to natural gas; environmental and weather risks, including the possible impacts of climate change; disruptions to our business due to recently completed or pending divestitures, acquisitions and other significant strategic transactions, including the Range Merger; and risks related to the Range Merger, including potential delays in consummating the potential transaction, including as a result of regulatory proceedings, the risk that our shareholders or Range Resources Corporation's (Range) shareholders do not approve the potential transaction, the risk that regulatory approvals are not obtained or are obtained subject to conditions that are not anticipated by us, our ability to integrate Range's operations in a successful manner and in the expected time period and the possibility that any of the anticipated benefits and projected synergies of the potential transaction will not be realized or will not be realized within the expected time period. 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

Range Merger

On October 25, 2026, we entered into the Merger Agreement (defined in Note 11 to the Condensed Consolidated Financial Statements) with Range to effect the Range Merger. Pursuant to the Merger Agreement, each share of Range common stock will be converted into the right to receive, without interest, 0.987 shares of EQT common stock with cash in lieu of fractional shares. Consummation of the Range Merger is subject to the satisfaction or waiver of certain closing conditions, including regulatory approvals, approval by EQT's shareholders and approval by Range's shareholders. Range is a leading U.S. independent natural gas and NGL producer with operations focused in the Appalachian Basin and with acreage directly offsetting our core positions in both Southwest and Northeast Pennsylvania. See Note 11 to the Condensed Consolidated Financial Statements for more information on the Merger Agreement and the Range Merger.

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

Beginning July 1, 2025, our financial results 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.

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Trends and Uncertainties

Commodity prices have been volatile thus far in 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 production curtailments from time to time. During the third quarter of 2026, strategic production curtailments resulted in decreased sales volumes of approximately 21 billion cubic feet equivalent (Bcfe). Our sales volume guidance for the fourth quarter of 2026 includes approximately 10 Bcfe to 20 Bcfe of strategic production curtailments, subject to market conditions. 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.

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 September 30, 2026 was approximately $279 million, $0.44 per diluted share, compared to approximately $336 million, $0.53 per diluted share, for the same period in 2025. The decrease was driven primarily by lower natural gas sales resulting from lower sales volume, as well as lower derivative gains, partly offset by lower production depletion expense, lower income tax expense and lower interest expense.

Net income attributable to EQT Corporation for the nine months ended September 30, 2026 was approximately $1,977 million, $3.14 per diluted share, compared to approximately $1,362 million, $2.23 per diluted share, for the same period in 2025. The increase was driven primarily by higher natural gas sales resulting from higher average sales price as well as lower interest expense and lower legal reserves, partly offset by a loss on derivatives in 2026 compared to a gain in 2025, higher income tax expense and higher depreciation and depletion 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.

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EQT CORPORATION AND SUBSIDIARIES

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

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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EQT CORPORATION AND SUBSIDIARIES

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)	544,536		595,642		1,722,847		1,666,421
NYMEX price ($/MMBtu)	$	2.96	$	3.07	$	3.60	$	3.37
Btu uplift	0.16		0.17		0.20		0.19
Natural gas price ($/Mcf)	$	3.12	$	3.24	$	3.80	$	3.56

Basis ($/Mcf) (a)	$	(0.65)	$	(0.70)	$	(0.31)	$	(0.50)
Cash settled basis swaps ($/Mcf)	0.01		0.02		(0.11)		(0.02)
Average differential, including cash settled basis swaps ($/Mcf)	(0.64)		(0.68)		(0.42)		(0.52)
Average adjusted price ($/Mcf)	2.48		2.56		3.38		3.04
Cash settled derivatives ($/Mcf)	0.12		0.10		0.02		(0.05)
Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.60	$	2.66	$	3.40	$	2.99
Natural gas sales, including cash settled derivatives	$	1,417,219	$	1,586,374	$	5,865,609	$	4,987,247

LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)	21,025		23,650		62,334		66,997
Sales volume (Mbbl)	3,504		3,942		10,389		11,166
NGL price ($/Bbl)	$	36.73	$	31.82	$	38.08	$	37.12
Cash settled derivatives ($/Bbl)	(0.31)		0.70		(0.18)		(0.21)
Average NGL price, including cash settled derivatives ($/Bbl)	$	36.42	$	32.52	$	37.90	$	36.91
NGL sales, including cash settled derivatives	$	127,636	$	128,183	$	393,789	$	412,206
Ethane:
Sales volume (MMcfe) (b)	14,923		12,157		41,561		32,759
Sales volume (Mbbl)	2,488		2,026		6,927		5,460
Ethane price ($/Bbl)	$	6.52	$	6.86	$	8.56	$	8.01
Ethane sales	$	16,223	$	13,901	$	59,312	$	43,730
Oil:
Sales volume (MMcfe) (b)	2,318		2,946		8,233		7,196
Sales volume (Mbbl)	386		491		1,372		1,199
Oil price ($/Bbl)	$	65.51	$	49.12	$	63.09	$	51.09
Oil sales	$	25,308	$	24,119	$	86,577	$	61,270

Total liquids sales volume (MMcfe) (b)	38,266		38,753		112,128		106,952
Total liquids sales volume (Mbbl)	6,378		6,459		18,688		17,825
Total liquids sales	$	169,167	$	166,203	$	539,678	$	517,206

TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,586,386	$	1,752,577	$	6,405,287	$	5,504,453
Total sales volume (MMcfe)	582,802		634,395		1,834,975		1,773,373
Average realized price ($/Mcfe)	$	2.72	$	2.76	$	3.49	$	3.10

(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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EQT CORPORATION AND SUBSIDIARIES

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

Non-GAAP Financial Measures Reconciliation

The table below reconciles 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 Upstream 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 Upstream 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, because it is unrelated to the revenue from our natural gas and liquids production.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Thousands, unless otherwise noted)
Total Upstream operating revenues	$	1,630,178	$	1,815,766	$	6,500,250	$	5,805,591
(Deduct) add:
Upstream (gain) loss on derivatives	(104,913)		(135,784)		88,716		(176,829)
Upstream net cash settlements received (paid) on derivatives (a)	70,119		74,960		(160,929)		(118,390)

Upstream other revenues	(8,998)		(2,365)		(22,750)		(5,919)
Upstream adjusted operating revenues, a non-GAAP financial measure	$	1,586,386	$	1,752,577	$	6,405,287	$	5,504,453

Total sales volume (MMcfe)	582,802		634,395		1,834,975		1,773,373
Average sales price ($/Mcfe)	$	2.60	$	2.64	$	3.58	$	3.17
Average realized price ($/Mcfe)	$	2.72	$	2.76	$	3.49	$	3.10

(a)Upstream net cash settlements received (paid) on derivatives are included in average realized price but may not be included in total Upstream operating revenues. For the three months ended September 30, 2026, Upstream net cash settlements received on derivatives consisted of net cash settlements received on NYMEX natural gas hedge positions of approximately $68 million and net cash settlements received on basis and liquids hedge positions of approximately $2 million. For the three months ended September 30, 2025, Upstream net cash settlements received on derivatives consisted of net cash settlements received on NYMEX natural gas hedge positions of approximately $59 million and net cash settlements received on basis and liquids hedge positions of approximately $16 million.

For the nine months ended September 30, 2026, Upstream net cash settlements paid on derivatives consisted of net cash settlements paid on basis and liquids hedge positions of approximately $191 million and net cash settlements received on NYMEX natural gas hedge positions of approximately $30 million. For the nine months ended September 30, 2025, Upstream net cash settlements paid on derivatives consisted of net cash settlements paid on NYMEX natural gas hedge positions of approximately $86 million and net cash settlements paid on basis and liquids hedge positions of approximately $32 million.

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EQT CORPORATION AND SUBSIDIARIES

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

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.

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.

Cash and cash equivalents, debt, income taxes, amounts related to our corporate function and other items managed on a consolidated basis as well as items related to our downstream liquefied propane gas business, new ventures and energy transition initiatives have not been allocated to our reportable segments. These items are presented as "Other" and discussed under "Other Income Statement Items."

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EQT CORPORATION AND SUBSIDIARIES

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

Upstream Results of Operations


	Three Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Total sales volume (MMcfe)	582,802		634,395		(51,593)		(8.1)
Average daily sales volume (MMcfe/d)	6,335		6,896		(561)		(8.1)
Average sales price ($/Mcfe)	$	2.60	$	2.64	$	(0.04)	(1.5)

Operating revenues:
Sales of natural gas, NGLs and oil	$	1,516,267	$	1,677,617	$	(161,350)	(9.6)
Gain on derivatives	104,913		135,784		(30,871)		(22.7)
Other revenues	8,998		2,365		6,633		280.5
Total operating revenues	1,630,178		1,815,766		(185,588)		(10.2)
Operating expenses:
Transportation and processing:
Gathering	50,215		39,786		10,429		26.2
Transmission	250,363		253,242		(2,879)		(1.1)
Processing	70,213		84,105		(13,892)		(16.5)
Transportation and processing to affiliate (a)	317,298		314,384		2,914		0.9
Total transportation and processing	688,089		691,517		(3,428)		(0.5)
Lease operating expense (LOE)	60,265		58,103		2,162		3.7
Production taxes	31,814		40,199		(8,385)		(20.9)
Selling, general and administrative	62,217		58,579		3,638		6.2
Production depletion	548,796		600,256		(51,460)		(8.6)
Other depreciation and depletion	1,166		1,297		(131)		(10.1)
Gain on sale/exchange of long-lived assets	(2,868)		(5,589)		2,721		(48.7)
Impairment and expiration of leases	6,007		3,476		2,531		72.8
Other operating expenses	15,052		(2,409)		17,461		(724.8)
Total operating expenses	1,410,538		1,445,429		(34,891)		(2.4)
Operating income	$	219,640	$	370,337	$	(150,697)	(40.7)

Per Unit ($/Mcfe):
Gathering	$	0.09	$	0.06	$	0.03	50.0
Transmission	0.43		0.40		0.03		7.5
Processing	0.12		0.13		(0.01)		(7.7)
Transportation and processing to affiliate (a)	0.54		0.50		0.04		8.0
LOE	0.10		0.09		0.01		11.1
Production taxes	0.05		0.06		(0.01)		(16.7)
Selling, general and administrative	0.11		0.09		0.02		22.2
Production depletion	0.94		0.95		(0.01)		(1.1)

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

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Sales of Natural Gas, NGLs and Oil. Sales of natural gas, NGLs and oil decreased by approximately $161 million for the three months ended September 30, 2026 compared to the same period in 2025, reflecting decreases of approximately $136 million from decreased sales volumes and approximately $25 million from lower average sales price.

Sales volume decreased for the three months ended September 30, 2026 compared to the same period for 2025 due primarily to strategic production curtailments of 21 Bcfe as well as normal production declines that outpaced sales volumes from wells turned-in-line since the third quarter of 2025.

Average sales price decreased for the three months ended September 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 NGL prices.

Gain on Derivatives. For the three months ended September 30, 2026, we recognized a gain on derivatives of approximately $105 million related primarily to increases in the fair market value of our NYMEX swaps and options of approximately $109 million due to decreases in NYMEX forward prices, partly offset by decreases in the fair market value of our basis and liquids swaps of approximately $4 million. For the three months ended September 30, 2025, we recognized a gain on derivatives of approximately $136 million related primarily to increases in the fair market value of our NYMEX swaps and options of approximately $266 million due to decreases in NYMEX forward prices, partly offset by decreases in the fair market value of our basis and liquids swaps of approximately $130 million.

Gathering Expense. Gathering expense increased on an absolute and per Mcfe basis for the three months ended September 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 September 30, 2026 compared to the same period in 2025 due primarily to decreased production of gas that requires processing.

Transportation and Processing Expense to Affiliate. Affiliate transportation and processing expense increased on an absolute basis for the three months ended September 30, 2026 compared to the same period in 2025 due primarily to additional contracted capacity and higher rates under certain gas gathering agreements with our Gathering segment, partly offset by lower gathered volumes under certain gas gathering agreements with our Gathering segment. On a per Mcfe basis, affiliate transportation and processing expense increased due primarily to decreased sales volumes.

Production Depletion Expense. Production depletion expense decreased on an absolute basis for the three months ended September 30, 2026 compared to the same period in 2025 due primarily to decreased sales volumes and a lower annual depletion rate.

Other Operating Expenses. Other operating expenses increased on an absolute basis for the three months ended September 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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EQT CORPORATION AND SUBSIDIARIES

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


	Nine Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Total sales volume (MMcfe)	1,834,975		1,773,373		61,602		3.5
Average daily sales volume (MMcfe/d)	6,722		6,496		226		3.5
Average sales price ($/Mcfe)	$	3.58	$	3.17	$	0.41	12.9

Operating revenues:
Sales of natural gas, NGLs and oil	$	6,566,216	$	5,622,843	$	943,373	16.8
(Loss) gain on derivatives	(88,716)		176,829		(265,545)		(150.2)
Other revenues	22,750		5,919		16,831		284.4
Total operating revenues	6,500,250		5,805,591		694,659		12.0
Operating expenses:
Transportation and processing:
Gathering	164,020		132,700		31,320		23.6
Transmission	767,683		761,830		5,853		0.8
Processing	224,444		249,928		(25,484)		(10.2)
Transportation and processing to affiliate (a)	977,628		941,798		35,830		3.8
Total transportation and processing	2,133,775		2,086,256		47,519		2.3
LOE	176,814		151,695		25,119		16.6
Production taxes	130,759		126,563		4,196		3.3
Selling, general and administrative	179,293		153,957		25,336		16.5
Production depletion	1,717,621		1,682,395		35,226		2.1
Other depreciation and depletion	3,512		3,570		(58)		(1.6)
Gain on sale/exchange of long-lived assets	(33)		(2,717)		2,684		(98.8)
Impairment and expiration of leases	16,062		9,391		6,671		71.0
Other operating expenses	87,148		25,248		61,900		245.2
Total operating expenses	4,444,951		4,236,358		208,593		4.9
Operating income	$	2,055,299	$	1,569,233	$	486,066	31.0

Per Unit ($/Mcfe):
Gathering	$	0.09	$	0.07	$	0.02	28.6
Transmission	0.42		0.43		(0.01)		(2.3)
Processing	0.12		0.14		(0.02)		(14.3)
Transportation and processing to affiliate (a)	0.53		0.53		—		—
LOE	0.10		0.09		0.01		11.1
Production taxes	0.07		0.07		—		—
Selling, general and administrative	0.10		0.09		0.01		11.1
Production depletion	0.94		0.95		(0.01)		(1.1)

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

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EQT CORPORATION AND SUBSIDIARIES

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

Sales of Natural Gas, NGLs and Oil. Sales of natural gas, NGLs and oil increased by approximately $943 million for the nine months ended September 30, 2026 compared to the same period in 2025, reflecting increases of approximately $748 million from higher average sales price and approximately $195 million from increased sales volumes.

Average sales price increased for the nine months ended September 30, 2026 compared to the same period for 2025 due primarily to a higher NYMEX price, a favorable basis differential and higher NGL prices.

Sales volume increased for the nine months ended September 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 and increases from well performance optimization, partly offset by strategic production curtailments of 25 Bcfe as well as normal production declines that outpaced sales volumes from wells turned-in-line in 2025 and 2026.

(Loss) Gain on Derivatives. For the nine months ended September 30, 2026, we recognized a loss on derivatives of approximately $89 million related primarily to decreases in the fair market value of our basis and liquids swaps of approximately $161 million, partly offset by increases in the fair market value of our NYMEX swaps and options of approximately $72 million due to decreases in NYMEX forward prices. For the nine months ended September 30, 2025, we recognized a gain on derivatives of approximately $177 million related primarily to increases in the fair market value of our NYMEX swaps and options of approximately $165 million due to decreases in NYMEX forward prices and increases in the fair market value of our basis and liquids swaps of approximately $12 million.

Gathering Expense. Gathering expense increased on an absolute and per Mcfe basis for the nine months ended September 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 nine months ended September 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 nine months ended September 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 declining rate structures and lower gathered volumes under certain gas gathering agreements with our Gathering segment.

Lease Operating Expense. Lease operating expense increased on an absolute and per Mcfe basis for the nine months ended September 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 operations 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 nine months ended September 30, 2026 compared to the same period in 2025 due primarily to higher long-term incentive compensation costs as well as higher personnel costs resulting from increased headcount.

Production Depletion Expense. Production depletion expense increased on an absolute basis for the nine months ended September 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 nine months ended September 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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EQT CORPORATION AND SUBSIDIARIES

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

Gathering Results of Operations


	Three Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Gathered volume (British thermal unit (BBtu)/d):
Firm capacity (a)	5,824		5,624		200		3.6
Volumetric-based volumes (a)	4,274		5,088		(814)		(16.0)
Total gathered volume	10,098		10,712		(614)		(5.7)

Operating revenues:

Firm reservation fees	$	179,724	$	144,259	$	35,465	24.6
Volumetric-based fees	152,004		176,893		(24,889)		(14.1)
Total operating revenues	331,728		321,152		10,576		3.3
Operating expenses:
Operating and maintenance	40,682		44,519		(3,837)		(8.6)
Selling, general and administrative	26,169		15,750		10,419		66.2
Depreciation	56,382		53,642		2,740		5.1
Gain on sale/exchange of long-lived assets	(9)		(12)		3		(25.0)

Other operating expenses	39		4,624		(4,585)		(99.2)
Total operating expenses	123,263		118,523		4,740		4.0
Operating income	$	208,465	$	202,629	$	5,836	2.9

(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.

Firm Reservation Fees. Firm reservation fee revenue increased for the three months ended September 30, 2026 compared to the same period in 2025 due primarily to increased affiliate revenue of approximately $33 million driven by additional contracted capacity and higher rates under certain gas gathering agreements with our Upstream segment.

Volumetric-Based Fees. Volumetric-based fee revenue decreased for the three months ended September 30, 2026 compared to the same period in 2025 due to decreased affiliate and third-party revenue. Affiliate revenue decreased approximately $20 million due primarily to lower usage under certain gas gathering agreements with our Upstream segment. Third-party revenue decreased approximately $5 million due primarily to lower usage.

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

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EQT CORPORATION AND SUBSIDIARIES

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


	Nine Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Gathered volume (BBtu/d):
Firm capacity (a)	5,819		5,288		531		10.0
Volumetric-based volumes (a)	4,692		4,861		(169)		(3.5)
Total gathered volume	10,511		10,149		362		3.6

Operating revenues:

Firm reservation fees	$	513,836	$	480,547	$	33,289	6.9
Volumetric-based fees	494,195		496,187		(1,992)		(0.4)
Total operating revenues	1,008,031		976,734		31,297		3.2
Operating expenses:
Operating and maintenance	129,895		121,425		8,470		7.0
Selling, general and administrative	66,267		44,068		22,199		50.4
Depreciation	168,331		157,098		11,233		7.2
Gain on sale/exchange of long-lived assets	(9)		(12)		3		(25.0)

Other operating expenses	74		14,920		(14,846)		(99.5)
Total operating expenses	364,558		337,499		27,059		8.0
Operating income	$	643,473	$	639,235	$	4,238	0.7

(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 increased for the nine months ended September 30, 2026 compared to the same period in 2025 due to increased affiliate and third-party revenue. Affiliate revenue increased approximately $21 million due primarily to additional contracted capacity under certain gas gathering agreements with our Upstream segment, partly offset by declining rate structures under certain gas gathering agreements with our Upstream segment. Third-party revenue increased approximately $12 million due primarily to increased contracted MVCs.

Volumetric-Based Fees. Volumetric-based fee revenue decreased for the nine months ended September 30, 2026 compared to the same period in 2025 due to decreased third-party revenue, partly offset by increased affiliate revenue. Third-party revenue decreased approximately $13 million due primarily to lower usage. Affiliate revenue increased approximately $11 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.

Operating and Maintenance Expense. Operating and maintenance expense increased for the nine months ended September 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 nine months ended September 30, 2026 compared to the same period in 2025 due primarily to higher long-term incentive compensation costs and higher professional service costs.

Depreciation Expense. Depreciation expense increased for the nine months ended September 30, 2026 compared to the same period in 2025 due primarily to depreciation of the gathering assets acquired in the Olympus Energy Acquisition and additional assets placed in service in 2026.

Other Operating Expense. During the nine months ended September 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 September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Transmission pipeline throughput (BBtu/d):
Firm capacity (a)	4,330		4,701		(371)		(7.9)
Interruptible capacity	47		13		34		261.5
Total transmission pipeline throughput	4,377		4,714		(337)		(7.1)

Average firm transmission reservation commitments (BBtu/d)	4,975		4,851		124		2.6

Operating revenues:
Firm reservation fees	$	106,404	$	101,914	$	4,490	4.4
Volumetric-based fees	23,642		34,799		(11,157)		(32.1)
Total operating revenues	130,046		136,713		(6,667)		(4.9)
Operating expenses:
Operating and maintenance	17,870		15,783		2,087		13.2
Selling, general and administrative	8,246		8,728		(482)		(5.5)
Depreciation	22,777		23,482		(705)		(3.0)
Amortization of intangible assets	3,333		3,333		—		—


Total operating expenses	52,226		51,326		900		1.8
Operating income	$	77,820	$	85,387	$	(7,567)	(8.9)

(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 September 30, 2026 compared to the same period in 2025 due primarily to increased affiliate revenue of approximately $3 million related to increased firm reservation capacity and higher average reservation rates under certain agreements with our Upstream segment.

Volumetric-Based Fees. Volumetric-based fee revenue decreased for the three months ended September 30, 2026 compared to the same period in 2025 due to decreased affiliate revenue of approximately $11 million related to lower usage and lower overrun charges from our Upstream segment.

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


	Nine Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Transmission pipeline throughput (BBtu/d):
Firm capacity (a)	4,572		4,358		214		4.9
Interruptible capacity	32		37		(5)		(13.5)
Total transmission pipeline throughput	4,604		4,395		209		4.8

Average firm transmission reservation commitments (BBtu/d)	5,213		4,890		323		6.6

Operating revenues:
Firm reservation fees	$	339,251	$	316,301	$	22,950	7.3
Volumetric-based fees	93,412		101,266		(7,854)		(7.8)
Total operating revenues	432,663		417,567		15,096		3.6
Operating expenses:
Operating and maintenance	43,745		40,157		3,588		8.9
Selling, general and administrative	24,285		26,254		(1,969)		(7.5)
Depreciation	64,814		62,751		2,063		3.3
Amortization of intangible assets	9,999		9,999		—		—
Loss on sale/exchange of long-lived assets	725		349		376		107.7
Other operating expenses	2,250		(536)		2,786		(519.8)
Total operating expenses	145,818		138,974		6,844		4.9
Operating income	$	286,845	$	278,593	$	8,252	3.0

(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 nine months ended September 30, 2026 compared to the same period in 2025 due to increased affiliate and third-party revenue. Affiliate revenue increased approximately $16 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 $7 million due primarily to increased short-term firm reservation winter capacity and higher average reservation rates under certain agreements with third parties.

Volumetric-Based Fees. Volumetric-based fee revenue decreased for the nine months ended September 30, 2026 compared to the same period in 2025 due primarily to decreased affiliate revenue of approximately $11 million related to lower usage and lower overrun charges from our Upstream segment, partly offset by increased third-party revenue.

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

Other Income Statement Items


	Three Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Operating revenues:
Loss on derivatives	$	(4,626)	$	—	$	(4,626)	100.0
Other revenues	8,825		10		8,815		88,150.0
Total operating revenues	4,199		10		4,189		41,890.0
Operating expenses:
Operating and maintenance	1,824		—		1,824		100.0
Purchased commodities	8,183		—		8,183		100.0
Selling, general and administrative	19,451		15,663		3,788		24.2
Depreciation	6,970		6,013		957		15.9
Amortization of intangible assets	359		359		—		—
Gain on sale/exchange of long-lived assets	(16)		(22)		6		(27.3)
Other operating expenses	5,433		32,454		(27,021)		(83.3)
Total operating expenses	42,204		54,467		(12,263)		(22.5)
Operating loss	$	(38,005)	$	(54,457)	$	16,452	(30.2)

Income from investments	$	(43,688)	$	(44,638)	$	950	(2.1)
Other income	(780)		(472)		(308)		65.3
Loss on debt extinguishment	18		1,909		(1,891)		(99.1)
Interest expense, net	72,152		109,929		(37,777)		(34.4)
Income tax expense	86,682		129,266		(42,584)		(32.9)
Net income attributable to noncontrolling interests	66,386		71,354		(4,968)		(7.0)

Other Revenues. Other revenues increased for the three months ended September 30, 2026 compared to the same period in 2025 due primarily to revenues from our operation of the propane assets acquired in the Blackline Midstream Acquisition.

Purchased Commodities. For the three months ended September 30, 2026, we recognized approximately $8 million of purchased commodities expense for propane inventory acquired in the Blackline Midstream Acquisition and subsequently sold as part of our operation of the acquired propane storage assets.

Other Operating Expenses. Other operating expenses decreased for the three months ended September 30, 2026 compared to the same period in 2025 due primarily to approximately $21 million of transaction costs recognized in 2025 related to the Olympus Energy Acquisition.

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

Income Tax Expense. See Note 6 to the Condensed Consolidated Financial Statements.

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


	Nine Months Ended September 30,
	2026		2025		Change		% Change

	(Thousands, unless otherwise noted)
Operating revenues:
Loss on derivatives	$	(4,626)	$	—	$	(4,626)	100.0
Other revenues	8,839		121		8,718		7,205.0
Total operating revenues	4,213		121		4,092		3,381.8
Operating expenses:
Operating and maintenance	1,824		—		1,824		100.0
Purchased commodities	8,183		—		8,183		100.0
Selling, general and administrative	48,427		47,491		936		2.0
Depreciation	18,812		15,737		3,075		19.5
Amortization of intangible assets	1,078		1,078		—		—
Gain on sale/exchange of long-lived assets	(24)		(22)		(2)		9.1
Other operating expenses	13,612		187,325		(173,713)		(92.7)
Total operating expenses	91,912		251,609		(159,697)		(63.5)
Operating loss	$	(87,699)	$	(251,488)	$	163,789	(65.1)

Income from investments	$	(165,929)	$	(138,274)	$	(27,655)	20.0
Other income	(4,302)		(3,711)		(591)		15.9
Loss on debt extinguishment	29,887		19,478		10,409		53.4
Interest expense, net	244,381		333,166		(88,785)		(26.6)
Income tax expense	604,967		443,549		161,418		36.4
Net income attributable to noncontrolling interests	203,110		217,142		(14,032)		(6.5)

Other Revenues. Other revenues increased for the nine months ended September 30, 2026 compared to the same period in 2025 due primarily to revenues from our operation of the propane assets acquired in the Blackline Midstream Acquisition.

Purchased Commodities. For the nine months ended September 30, 2026, we recognized approximately $8 million of purchased commodities expense for propane inventory acquired in the Blackline Midstream Acquisition and subsequently sold as part of our operation of the acquired propane storage assets.

Other Operating Expenses. Other operating expenses decreased for the nine months ended September 30, 2026 compared to the same period in 2025 due primarily to approximately $134 million of expense, net of insurance recoveries, recognized in 2025 related to a securities class action settlement as well as approximately $25 million of transaction costs recognized in 2025 related to the Olympus Energy Acquisition.

Income from Investments. Income from investments increased for the nine months ended September 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 $37 million and a favorable change in the fair value of our investment in the Investment Fund (defined in Note 8 to the Condensed Consolidated Financial Statements) of approximately $14 million, partly offset by lower equity earnings from our investment in Laurel Mountain Midstream, LLC.

Loss on Debt Extinguishment. Loss on debt extinguishment increased for the nine months ended September 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 $10 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 nine months ended September 30, 2026.

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EQT CORPORATION AND SUBSIDIARIES

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

Interest Expense, Net. Net interest expense decreased for the nine months ended September 30, 2026 compared to the same period in 2025 due primarily to the redemptions and repurchases of senior notes in 2025 and 2026.

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 and, beginning October 7, 2026, EQT's commercial paper program (the Commercial Paper Program), 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. EQT's revolving credit facility serves as a liquidity backstop for issuances under the Commercial Paper Program, and we intend to maintain available capacity under EQT's revolving credit facility in an amount at least equal to the aggregate principal amount of outstanding commercial paper notes issued under the Commercial Paper Program.

See Note 7 to the Condensed Consolidated Financial Statements for further information on the Commercial Paper Program.

Planned Capital Expenditures, Capital Contributions and Sales Volume

In the fourth quarter of 2026, we expect to spend approximately $725 million to $835 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 and the Commercial Paper Program. 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 fourth quarter of 2026, we expect to make approximately $30 million to $40 million of capital contributions to our equity method investments, including the MVP Joint Venture.

In the fourth quarter of 2026, we expect our sales volume, including expected curtailments, to be 550 Bcfe to 600 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 have agreed to 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.

Sources and Uses of Cash

Operating Activities. Net cash provided by operating activities was approximately $5,186 million and $4,001 million for the nine months ended September 30, 2026 and 2025, respectively. The increase was due primarily to higher sales of natural gas, NGLs and oil, resulting from higher average sales price, as well as favorable changes in working capital and lower net interest expense, partly offset by our receipt of a tax refund in 2025 and higher net cash settlements paid on derivatives.

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EQT CORPORATION AND SUBSIDIARIES

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

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 $2,311 million and $2,224 million for the nine months ended September 30, 2026 and 2025, respectively. The increase was due primarily to increased capital expenditures and cash paid for the MVP A and MVP C Interest Acquisitions, including the portion paid by the BXCI Affiliate, partly offset by lower cash paid for the Blackline Midstream Acquisition in 2026 compared to cash paid for the Olympus Energy Acquisition in 2025.

The following table summarizes our capital expenditures by segment.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025

	(Millions)
Upstream:
Reserve development	$	366	$	391	$	1,147	$	1,122
Land and lease	45		51		126		100
Other upstream infrastructure	12		19		60		47
Capitalized overhead, capitalized interest and other	35		30		97		80
Total Upstream	458		491		1,430		1,349
Gathering	151		105		414		263
Transmission	5		13		24		36
Other corporate items	24		9		44		21
Total capital expenditures	638		618		1,912		1,669
Add (deduct): Non-cash items (a)	9		9		(16)		7
Total cash capital expenditures	$	647	$	627	$	1,896	$	1,676

(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 $2,907 million and $1,743 million for the nine months ended September 30, 2026 and 2025, respectively. For the nine months ended September 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 nine months ended September 30, 2026 were capital contributions from the BXCI Affiliate related to the MVP A Interest Acquisition of approximately $98 million. For the nine months ended September 30, 2025, the primary uses of financing cash flows were the repayment and retirement of debt, payment of dividends, distributions to the BXCI Affiliate and net repayment of revolving credit facility borrowings.

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

On October 14, 2026, our Board of Directors declared a quarterly cash dividend of $0.17 per share of EQT common stock, payable on December 1, 2026, to shareholders of record at the close of business on November 4, 2026.

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EQT CORPORATION AND SUBSIDIARIES

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

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 September 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 October 20, 2026.

Senior Notes

Commercial Paper Notes

Rating Agency

Rating

Outlook

Rating

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

Baa3

Positive

P-3

S&P Global Ratings (S&P)

BBB–

Positive

A-3

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 EQT's revolving credit facility and the Commercial Paper Program, 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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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 October 20, 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.


	Q4 2026 (a)		Q1 2027		Q2 2027		Q3 2027		Q4 2027
Hedged Volume (MMDth)	108		62		156		174		70
Hedged Volume (MMDth/d)	1.2		0.7		1.7		1.9		0.8



Swaps – Short
Volume (MMDth)	—		—		83		100		45
Avg. Price ($/Dth)	$	—	$	—	$	3.13	$	3.14	$	3.16



Calls – Short
Volume (MMDth)	108		62		73		74		25
Avg. Strike ($/Dth)	$	5.13	$	5.77	$	4.51	$	4.51	$	4.51
Puts – Long
Volume (MMDth)	108		62		73		74		25
Avg. Strike ($/Dth)	$	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)October 1 through December 31.

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

See 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

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

We evaluate our legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrue a liability 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.

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.

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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 September 30, 2026 and December 31, 2025 would increase the fair value of our natural gas derivative commodity instruments by approximately $113 million and $100 million, respectively. A hypothetical increase of 10% in the NYMEX natural gas price on September 30, 2026 and December 31, 2025 would decrease the fair value of our natural gas derivative commodity instruments by approximately $114 million and $93 million, respectively. For purposes of this analysis, we applied the 10% change in the NYMEX natural gas price on September 30, 2026 and December 31, 2025 to our natural gas derivative commodity instruments as of September 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 September 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 78%, or $167 million, of our OTC derivative contracts outstanding at September 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 September 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 third 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

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

Except as set forth below, 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.

Our acquisition of Range is subject to conditions, including certain conditions that are beyond our control and may not be satisfied. Failure to complete the Range Merger could have a material and adverse effect on us.

Completion of our acquisition of Range is subject to a number of conditions set forth in the Merger Agreement, including those described in Note 11 to the Condensed Consolidated Financial Statements. Some of the conditions, such as approval by our shareholders and Range's shareholders of the transaction and certain regulatory approvals, are beyond our control, which make the completion and timing of the completion of the Range Merger uncertain. In addition, the Merger Agreement contains certain termination rights for both Range and us, which if exercised, will also result in the Range Merger not being consummated. Furthermore, the governmental authorities from which regulatory approvals are required may impose conditions on the completion of the Range Merger or require changes to the terms of the Merger Agreement.

If the Range Merger is not completed, our ongoing business may be adversely affected and, without realizing any of the benefits of having completed the transaction, we will be subject to a number of risks, including the following: we will be required to pay our costs relating to the Range Merger, such as legal, accounting and financial advisory fees, whether or not the Range Merger is completed; time and resources committed by our management to matters relating to the Range Merger could otherwise have been devoted to pursuing other beneficial opportunities; and the market price of our common stock could decline to the extent that the current market price reflects a market assumption that the Range Merger will be completed. In addition to such risks, if the Merger Agreement is terminated and our Board of Directors seeks another acquisition, our shareholders cannot be certain that we will be able to find a party willing to enter into a transaction as attractive to us as the Range Merger.

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If the Range Merger is completed, we may not achieve the anticipated benefits.

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

The Range Merger may be completed even though material adverse changes, such as industry-wide changes or other events, subsequent to the announcement of the transaction may occur.

Although one of the conditions to the consummation of the transaction is there being no Company Material Adverse Effect and no Parent Material Adverse Effect (each as defined in the Merger Agreement) having occurred since the date of the Merger Agreement, some types of changes do not permit the parties to refuse to complete the transaction, even if such changes would have a material adverse effect on either of the parties. For example, a worsening of Range's financial condition or results of operations due to general economic conditions would not give us the right to refuse to complete the Range Merger. In such a case, our business and financial results after the Range Merger may be negatively affected.

We will be subject to business uncertainties while the Range Merger is pending, which could adversely affect our business, and the Range Merger may disrupt our current plans or operation.

It is possible that certain persons with whom we have a business relationship may delay certain business decisions relating to us in connection with the pendency of the Range Merger or they might decide to seek to terminate, change or renegotiate their relationships with us as a result of the Range Merger, which could negatively affect our revenues, earnings and cash flows, regardless of whether the Range Merger is completed.

In addition, under the terms of the Merger Agreement, we are subject to certain restrictions on the conduct of our business prior to the completion of the Range Merger, including the ability in certain cases to acquire certain assets, which could delay or otherwise adversely affect our ability to execute certain of our business strategies and could negatively affect our business and operations.

The Merger Agreement limits our ability to pursue alternatives to the Range Merger.

In the Merger Agreement, we have agreed, subject to certain exceptions with respect to unsolicited proposals, not to directly or indirectly solicit competing acquisition proposals or to enter into discussions concerning, or provide confidential information in connection with, any unsolicited alternative acquisition proposals. In addition, upon termination of the Merger Agreement under certain circumstances specified therein, we would be required to pay Range a termination fee equal to $1,148 million. These provisions could discourage a potential acquirer or other strategic transaction partner that might have an interest in acquiring all or a significant portion of EQT from considering or pursuing an alternative transaction with us or proposing such a transaction. These provisions might also result in a potential acquirer or other strategic transaction partner proposing to pay a lower price than it might otherwise have proposed to pay because of the added expense of the termination fee that may become payable in certain circumstances.

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We are expected to incur significant transaction costs in connection with the acquisition of Range, which may be in excess of those anticipated by us.

We have incurred and are expected to continue to incur a number of non-recurring costs associated with negotiating and completing the Range Merger, combining the operations of the two companies and achieving desired synergies. These fees and costs have been, and will continue to be, substantial and, in many cases, will be borne by us whether or not the Range Merger is completed, and could have an adverse effect on our financial condition and operating results following the completion of the transaction.

We may be a target of securities class action and derivative lawsuits, which could result in substantial costs and may delay or prevent the Range Merger from being completed.

Securities class action lawsuits and derivative lawsuits are often brought against public companies that have entered into acquisition or merger agreements. Even if the lawsuits are without merit, defending against these claims can result in substantial costs and divert management time and resources. An adverse judgment could result in monetary damages, which could have a negative impact on our liquidity and financial condition. Additionally, if a plaintiff is successful in obtaining an injunction prohibiting completion of the Range Merger, that injunction may delay or prevent the transaction from being completed, which may adversely affect our business, financial position and results of operations, as described in the first risk factor in this Item 1A.

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 third 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 September 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 September 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

2.01*

Agreement and Plan of Merger, dated as of October 25, 2026, by and among EQT Corporation, EQT Holdings LLC, Rhino Merger Sub Inc., Rhino Merger Sub LLC and Range Resources Corporation.

Incorporated herein by reference to Exhibit 2.1 to Form 8-K (#001-3551) filed on October 26, 2026.

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

Form of Commercial Paper Dealer Agreement between EQT Corporation and the Dealer party thereto.

Incorporated herein by reference to Exhibit 10.1 to Form 8-K (#001-3551) filed on October 7, 2026.

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.

* Schedules and exhibits to this Exhibit have been omitted pursuant to Item 601(a)(5) of Regulation S-K. EQT agrees to provide a copy of any omitted schedule or exhibit to the SEC or its staff upon request.

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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 (Principal Financial Officer)

Date: October 28, 2026

EQT Corporation - 10-Q quarterly report FY2026 Q3

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		Page
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	30
Item 3.	Quantitative and Qualitative Disclosures About Market Ri s k	51
Item 4.	Controls and Procedures	52

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	52
Item 1A.	Risk Factors	52
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	54
Item 5.	Other Information	54
Item 6.	Exhibits	55

Signatures		56