Form 10-Q - Quarterly report [Sections 13 or 15(d)]

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, 2023

☐

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

FOR THE TRANSITION PERIOD FROM__________ TO__________

COMMISSION FILE NUMBER: 001-03551

EQT CORPORATION

(Exact name of registrant as specified in its charter)


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

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

(412) 553-5700

(Registrant's telephone number, including area code)

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

Title of each class

Trading symbol(s)

Name of each exchange on which registered

Common Stock, no par value

EQT

New York Stock Exchange

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

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

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

The number of shares of common stock, no par value, of the registrant outstanding (in thousands) as of October 20, 2023: 411,332

Table of Contents

TABLE OF CONTENTS


		Page No.
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	23
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	37
Item 4.	Controls and Procedures	39

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	39
Item 1A.	Risk Factors	39
Item 2.	Unregistered Sales of Equity Securities, Use of Proceeds, and Issuer Purchases of Equity Securities	40
Item 5.	Other Information	40
Item 6.	Exhibits	41

Signature		43

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,
	2023		2022		2023		2022

	(Thousands, except per share amounts)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	1,001,883	$	3,694,194	$	3,680,566	$	9,546,029
Gain (loss) on derivatives	177,906		(1,627,296)		1,167,144		(5,550,028)
Net marketing services and other	6,313		2,565		18,214		21,860
Total operating revenues	1,186,102		2,069,463		4,865,924		4,017,861
Operating expenses:
Transportation and processing	554,788		541,092		1,592,934		1,596,900
Production	67,093		81,785		170,071		235,353
Exploration	447		357		2,602		2,870
Selling, general and administrative	56,942		67,231		168,999		195,603
Depreciation and depletion	446,886		418,695		1,230,255		1,269,936
Loss (gain) on sale/exchange of long-lived assets	1,511		(265)		17,814		(2,455)
Impairment of contract asset	—		—		—		184,945
Impairment and expiration of leases	6,419		20,497		22,290		97,536
Other operating expenses	36,209		15,485		69,265		38,952
Total operating expenses	1,170,295		1,144,877		3,274,230		3,619,640
Operating income	15,807		924,586		1,591,694		398,221
Loss (income) from investments	546		(2,877)		(5,310)		14,331
Dividend and other income	(132)		(157)		(869)		(11,066)
Loss (gain) on debt extinguishment	1,089		27,814		(55)		139,085
Interest expense, net	60,427		60,138		146,856		194,025
(Loss) income before income taxes	(46,123)		839,668		1,451,072		61,846
Income tax (benefit) expense	(126,853)		152,206		217,975		(5,257)
Net income	80,730		687,462		1,233,097		67,103
Less: Net (loss) income attributable to noncontrolling interests	(525)		3,792		(80)		8,120
Net income attributable to EQT Corporation	$	81,255	$	683,670	$	1,233,177	$	58,983

Income per share of common stock attributable to EQT Corporation:
Basic:
Weighted average common stock outstanding	383,359		369,987		368,936		371,308
Net income attributable to EQT Corporation	$	0.21	$	1.85	$	3.34	$	0.16
Diluted (Note 7):
Weighted average common stock outstanding	416,190		403,889		401,859		377,028
Net income attributable to EQT Corporation	$	0.20	$	1.69	$	3.08	$	0.16

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

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands)
Net income	$	80,730	$	687,462	$	1,233,097	$	67,103
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax expense: $15, $20, $44 and $61	57		63		270		190
Comprehensive income	80,787		687,525		1,233,367		67,293
Less: Comprehensive (loss) income attributable to noncontrolling interests	(525)		3,792		(80)		8,120
Comprehensive income attributable to EQT Corporation	$	81,312	$	683,733	$	1,233,447	$	59,173

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

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EQT CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	September 30, 2023		December 31, 2022

	(Thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	64,750	$	1,458,644
Accounts receivable (less provision for doubtful accounts: $235 and $605)	559,348		1,608,089
Derivative instruments, at fair value	577,926		812,371
Prepaid expenses and other	45,214		135,337
Total current assets	1,247,238		4,014,441

Property, plant and equipment	33,313,666		27,393,919
Less: Accumulated depreciation and depletion	10,391,586		9,226,586
Net property, plant and equipment	22,922,080		18,167,333

Other assets	385,670		488,152
Total assets	$	24,554,988	$	22,669,926

LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	414,592	$	422,632
Accounts payable	1,159,743		1,574,610
Derivative instruments, at fair value	274,684		1,393,487
Other current liabilities	269,925		341,491
Total current liabilities	2,118,944		3,732,220


Term Loan Facility borrowings	1,243,280		—
Senior notes	4,174,163		5,167,849
Note payable to EQM Midstream Partners, LP	83,831		88,484
Deferred income taxes	1,751,388		1,442,406
Other liabilities and credits	973,825		1,025,639
Total liabilities	10,345,431		11,456,598

Equity:
Common stock, no par value, shares authorized: 640,000, shares issued: 411,311 and 365,363	11,958,441		9,891,890
Retained earnings	2,245,615		1,283,578
Accumulated other comprehensive loss	(2,724)		(2,994)
Total common shareholders' equity	14,201,332		11,172,474
Noncontrolling interest in consolidated subsidiaries	8,225		40,854
Total equity	14,209,557		11,213,328
Total liabilities and equity	$	24,554,988	$	22,669,926

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

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED)


	Nine Months Ended September 30,
	2023		2022

	(Thousands)
Cash flows from operating activities:
Net income	$	1,233,097	$	67,103
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax expense (benefit)	227,701		(14,229)
Depreciation and depletion	1,230,255		1,269,936
Impairment of long-lived assets and loss/gain on sale/exchange of long-lived assets	40,104		280,026
(Income) loss from investments	(5,310)		14,331
(Gain) loss on debt extinguishment	(55)		139,085
Share-based compensation expense	38,179		33,706
Distribution of earnings from equity method investments	18,073		38,750
Amortization, accretion and other	12,022		24,937
(Gain) loss on derivatives	(1,167,144)		5,550,028
Net cash settlements received (paid) on derivatives	625,051		(4,672,998)
Net premiums (paid) received on derivative instruments	(231,343)		13,809
Changes in other assets and liabilities:
Accounts receivable	1,122,843		(507,050)
Accounts payable	(515,879)		343,925
Other current assets	91,946		(27,960)
Other items, net	(165,076)		(151,641)
Net cash provided by operating activities	2,554,464		2,401,758
Cash flows from investing activities:
Capital expenditures	(1,485,898)		(1,047,475)
Cash paid for acquisitions	(2,288,201)		(150,000)
Proceeds from sale/exchange of assets	4,831		5,394
Proceeds from sale of investment shares	—		189,249
Other investing activities	(4,841)		(14,306)
Net cash used in investing activities	(3,774,109)		(1,017,138)
Cash flows from financing activities:
Proceeds from revolving credit facility borrowings	313,000		10,242,000
Repayment of revolving credit facility borrowings	(313,000)		(10,242,000)
Proceeds from Term Loan Facility borrowings	1,250,000		—
Debt issuance costs	(5,336)		(17,852)
Repayment and retirement of debt	(1,014,346)		(833,029)
Discounts received (premiums paid) on debt extinguishment	5,313		(135,248)
Dividends paid	(162,567)		(148,765)


Repurchase and retirement of common stock	(201,029)		(270,345)
Net (distribution to) contribution from noncontrolling interest	(7,322)		4,050
Other financing activities	(38,962)		(9,853)
Net cash used in financing activities	(174,249)		(1,411,042)
Net change in cash and cash equivalents	(1,393,894)		(26,422)
Cash and cash equivalents at beginning of period	1,458,644		113,963
Cash and cash equivalents at end of period	$	64,750	$	87,541

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

See Note 1 for supplemental cash flow information.

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)


	Common Stock
	Shares	No Par Value		Treasury Stock		(Accumulated Deficit) Retained Earnings		Accumulated Other Comprehensive Loss (a)		Noncontrolling Interest in Consolidated Subsidiaries		Total Equity

	(Thousands, except per share amounts)
Balance at July 1, 2022	369,720	$	9,948,646	$	(2,848)	$	(880,127)	$	(4,484)	$	28,903	$	9,090,090
Comprehensive income, net of tax:
Net income						683,670				3,792		687,462
Other postretirement benefits liability adjustment, net of tax expense: $20								63				63
Dividends ($0.15 per share)						(55,493)						(55,493)
Share-based compensation plans	209	2,292		2,269								4,561
Convertible Notes settlements	1	10										10
Repurchase and retirement of common stock	(1,768)	(27,409)				(47,627)						(75,036)
Distribution to noncontrolling interest										(4,306)		(4,306)
Contribution from noncontrolling interest										11,250		11,250
Balance at September 30, 2022	368,162	$	9,923,539	$	(579)	$	(299,577)	$	(4,421)	$	39,639	$	9,658,601

Balance at July 1, 2023	361,654	$	9,790,855	$	—	$	2,217,698	$	(2,781)	$	39,256	$	12,045,028
Comprehensive income, net of tax:
Net income (loss)						81,255				(525)		80,730
Other postretirement benefits liability adjustment, net of tax expense: $15								57				57
Dividends ($0.15 per share)						(54,249)						(54,249)
Share-based compensation plans	56	14,939										14,939
Convertible Notes settlements	1	16										16

Tug Hill and XcL Midstream Acquisition	49,600	2,152,631										2,152,631
Distribution to noncontrolling interest										(5,279)		(5,279)
Dissolution of consolidated variable interest entity (Note 1)										(25,227)		(25,227)
Other						911						911
Balance at September 30, 2023	411,311	$	11,958,441	$	—	$	2,245,615	$	(2,724)	$	8,225	$	14,209,557

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

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

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

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)


	Common Stock
	Shares	No Par Value		Treasury Stock		(Accumulated Deficit) Retained Earnings		Accumulated Other Comprehensive Loss (a)		Noncontrolling Interest in Consolidated Subsidiaries		Total Equity

	(Thousands, except per share amounts)
Balance at January 1, 2022	376,399	$	10,071,820	$	(18,046)	$	(94,400)	$	(4,611)	$	16,236	$	9,970,999
Comprehensive income, net of tax:
Net income						58,983				8,120		67,103
Other postretirement benefits liability adjustment, net of tax expense: $61								190				190
Dividends ($0.40 per share)						(148,765)						(148,765)
Share-based compensation plans	2,061	11,340		17,467								28,807
Convertible Notes settlements	3	48										48
Repurchase and retirement of common stock	(10,301)	(159,669)				(115,395)						(275,064)
Distribution to noncontrolling interest										(7,200)		(7,200)
Contribution from noncontrolling interest										11,250		11,250
Other										11,233		11,233
Balance at September 30, 2022	368,162	$	9,923,539	$	(579)	$	(299,577)	$	(4,421)	$	39,639	$	9,658,601

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

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

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

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

1. Financial Statements

The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all information and notes required by GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals, unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of EQT Corporation and subsidiaries as of September 30, 2023 and December 31, 2022, the results of its operations and equity for the three and nine month periods ended September 30, 2023 and 2022 and its cash flows for the nine month periods ended September 30, 2023 and 2022. Certain previously reported amounts have been reclassified to conform to the current year presentation. In this Quarterly Report on Form 10-Q, references to "EQT" and "the Company" refer collectively to EQT Corporation and its consolidated subsidiaries unless otherwise noted.

The Condensed Consolidated Balance Sheet at December 31, 2022 has been derived from the audited financial statements at that date. For further information, refer to the Consolidated Financial Statements and accompanying notes in the Company's Annual Report on Form 10-K for the year ended December 31, 2022.

Dissolution of Consolidated Variable Interest Entity. In 2020, the Company entered into a partnership (the Partnership) with a third-party investor (the Investor) to purchase certain mineral rights in the Appalachian Basin. During the three months ended September 30, 2023, the Partnership's assets were distributed pro rata to the Company and the Investor, and the Partnership was dissolved. Prior to its dissolution, the Partnership was accounted for as a consolidated variable interest entity as the Company had the power to direct the activities that most significantly affected the Partnership's economic performance.

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,
	2023		2022

	(Thousands)
Cash paid during the period for:
Interest, net of amount capitalized	$	145,787	$	208,239
Income taxes, net	13,441		10,529

Non-cash activity during the period for:
Tug Hill and XcL Midstream Acquisition	$	2,152,631	$	—
Increase in right-of-use assets and lease liabilities, net	25,849		1,651
Dissolution of consolidated variable interest entity	25,227		—
Increase in asset retirement costs and obligations	5,216		14,102
Capitalization of non-cash equity share-based compensation	4,587		3,923
Issuance of common stock for Convertible Notes settlement	98		48

2. Revenue from Contracts with Customers

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

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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

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

For contracts with customers where the Company's performance obligations had been satisfied and an unconditional right to consideration existed as of the balance sheet date, the Company recorded amounts due from contracts with customers of $382.2 million and $1,171.9 million in accounts receivable in the Condensed Consolidated Balance Sheets as of September 30, 2023 and December 31, 2022, respectively.

The table below provides disaggregated information on the Company's revenues. Certain other revenue contracts are outside the scope of Accounting Standards Update (ASU) 2014-09, Revenue from Contracts with Customers. These contracts are reported in net marketing services and other 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,
	2023		2022		2023		2022

	(Thousands)
Revenues from contracts with customers:
Natural gas sales	$	859,512	$	3,543,706	$	3,337,600	$	9,008,226
NGLs sales	108,205		134,636		274,932		475,988
Oil sales	34,166		15,852		68,034		61,815
Total revenues from contracts with customers	$	1,001,883	$	3,694,194	$	3,680,566	$	9,546,029

Other sources of revenue:
Gain (loss) on derivatives	177,906		(1,627,296)		1,167,144		(5,550,028)
Net marketing services and other	6,313		2,565		18,214		21,860
Total operating revenues	$	1,186,102	$	2,069,463	$	4,865,924	$	4,017,861

The following table summarizes the transaction price allocated to the Company's remaining performance obligations on all contracts with fixed consideration as of September 30, 2023. Amounts shown exclude contracts that qualified for the exception to the relative standalone selling price method as of September 30, 2023.


	2023 (a)		2024		Total

	(Thousands)
Natural gas sales	$	1,007	$	469	$	1,476

(a)October 1 through December 31.

3. 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.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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

The Company does not designate any of its derivative instruments as cash flow hedges; therefore, all changes in fair value of the Company's derivative instruments are recognized in operating revenues in gain (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.

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 1,866 billion cubic feet (Bcf) of natural gas and 881 thousand barrels (Mbbl) of NGLs as of September 30, 2023 and 1,424 Bcf of natural gas and 1,483 Mbbl of NGLs as of December 31, 2022. The open positions at both September 30, 2023 and December 31, 2022 had maturities extending through December 2027.

Certain of the Company's OTC derivative instrument contracts provide that, if the Company's credit rating assigned by Moody's Investors Service, Inc. (Moody's), S&P Global Ratings (S&P) or Fitch Ratings Service (Fitch) is below the agreed-upon credit rating threshold (typically, below investment grade) and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the counterparty to such contract can require the Company to deposit collateral. Similarly, if such counterparty's credit rating assigned by Moody's, S&P or Fitch is below the agreed-upon credit rating threshold and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the Company can require the counterparty to deposit collateral with the Company. Such collateral can be up to 100% of the derivative liability. Investment grade refers to the quality of a company's credit as assessed by one or more credit rating agencies. To be considered investment grade, a company must be rated "Baa3" or higher by Moody's, "BBB–" or higher by S&P and "BBB–" or higher by Fitch. Anything below these ratings is considered non-investment grade. As of September 30, 2023, the Company's senior notes were rated "Baa3" by Moody's, "BBB–" by S&P and "BBB–" by Fitch.

When the net fair value of any of the Company's OTC derivative instrument contracts represents a liability to the Company that is in excess of the agreed-upon dollar threshold for the Company's then-applicable credit rating, the counterparty has the right to require the Company to remit funds as a margin deposit in an amount equal to the portion of the derivative liability that is in excess of the dollar threshold amount. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. As of September 30, 2023, none of the Company's OTC derivative instruments with credit rating risk-related contingent features were in a net liability position. As of December 31, 2022, the aggregate fair value of the Company's OTC derivative instruments with credit rating risk-related contingent features that were in a net liability position was $347.6 million, for which no deposits were required or recorded in the Condensed Consolidated Balance Sheet.

When the net fair value of any of the Company's OTC derivative instrument contracts represents an asset to the Company that is in excess of the agreed-upon dollar threshold for the counterparty's then-applicable credit rating, the Company has the right to require the counterparty to remit funds as a margin deposit in an amount equal to the portion of the derivative asset that is in excess of the dollar threshold amount. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. As of both September 30, 2023 and December 31, 2022, there were no such deposits recorded in the Condensed Consolidated Balance Sheets.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

When the Company enters into exchange traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good-faith deposits to guard against the risks associated with changing market conditions. The Company is required to make such deposits based on an established initial margin requirement and the net liability position, if any, of the fair value of the associated contracts. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. When the fair value of such contracts is in a net asset position, the broker may remit funds to the Company. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the contract. The margin requirements are subject to change at the exchanges' discretion. As of September 30, 2023 and December 31, 2022, the Company recorded $14.6 million and $100.6 million, respectively, of such deposits as current assets in the Condensed Consolidated Balance Sheets.

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


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

	(Thousands)
September 30, 2023
Asset derivative instruments, at fair value	$	577,926	$	(198,511)	$	—	$	379,415
Liability derivative instruments, at fair value	274,684		(198,511)		(14,570)		61,603

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	(756,495)	$	—	$	55,876
Liability derivative instruments, at fair value	1,393,487		(756,495)		(100,623)		536,369

Henry Hub Cash Bonus. The Consolidated GGA (defined in Note 8) executed in connection with the Equitrans Share Exchange (defined in Note 8) provides for cash bonus payments (the Henry Hub Cash Bonus) payable by the Company during the period beginning on the first day of the quarter in which the Mountain Valley Pipeline is placed in service and ending on the earlier of 36 months thereafter or December 31, 2024. Such payments are conditioned upon the quarterly average of the NYMEX Henry Hub natural gas settlement price exceeding certain price thresholds.

As of December 31, 2022, the Company reduced the derivative liability related to the Henry Hub Cash Bonus to zero given the uncertainties surrounding the in-service date of the Mountain Valley Pipeline and the Company's then-held belief that achieving an in-service date of the Mountain Valley Pipeline prior to December 31, 2024 was not probable.

On June 3, 2023, President Biden signed legislation that raised the United States' debt limit, ratified and approved all permits and authorizations necessary for the construction and initial operation of the Mountain Valley Pipeline and directs the applicable federal officials and agencies to maintain such authorizations. Further, the legislation requires the Secretary of the Army to issue all permits or verifications necessary to complete project construction and allow for the Mountain Valley Pipeline's operation and maintenance. Given the impact of this legislation, the Company reevaluated its probability-weighted assessment of the achievement of an in-service date of the Mountain Valley Pipeline prior to December 31, 2024 and concluded that, as of September 30, 2023, based on the facts and circumstances that existed as of that date, the derivative liability related to the Henry Hub Cash Bonus had a fair value of approximately $54.4 million.

The fair value of the derivative liability related to the Henry Hub Cash Bonus is based on significant inputs that are interpolated from observable market data and, as such, is a Level 2 fair value measurement. See Note 4 for a description of the fair value hierarchy.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

4. Fair Value Measurements

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

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

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

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


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

	(Thousands)
September 30, 2023
Asset derivative instruments, at fair value	$	577,926	$	42,352	$	535,574	$	—
Liability derivative instruments, at fair value	274,684		45,464		229,220		—

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	103,028	$	709,343	$	—
Liability derivative instruments, at fair value	1,393,487		154,601		1,238,886		—

The carrying values of cash equivalents, accounts receivable and accounts payable approximate fair value due to their short-term maturities. The carrying value of borrowings under the Company's revolving credit facility and the Term Loan Facility (defined in Note 6) approximates fair value as their interest rates are based on prevailing market rates. The Company considers these fair values to be Level 1 fair value measurements.

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

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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, 2023 and December 31, 2022, the Company's senior notes had a fair value of approximately $5.2 billion and $6.1 billion, respectively, and a carrying value of approximately $4.6 billion and $5.6 billion, respectively, inclusive of any current portion. The fair value of the Company's note payable to EQM Midstream Partners, LP (EQM) is estimated using an income approach model with a market-based discount rate and is a Level 3 fair value measurement. As of September 30, 2023 and December 31, 2022, the Company's note payable to EQM had a fair value of approximately $89 million and $96 million, respectively, and a carrying value of approximately $90 million and $94 million, respectively, inclusive of any current portion. See Note 6 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 3 for a discussion of the fair value measurement of the Henry Hub Cash Bonus. See Note 8 for a discussion of the fair value measurement of the contract asset. See Note 9 for a discussion of the fair value measurement of the Tug Hill and XcL Midstream Acquisition (defined in Note 9). See Note 1 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, 2022 for a discussion of the fair value measurement of the Company's oil and gas properties and other long-lived assets, including impairment and expiration of leases.

5. Income Taxes

For the nine months ended September 30, 2023 and 2022, the Company calculated the provision for income taxes for interim periods by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the nine months ended September 30, 2023.

For the nine months ended September 30, 2023 and 2022, the Company recorded income tax expense (benefit) at an effective tax rate of 15.0% and (8.5)%, respectively. The Company's effective tax rate for the nine months ended September 30, 2023 was lower compared to the U.S. federal statutory rate due primarily as a result of the release of valuation allowances limiting certain state deferred tax assets and net state deferred tax benefit related to a rate reduction from a Pennsylvania tax law change enacted on July 8, 2022 and the Tug Hill and XcL Midstream Acquisition. The Company's effective tax rate for the nine months ended September 30, 2022 was lower compared to the U.S. federal statutory rate due primarily to a reduction to deferred state taxes from a Pennsylvania tax law change enacted on July 8, 2022, partly offset by nondeductible repurchase premiums on the Convertible Notes (defined in Note 6).

The Company recognizes a valuation allowance when it is more likely than not that all or a portion of a deferred tax asset (DTA) will not be realized. All available evidence, both positive and negative, is considered when determining the need for a valuation allowance. To determine whether a valuation allowance is required, the Company uses judgement to estimate future taxable income and considers the tax consequences in the jurisdiction where such taxable income is generated as well as evidence including the Company's current financial position, actual and forecasted results of operations, the reversal of deferred tax liabilities and tax planning strategies in addition to the current and forecasted business economics of the oil and gas industry. During the three months ended September 30, 2023, the Company concluded that the positive evidence, including the Company's change in its cumulative income position from loss to income and its forecasted income, more likely than not outweighed the negative evidence regarding the realization of the Company's DTA for certain state tax net operating loss (NOL) carryforwards. As a result, the Company recorded a state deferred tax benefit of $101 million related to its valuation allowance for its state NOL carryforwards in the Statement of Condensed Consolidated Operations for the three months ended September 30, 2023.

The Company has retained a valuation allowance related to its NOLs for certain entities and jurisdictions in which it is more likely than not that the benefit from the related DTA will not be realized as well as a valuation allowance against the portion of its federal and state DTAs, such as capital losses, which may expire before being fully utilized due to the limitation to offset only capital gains.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

6. Debt

The table below summarizes the Company's outstanding debt.


	September 30, 2023				December 31, 2022
	Principal Value		Carrying Value (a)		Principal Value		Carrying Value (a)

	(Thousands)

Term Loan Facility due June 30, 2025 (b)	$	1,250,000	$	1,243,280	$	—	$	—
Senior notes:
7.42% series B notes due 2023	—		—		10,000		10,000
6.125% notes due February 1, 2025 (b)	601,521		600,128		911,467		908,168
5.678% notes due October 1, 2025	—		—		500,000		496,578
1.75% convertible notes due May 1, 2026	414,732		408,450		414,832		406,796
3.125% notes due May 15, 2026	392,915		389,674		440,857		436,198
7.75% debentures due July 15, 2026	115,000		113,591		115,000		113,218
3.90% notes due October 1, 2027	1,169,503		1,165,167		1,233,008		1,227,582
5.700% notes due April 1, 2028	500,000		489,810		500,000		493,941
5.00% notes due January 15, 2029	318,494		314,956		327,101		322,956
7.000% notes due February 1, 2030 (b)	674,800		670,865		714,800		710,138
3.625% notes due May 15, 2031	435,165		429,972		465,165		459,070
Note payable to EQM	89,973		89,973		94,320		94,320
Total debt	5,962,103		5,915,866		5,726,550		5,678,965
Less: Current portion of debt (c)	420,874		414,592		430,668		422,632
Long-term debt	$	5,541,229	$	5,501,274	$	5,295,882	$	5,256,333

(a)For the note payable to EQM, the principal value represents the carrying value. For all other debt, the principal value less the unamortized debt issuance costs and debt discounts represents the carrying value.

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

(c)As of September 30, 2023, the current portion of debt included the 1.75% convertible notes and a portion of the note payable to EQM. As of December 31, 2022, the current portion of debt included the 7.42% series B notes, the 1.75% convertible notes and a portion of the note payable to EQM.

Debt Repayments. The Company redeemed or repurchased the following debt during the nine months ended September 30, 2023.


Debt Tranche	Principal		Premiums/(Discounts) (a)		Accrued but Unpaid Interest		Total Cost

	(Thousands)
6.125% notes due February 1, 2025	$	309,946	$	1,832	$	6,801	$	318,579
5.678% notes due October 1, 2025	500,000		—		6,940		506,940

3.125% notes due May 15, 2026	47,942		(3,042)		296		45,196
3.90% notes due October 1, 2027	63,505		(3,534)		781		60,752

5.00% notes due January 15, 2029	8,607		(309)		137		8,435
7.000% notes due February 1, 2030	40,000		2,736		1,313		44,049
3.625% notes due May 15, 2031	30,000		(4,011)		167		26,156
Total	$	1,000,000	$	(6,328)	$	16,435	$	1,010,107

(a)Includes third-party costs and fees paid to dealer managers and brokers.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Revolving Credit Facility. The Company has a $2.5 billion revolving credit facility that matures in June 2027.

As of September 30, 2023 and December 31, 2022, the Company had approximately $15 million and $25 million, respectively, of letters of credit outstanding under its revolving credit facility.

During the three months ended September 30, 2023 and 2022, under the Company's revolving credit facility, the maximum amount of outstanding borrowings was $158 million and $1,216 million, respectively, the average daily balance was approximately $28 million and $717 million, respectively, and interest was incurred at a weighted average annual interest rate of 6.9% and 3.8%, respectively. During the nine months ended September 30, 2023 and 2022, under the Company's revolving credit facility, the maximum amount of outstanding borrowings was $158 million and $1,300 million, respectively, the average daily balance was approximately $9 million and $624 million, respectively, and interest was incurred at a weighted average annual interest rate of 6.9% and 2.8%, respectively.

Term Loan Facility. On November 9, 2022, the Company entered into a Credit Agreement with PNC Bank, National Association, as administrative agent, and the other lenders party thereto (as amended, the Term Loan Agreement), under which such lenders agreed to make to the Company unsecured term loans in a single draw in an aggregate principal amount of up to $1.25 billion (the Term Loan Facility) to partly fund the Tug Hill and XcL Midstream Acquisition. On August 21, 2023, the Company borrowed $1.25 billion under the Term Loan Facility, receiving proceeds, net of $7.1 million of debt issuance costs, of $1,242.9 million.

At the Company's election, the $1.25 billion of borrowings under the Term Loan Facility bear interest at a Term SOFR Rate plus the SOFR Adjustment or Base Rate (all terms defined in the Term Loan Agreement), each plus a margin based on the Company's credit ratings. The Company may voluntarily prepay, in whole or in part, borrowings under the Term Loan Facility without premium or penalty but subject to reimbursement of funding losses with respect to prepayment of loans that bear interest based on the Term SOFR Rate. Borrowings under the Term Loan Facility that are repaid may not be re-borrowed. During the period from August 21, 2023 through September 30, 2023, under the Term Loan Facility, interest was incurred at a weighted average annual interest rate of 7.0%.

The Term Loan Agreement contains certain representations and warranties and various affirmative and negative covenants and events of default, including (i) a restriction on the ability of the Company and certain of its subsidiaries to incur or permit liens on assets, subject to certain significant exceptions, (ii) a restriction on the ability of certain of the Company's subsidiaries to incur debt, subject to certain significant exceptions, (iii) the establishment of a maximum consolidated debt-to-total capital ratio of the Company and its subsidiaries of 65%, (iv) a limitation on certain changes to the Company's business and (v) certain restrictions related to mergers and sales of all or substantially all of the Company's assets. As of September 30, 2023, the Company was in compliance with these covenants.

5.700% Senior Notes. On October 4, 2022, the Company issued its 5.700% senior notes to partly fund the Tug Hill and XcL Midstream Acquisition. On May 10, 2023, following the receipt of the requisite consents of holders of a majority of the aggregate principal amount of the Company's 5.700% senior notes, the Company amended the mandatory redemption provision of the indenture governing the Company's outstanding 5.700% senior notes. Under the terms set forth in the consent solicitation statement, the Company paid consent fees of $5.3 million in the aggregate to holders of outstanding 5.700% senior notes who delivered valid consents.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Convertible Notes. In April 2020, the Company issued $500 million aggregate principal amount of 1.75% convertible senior notes (the Convertible Notes) due May 1, 2026 unless earlier redeemed, repurchased or converted.

Holders of the Convertible Notes may convert their Convertible Notes at their option at any time prior to the close of business on January 30, 2026 under the following circumstances:

•during any quarter as long as the last reported price of EQT Corporation common stock for at least 20 trading days (consecutive or otherwise) during the period of 30 consecutive trading days ending on the last trading day of the immediately preceding quarter is greater than or equal to 130% of the conversion price on each such trading day (the Sale Price Condition);

•during the five-business-day period after any five-consecutive-trading-day period (the measurement period) in which the trading price per $1,000 principal amount of the Convertible Notes for each trading day of the measurement period is less than 98% of the product of the last reported price of EQT Corporation common stock and the conversion rate for the Convertible Notes on each such trading day;

•if the Company calls any or all of the Convertible Notes for redemption at any time prior to the close of business on the second scheduled trading day immediately preceding such redemption date; and

•upon the occurrence of certain corporate events set forth in the Convertible Notes indenture.

On or after February 1, 2026, holders of the Convertible Notes may convert their Convertible Notes at their option at any time until the close of business on the second scheduled trading date immediately preceding May 1, 2026.

The Company was not permitted to redeem the Convertible Notes prior to May 5, 2023. On or after May 5, 2023 and prior to February 1, 2026, the Company may redeem for cash all or any portion of the Convertible Notes at its option at a redemption price equal to 100% of the principal amount of the Convertible Notes to be redeemed plus accrued and unpaid interest up to the redemption date as long as the last reported price per share of EQT Corporation common stock has been at least 130% of the conversion price in effect for at least 20 trading days (consecutive or otherwise) during any 30-consecutive-trading-day period ending on the trading day immediately preceding the date on which the Company delivers notice of redemption. A sinking fund is not provided for the Convertible Notes.

The table below summarizes adjustments made to the conversion rate for the Convertible Notes as a result of cash dividends paid by the Company on EQT Corporation common stock during the nine months ended September 30, 2023. Future cash dividends paid by the Company will result in further adjustments to the conversion rate.

Dividend Paid

Effective Date of Adjustment to Conversion Rate

Conversion Shares of EQT Corporation Common Stock per $1,000 Principal Amount

First Quarter of 2023

February 17, 2023

68.0740

Second Quarter of 2023

May 9, 2023

68.3917

Third Quarter of 2023

August 8, 2023

68.6360

The conversion rate is also subject to adjustment under certain other circumstances. In addition, following certain corporate events that occur prior to May 1, 2026 or if the Company delivers a notice of redemption, the Company will, in certain circumstances, increase the conversion rate for a holder who elects to convert its Convertible Notes in connection with such corporate event or notice of redemption.

The Sale Price Condition for conversion of the Convertible Notes was satisfied as of September 30, 2023, and, accordingly, the Convertible Notes indenture permits holders of the Convertible Notes to convert any of their Convertible Notes at their option at any time during the fourth quarter of 2023, subject to the terms and conditions set forth in the Convertible Notes indenture. In addition, the Sales Price Condition for conversion of the Convertible Notes was satisfied as of December 31, 2022, and, accordingly, the Convertible Notes indenture permitted holders of the Convertible Notes to convert any of their Convertible Notes at their option at any time during the first quarter of 2023, subject to the terms and conditions set forth in the Convertible Notes indenture. Therefore, as of September 30, 2023 and December 31, 2022, the net carrying value of the Convertible Notes was included in current portion of debt in the Condensed Consolidated Balance Sheets.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The table below summarizes settlements of Convertible Notes conversion right exercises for the nine months ended September 30, 2023. The Company elected to settle all such conversions by issuing shares of EQT Corporation common stock to the converting holders. Convertible Notes conversion right exercises are accrued in the period received.


Settlement Month	Principal Converted		Shares Issued	Average Conversion Price

	(Thousands)
January 2023	$	7	473	$	33.70
February 2023	8		541	30.77
March 2023	6		408	31.46
April 2023	58		3,948	32.01
June 2023	4		272	39.06
July 2023	10		682	40.92
September 2023	6		411	42.35

Upon conversion of the remaining outstanding Convertible Notes, the Company may satisfy its conversion obligation by paying and/or delivering at the Company's election, in the manner and subject to the terms and conditions provided in the Convertible Notes indenture, cash, shares of EQT Corporation common stock or a combination thereof. The Company intends to use a combined settlement approach to satisfy its obligation by paying or delivering to holders of the Convertible Notes cash equal to the principal amount of the obligation and EQT Corporation common stock for amounts that exceed the principal amount of the obligation.

In connection with the Convertible Notes offering, the Company entered into privately negotiated capped call transactions (the Capped Call Transactions), the purpose of which is to reduce the potential dilution to EQT Corporation common stock upon conversion of the Convertible Notes and/or offset any cash payments the Company is required to make in excess of the principal amount of such obligation, with such reduction and offset subject to a cap. The Capped Call Transactions have an initial strike price of $15.00 per share of EQT Corporation common stock and an initial capped price of $18.75 per share of EQT Corporation common stock, each of which are subject to certain customary adjustments, including adjustments as a result of EQT Corporation paying a dividend on its common stock.

Based on the closing stock price of EQT Corporation common stock of $40.58 on September 29, 2023 and excluding the impact of the Capped Call Transactions, the if-converted value of the Convertible Notes exceeded the principal amount by $740 million.

The table below summarizes the net carrying value and fair value of the Convertible Notes.


	September 30, 2023		December 31, 2022

	(Thousands)
Principal	$	414,732	$	414,832
Less: Unamortized debt issuance costs	6,282		8,036
Net carrying value of Convertible Notes	$	408,450	$	406,796

Fair value of Convertible Notes (a)	$	1,155,337	$	967,728

(a)The fair value is a Level 2 fair value measurement. See Note 4.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The table below summarizes the components of interest expense related to the Convertible Notes. The effective interest rate for the Convertible Notes is 2.4%.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands)
Contractual interest expense	$	1,814	$	1,821	$	5,443	$	6,191
Amortization of issuance costs	588		574		1,752		1,945
Total Convertible Notes interest expense	$	2,402	$	2,395	$	7,195	$	8,136

7. 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,
	2023		2022		2023		2022

	(Thousands, except per share amounts)
Net income attributable to EQT Corporation – Basic income available to shareholders	$	81,255	$	683,670	$	1,233,177	$	58,983
Add back: Interest expense on Convertible Notes, net of tax (a)	2,042		921		6,117		—
Diluted income available to shareholders	$	83,297	$	684,591	$	1,239,294	$	58,983

Weighted average common stock outstanding – Basic	383,359		369,987		368,936		371,308
Options, restricted stock, performance awards and stock appreciation rights	4,398		5,880		4,606		5,720
Convertible Notes (a)	28,433		28,022		28,317		—
Weighted average common stock outstanding – Diluted	416,190		403,889		401,859		377,028

Income per share of common stock attributable to EQT Corporation:
Basic	$	0.21	$	1.85	$	3.34	$	0.16
Diluted	$	0.20	$	1.69	$	3.08	$	0.16

(a)The Company uses the if-converted method to calculate the impact of the Convertible Notes on diluted income per share. For the nine months ended September 30, 2022, such if-converted securities of approximately 31.6 million as well as the related add back of interest expense on the Convertible Notes, net of tax, of $6.1 million were excluded from potentially dilutive securities because of their anti-dilutive effect on income per share.

8. Impairment of Contract Asset

During the first quarter of 2020, the Company sold to Equitrans Midstream Corporation (Equitrans Midstream) approximately 50% of the Company's then-owned equity interest in Equitrans Midstream in exchange for a combination of cash and rate relief under certain of the Company's gathering contracts with an affiliate of Equitrans Midstream (the Equitrans Share Exchange). The rate relief was effected through the execution of a consolidated gas gathering and compression agreement entered into between the Company and an affiliate of Equitrans Midstream (the Consolidated GGA). On the closing date of the Equitrans Share Exchange, the Company recorded in the Condensed Consolidated Balance Sheet a contract asset of $410 million representing the estimated fair value of the rate relief inclusive of the Cash Payment Option (defined below).

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Because the Mountain Valley Pipeline was not in service by January 1, 2022, the Consolidated GGA provided the Company the option to forgo a portion of the gathering fee relief that would otherwise be applicable following the Mountain Valley Pipeline in-service date in exchange for a cash payment of approximately $196 million (the Cash Payment Option). During the third quarter of 2022, the Company elected to exercise the Cash Payment Option, and, in the fourth quarter of 2022, the Company received the cash proceeds from the Cash Payment Option.

During 2022, the Company identified indicators that the carrying value of the contract asset may not be fully recoverable, including increased uncertainty of the estimated timing of completion of the Mountain Valley Pipeline due to court rulings and public statements from Equitrans Midstream with respect to its completion. As a result of the Company's impairment evaluation, the Company recognized impairment of the contract asset during the first quarter of 2022 of $184.9 million in the Statement of Condensed Consolidated Operations. During the fourth quarter of 2022, the Company recognized additional impairment of the contract asset of $29.3 million in the Statement of Condensed Consolidated Operations. As of December 31, 2022, the previously recognized impairments plus the election of the Cash Payment Option reduced the carrying value of the contract asset to zero.

The fair value of the contract asset was based on significant inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. See Note 4 for a description of the fair value hierarchy. Key assumptions used in the fair value calculation included the following: (i) a probability-weighted estimate of the in-service date of the Mountain Valley Pipeline; (ii) an estimate of the potential exercise and timing of the Cash Payment Option; (iii) an estimated production volume forecast and (iv) a market-based weighted average cost of capital.

9. Tug Hill and XcL Midstream Acquisition

On August 22, 2023, the Company completed its acquisition (the Tug Hill and XcL Midstream Acquisition) of the upstream assets from THQ Appalachia I, LLC (the Upstream Seller) and the gathering and processing assets from THQ-XcL Holdings I, LLC (the Midstream Seller) through the acquisition of all of the issued and outstanding membership interests of each of THQ Appalachia I Midco, LLC and THQ-XcL Holdings I Midco, LLC pursuant to the Amended and Restated Purchase Agreement, dated December 23, 2022 (as amended, the Purchase Agreement), entered into by and among EQT Corporation, EQT Production Company (a wholly-owned indirect subsidiary of EQT Corporation), the Upstream Seller and the Midstream Seller.

The purchase price for the Tug Hill and XcL Midstream Acquisition consisted of 49,599,796 shares of EQT Corporation common stock and approximately $2.4 billion in cash, subject to customary post-closing adjustments. The Company funded the cash portion of the consideration with $1.25 billion of borrowings under its Term Loan Facility, $1.0 billion of cash on hand and the $150 million cash deposit previously placed in escrow. The Purchase Agreement has an economic effective date of July 1, 2022.

As a result of the Tug Hill and XcL Midstream Acquisition, the Company acquired approximately 90,000 net West Virginia acres, approximately 800 million cubic feet of natural gas equivalents (MMcfe) per day of current net production, approximately 145 miles of midstream gathering pipeline, compression and gas processing assets and approximately 55 miles of connected water infrastructure with four centralized storage facilities.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Allocation of Purchase Price. The Tug Hill and XcL Midstream Acquisition was accounted for as a business combination using the acquisition method. The table below summarizes the preliminary purchase price and estimated fair values of assets acquired and liabilities assumed as of August 22, 2023. Certain information necessary to complete the purchase price allocation is not yet available, including, but not limited to, final appraisals of assets acquired and liabilities assumed. The Company expects to complete the purchase price allocation once it has received all necessary information, at which time the value of the assets acquired and liabilities assumed will be revised if necessary.


	Preliminary Purchase Price Allocation

	(Thousands)
Consideration:
Equity	$	2,152,631
Cash	2,403,301
Settlement of pre-existing relationships	(31,754)
Total consideration	$	4,524,178

Fair value of assets acquired:
Cash and cash equivalents	$	100
Accounts receivable, net	75,961
Derivative instruments, at fair value	162,455
Prepaid expenses and other	1,825
Property, plant and equipment	4,555,311
Other assets	5,921
Total amount attributable to assets acquired	$	4,801,573

Fair value of liabilities assumed:
Accounts payable	$	162,668
Other current liabilities	47,399
Other liabilities and credits	67,328
Total amount attributable to liabilities assumed	$	277,395

The fair value of the acquired developed natural gas and oil properties was measured using discounted cash flow valuation techniques based on inputs that are not observable in the market and, as such, are considered Level 3 fair value measurements. Significant inputs include future commodity prices, projections of estimated quantities of reserves, estimated future rates of production, projected reserve recovery factors, timing and amount of future development and operating costs and a weighted average cost of capital.

The fair value of the acquired undeveloped properties was primarily measured using discounted cash flow valuation techniques based on inputs that are not observable in the market and, as such, are considered Level 3 fair value measurements. Significant inputs include timing and amount of future development from a market participant perspective.

The fair value of the acquired midstream and water infrastructure assets was measured primarily using the cost approach based on inputs that are not observable in the market and, as such, are considered Level 3 fair value measurements. Significant inputs include replacement costs for similar assets, relative age of the acquired assets and any potential economic or functional obsolescence associated with the acquired assets.

See Note 4 for a description of the fair value hierarchy.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Post-Acquisition Operating Results. The table below summarizes amounts contributed by the upstream, gathering and processing assets acquired in the Tug Hill and XcL Midstream Acquisition to the Company's consolidated results for the period from August 22, 2023 through September 30, 2023.


	August 22, 2023 through September 30, 2023

	(Thousands)
Sales of natural gas, NGLs and oil	$	64,541
Loss on derivatives	(6,126)
Net marketing services and other	299
Total operating revenues	$	58,714

Net loss	$	(26,612)

Unaudited Pro Forma Information. The table below summarizes the Company's results as though the Tug Hill and XcL Midstream Acquisition had been completed on January 1, 2022. Certain of the Upstream Seller's and Midstream Seller's historical amounts were reclassified to conform to the Company's financial presentation of operations. Such unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Tug Hill and XcL Midstream Acquisition occurred on January 1, 2022 nor are they indicative of future consolidated results of operations.


	Nine Months Ended September 30,
	2023		2022

	(Thousands, except per share amounts)
Pro forma sales of natural gas, NGLs and oil	$	4,145,295	$	10,899,338
Pro forma gain (loss) on derivatives	1,324,773		(5,535,540)
Pro forma net marketing services and other	20,720		31,034
Pro forma total operating revenues	$	5,490,788	$	5,394,832

Pro forma net income	$	1,410,143	$	646,609
Less: Pro forma net (loss) income attributable to noncontrolling interests	(80)		8,120
Pro forma net income attributable to EQT Corporation	$	1,410,223	$	638,489

Pro forma income per share of common stock attributable to EQT Corporation:
Pro forma net income attributable to EQT Corporation – Basic	$	3.82	$	1.72
Pro forma net income attributable to EQT Corporation – Diluted	$	3.52	$	1.69

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EQT CORPORATION AND SUBSIDIARIES

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

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

The following discussion and analysis of financial condition and results of operations should be read in conjunction with the Condensed Consolidated Financial Statements and the notes thereto included in this report. Unless the context otherwise indicates, all references in this report to "EQT," the "Company," "we," "us," or "our" are to EQT Corporation and its subsidiaries, collectively. For certain industry specific terms used in this Quarterly Report on Form 10-Q, please see "Glossary of Commonly Used Terms, Abbreviations and Measurements" in our Annual Report on Form 10-K for the year ended December 31, 2022.

CAUTIONARY STATEMENTS

This Quarterly Report on Form 10-Q contains certain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and Section 27A of the Securities Act of 1933, as amended (the Securities Act). Statements that do not relate strictly to historical or current facts are forward-looking and are usually identified by the use of words such as "anticipate," "estimate," "could," "would," "will," "may," "forecast," "approximate," "expect," "project," "intend," "plan," "believe" and other words of similar meaning, or the negative thereof, in connection with any discussion of future operating or financial matters. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10-Q include the 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 and growth rates; natural gas prices; changes in basis and the impact of commodity prices on our business; potential future impairments of our assets; projected well costs and capital expenditures; infrastructure programs; the cost, capacity, and timing of obtaining regulatory approvals; our ability to successfully implement and execute our operational, organizational, technological and environmental, social and governance (ESG) initiatives, and achieve the anticipated results of such initiatives; projected gathering and compression rates; potential acquisitions or other strategic transactions, the timing thereof and our ability to achieve the intended operational, financial and strategic benefits from any such transactions or from any recently completed acquisitions or other strategic transactions, including the Tug Hill and XcL Midstream Acquisition (defined and discussed in Note 9 to the Condensed Consolidated Financial Statements); the amount and timing of any repayments, redemptions or repurchases of our common stock, outstanding debt securities or other debt instruments; our ability to retire our debt and the timing of such retirements, if any; the projected amount and timing of dividends; projected cash flows and free cash flow and the timing thereof; liquidity and financing requirements, including funding sources and availability; our ability to maintain or improve our credit ratings, leverage levels and financial profile; our hedging strategy and projected margin posting obligations; the effects of litigation, government regulation and tax position; and the expected impact of changes to tax laws.

The forward-looking statements included in this Quarterly Report on Form 10-Q involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. We have based these forward-looking statements on current expectations and assumptions about future events, taking into account all information currently known by us. While we consider these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks and uncertainties, many of which are difficult to predict and beyond our control. These risks and uncertainties include, but are not limited to, volatility of commodity prices; the costs and results of drilling and operations; uncertainties about estimates of reserves, identification of drilling locations and the ability to add proved reserves in the future; the assumptions underlying production forecasts; the quality of technical data; our ability to appropriately allocate capital and other resources among our strategic opportunities; access to and cost of capital, including as a result of rising interest rates and other economic uncertainties; our hedging and other financial contracts; inherent hazards and risks normally incidental to drilling for, producing, transporting and storing natural gas, natural gas liquids (NGLs) and oil; cyber security risks and acts of sabotage; availability and cost of drilling rigs, completion services, equipment, supplies, personnel, oilfield services and sand and water required to execute our exploration and development plans, including as a result of inflationary pressures; risks associated with operating primarily in the Appalachian Basin and obtaining a substantial amount of our midstream services from Equitrans Midstream Corporation (Equitrans Midstream); the ability to obtain environmental and other permits and the timing thereof; 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; and disruptions to our business due to acquisitions and other significant transactions, including the Tug Hill and XcL Midstream Acquisition. These and other risks and uncertainties are described under the "Risk Factors" section and elsewhere in our Annual Report on Form 10-K for the year ended December 31, 2022, and may be updated by the "Risk Factors" section of subsequent Quarterly Reports on Form 10-Q and other documents we subsequently file from time to time with the Securities and Exchange Commission.

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.

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EQT CORPORATION AND SUBSIDIARIES

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

Consolidated Results of Operations

Net income attributable to EQT Corporation for the three months ended September 30, 2023 was $81.3 million, $0.20 per diluted share, compared to net income attributable to EQT Corporation for the same period in 2022 of $683.7 million, $1.69 per diluted share. The decrease was attributable primarily to decreased sales of natural gas, NGLs and oil, partly offset by a gain on derivatives in 2023 compared to a loss on derivatives in 2022 and income tax benefit in 2023 compared to income tax expense in 2022.

Net income attributable to EQT Corporation for the nine months ended September 30, 2023 was $1,233.2 million, $3.08 per diluted share, compared to net income attributable to EQT Corporation for the same period in 2022 of $59.0 million, $0.16 per diluted share. The increase was attributable primarily to a gain on derivatives in 2023 compared to a loss on derivatives in 2022, impairment of the contract asset in 2022 and a loss on debt extinguishment in 2022, partly offset by decreased sales of natural gas, NGLs and oil and income tax expense in 2023 compared to income tax benefit in 2022.

Results of operations for 2023 include the results of approximately one month of our operation of assets acquired in the Tug Hill and XcL Midstream Acquisition, which closed on August 22, 2023. See Note 9 to the Condensed Consolidated Financial Statements for further discussion of the Tug Hill and XcL Midstream Acquisition.

See "Sales Volume and Revenues" and "Operating Expenses" for discussions of items affecting operating income 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.

Trends and Uncertainties

Our sales volume and operating expenses on a per Mcfe basis for 2022 and the first half of 2023 were negatively impacted by fewer wells turned-in-line during 2022 compared to our 2022 planned development schedule due to third-party supply chain constraints. In addition, as a result of third-party supply chain constraints in 2022, we shifted the planned development of approximately 30 wells from 2022 to 2023 (the Rescheduled Wells). All of the Rescheduled Wells have been completed and were turned-to-sales as of July 2023, resulting in our third quarter 2023 sales volume returning to our maintenance level of production; however, our third quarter 2023 sales volume was negatively impacted by approximately 13 Bcfe of curtailments (inclusive of our operated and non-operated wells) principally in response to lower natural gas prices in the Appalachian Basin. Future supply chain constraints or declines in natural gas prices may result in adjustments to our 2023 planned development schedule or the development schedule of non-operated wells in which we have a working interest. Our sales volume and operating expenses on a per Mcfe basis for the second quarter of 2023 were also negatively impacted by lower-than-expected liquids volumes from unscheduled downtime at an in-basin ethane cracker plant to conduct equipment repairs and maintenance and a delay in the development schedule of certain wells that are not operated by us but in which we have a working interest in the volumes produced from such wells. We cannot control or otherwise influence the development schedule of non-operated wells in which we have a working interest. Adjustments to our 2023 planned development schedule or the development schedule of non-operated wells in which we have a working interest could impact our future sales volume, operating revenues and expenses, per unit metrics and capital expenditures.

The annual inflation rate in the United States was particularly high during 2022, and, although the inflation rate has decreased through 2023, it still remains elevated compared to historical levels. Inflationary pressures have multiple impacts on our business, including increasing our operating expenses and our cost of capital. While the prices for certain of the raw materials and services we use in our operations have generally decreased from the peak prices experienced during 2022, we will not fully realize the benefit of such reduced prices until we enter into new contracts for such materials and services, and inflationary pressures may cause prices to fluctuate. Additionally, certain of our commitments for demand charges under our existing long-term contracts and processing capacity are subject to consumer price index adjustments. Although we believe our scale and supply chain contracting strategy of using multi-year sand and frac crew contracts allows us to maximize capital and operating efficiencies, future increases in the inflation rate will negatively impact our long-term contracts with consumer price index adjustments.

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EQT CORPORATION AND SUBSIDIARIES

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

Additionally, while the prices for natural gas, NGLs and oil have historically been volatile, price volatility was especially pronounced during 2022, with natural gas prices peaking in August 2022 and steadily declining thereafter. Natural gas prices have generally continued to trend down through the first half of 2023 but have moderately increased during the third quarter of 2023, although, through most of 2023, natural gas prices on average have remained lower than the prices experienced throughout 2022. We expect commodity price volatility to continue or increase throughout the remainder of 2023 due to macroeconomic uncertainty and geopolitical tensions, including continued developments pertaining to Russia's invasion of Ukraine and conflicts in the Middle East. Our revenue, profitability, rate of growth, 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.

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 adjusted operating revenues, a non-GAAP supplemental financial measure. Adjusted operating revenues is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Adjusted operating revenues should not be considered as an alternative to total operating revenues. See "Non-GAAP Financial Measures Reconciliation" for a reconciliation of adjusted operating revenues with total operating revenues, the most directly comparable financial measure calculated in accordance with 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,
	2023		2022		2023		2022

	(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)	491,472		463,856		1,374,527		1,406,715
NYMEX price ($/MMBtu)	$	2.55	$	8.18	$	2.68	$	6.75
Btu uplift	0.13		0.44		0.14		0.35
Natural gas price ($/Mcf)	$	2.68	$	8.62	$	2.82	$	7.10

Basis ($/Mcf) (a)	$	(0.93)	$	(0.97)	$	(0.39)	$	(0.70)
Cash settled basis swaps ($/Mcf)	0.12		(0.05)		(0.08)		(0.08)
Average differential, including cash settled basis swaps ($/Mcf)	$	(0.81)	$	(1.02)	$	(0.47)	$	(0.78)
Average adjusted price ($/Mcf)	$	1.87	$	7.60	$	2.35	$	6.32
Cash settled derivatives ($/Mcf)	0.27		(4.32)		0.37		(3.24)
Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.14	$	3.28	$	2.72	$	3.08
Natural gas sales, including cash settled derivatives	$	1,053,146	$	1,519,597	$	3,741,247	$	4,335,811

LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)	16,629		13,841		41,805		43,043
Sales volume (Mbbl)	2,772		2,307		6,968		7,174
NGLs price ($/Bbl)	$	35.42	$	48.77	$	35.34	$	57.25
Cash settled derivatives ($/Bbl)	(1.10)		(3.78)		(1.54)		(4.45)
Average NGLs price, including cash settled derivatives ($/Bbl)	$	34.32	$	44.99	$	33.80	$	52.80
NGLs sales, including cash settled derivatives	$	95,120	$	103,789	$	235,509	$	378,811
Ethane:
Sales volume (MMcfe) (b)	11,528		8,464		29,198		27,071
Sales volume (Mbbl)	1,921		1,411		4,866		4,512
Ethane price ($/Bbl)	$	5.23	$	15.68	$	5.90	$	14.47
Ethane sales	$	10,039	$	22,123	$	28,699	$	65,276
Oil:
Sales volume (MMcfe) (b)	3,071		1,505		6,814		4,629
Sales volume (Mbbl)	512		251		1,136		772
Oil price ($/Bbl)	$	66.75	$	63.20	$	59.91	$	80.12
Oil sales	$	34,166	$	15,852	$	68,034	$	61,815

Total liquids sales volume (MMcfe) (b)	31,228		23,810		77,817		74,743
Total liquids sales volume (Mbbl)	5,205		3,969		12,970		12,458
Total liquids sales	$	139,325	$	141,764	$	332,242	$	505,902

TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,192,471	$	1,661,361	$	4,073,489	$	4,841,713
Total sales volume (MMcfe)	522,700		487,666		1,452,344		1,481,458
Average realized price ($/Mcfe)	$	2.28	$	3.41	$	2.80	$	3.27

(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 Mcfe at a rate of six Mcfe per barrel.

(c)Total natural gas and liquids sales, including cash settled derivatives, is also referred to in this report as 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 adjusted operating revenues, a non-GAAP supplemental financial measure, with total operating revenues, its most directly comparable financial measure calculated in accordance with GAAP. 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. Adjusted operating revenues excludes the revenue impacts of changes in the fair value of derivative instruments prior to settlement and net marketing services and other. We use adjusted operating revenues to evaluate earnings trends because, as a result of the measure's exclusion of the often-volatile changes in the fair value of derivative instruments prior to settlement, the measure reflects only the impact of settled derivative contracts. Net marketing services and other consists of the costs of, and recoveries on, pipeline capacity releases, revenues for gathering and processing services provided to third parties and other revenues. Because we consider net marketing services and other to be unrelated to our natural gas and liquids production activities, adjusted operating revenues excludes net marketing services and other. We believe that adjusted operating revenues provides useful information to investors for evaluating period-to-period comparisons of earnings trends.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands, unless otherwise noted)
Total operating revenues	$	1,186,102	$	2,069,463	$	4,865,924	$	4,017,861
(Deduct) add:
(Gain) loss on derivatives	(177,906)		1,627,296		(1,167,144)		5,550,028
Net cash settlements received (paid) on derivatives	255,804		(2,033,727)		625,051		(4,672,998)
Premiums (paid) received for derivatives that settled during the period	(65,216)		894		(232,128)		(31,318)
Net marketing services and other	(6,313)		(2,565)		(18,214)		(21,860)
Adjusted operating revenues, a non-GAAP financial measure	$	1,192,471	$	1,661,361	$	4,073,489	$	4,841,713

Total sales volume (MMcfe)	522,700		487,666		1,452,344		1,481,458
Average realized price ($/Mcfe)	$	2.28	$	3.41	$	2.80	$	3.27

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EQT CORPORATION AND SUBSIDIARIES

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

Sales Volume and Revenues

Three Months Ended September 30, 2023 Compared to Three Months Ended September 30, 2022


	Three Months Ended September 30,
	2023		2022		Change		% Change

	(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):
Marcellus	492,172		456,495		35,677		7.8
Ohio Utica	21,801		30,531		(8,730)		(28.6)
Other	8,727		640		8,087		1,263.6
Total sales volume	522,700		487,666		35,034		7.2

Average daily sales volume (MMcfe/d)	5,682		5,301		381		7.2

Operating revenues:
Sales of natural gas, NGLs and oil	$	1,001,883	$	3,694,194	$	(2,692,311)	(72.9)
Gain (loss) on derivatives	177,906		(1,627,296)		1,805,202		(110.9)
Net marketing services and other	6,313		2,565		3,748		146.1
Total operating revenues	$	1,186,102	$	2,069,463	$	(883,361)	(42.7)

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil decreased for the three months ended September 30, 2023 compared to the same period in 2022 due to lower average realized price, partly offset by increased sales volume.

Average realized price decreased for the three months ended September 30, 2023 compared to the same period in 2022 due to lower NYMEX prices, partly offset by favorable cash settled derivatives and favorable differential. For the three months ended September 30, 2023, we received $255.8 million of net cash settlements on derivatives, composed of $199.0 million of net cash settlements received on our NYMEX natural gas hedge positions and $56.8 million of net cash settlements received on our basis and liquids hedge positions. For the same period in 2022, we paid $2,033.7 million of net cash settlements on derivatives, composed of $2,003.2 million of net cash settlements paid on our NYMEX natural gas hedge positions and $30.5 million of net cash settlements paid on our basis and liquids hedge positions. Net cash settlements received (paid) on derivatives are included in average realized price but may not be included in operating revenues. For the three months ended September 30, 2023 and 2022, we paid $65.2 million and received $0.9 million, respectively, of premiums for derivatives that settled during the period.

Sales volume increased for the three months ended September 30, 2023 compared to the same period in 2022 primarily as a result of sales volume increases of 25 Bcfe from the assets acquired in the Tug Hill and XcL Midstream Acquisition in addition to wells, including the Rescheduled Wells, turned-in-line during 2023.

Gain (loss) on derivatives. For the three months ended September 30, 2023, we recognized a gain on derivatives of $177.9 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices. For the same period in 2022, we recognized a loss on derivatives of $1,627.3 million related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.

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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, 2023 Compared to Nine Months Ended September 30, 2022


	Nine Months Ended September 30,
	2023		2022		Change		% Change

	(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):
Marcellus	1,375,952		1,377,637		(1,685)		(0.1)
Ohio Utica	64,481		98,206		(33,725)		(34.3)
Other	11,911		5,615		6,296		112.1
Total sales volume	1,452,344		1,481,458		(29,114)		(2.0)

Average daily sales volume (MMcfe/d)	5,320		5,427		(107)		(2.0)

Operating revenues:
Sales of natural gas, NGLs and oil	$	3,680,566	$	9,546,029	$	(5,865,463)	(61.4)
Gain (loss) on derivatives	1,167,144		(5,550,028)		6,717,172		(121.0)
Net marketing services and other	18,214		21,860		(3,646)		(16.7)
Total operating revenues	$	4,865,924	$	4,017,861	$	848,063	21.1

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil decreased for the nine months ended September 30, 2023 compared to the same period in 2022 due to lower average realized price and decreased sales volume.

Average realized price decreased for the nine months ended September 30, 2023 compared to the same period in 2022 due to lower NYMEX and liquids prices, partly offset by favorable cash settled derivatives and favorable differential. For the nine months ended September 30, 2023, we received $625.1 million of net cash settlements on derivatives, composed of $738.1 million of net cash settlements received on our NYMEX natural gas hedge positions and $113.0 million of net cash settlements paid on our basis and liquids hedge positions. For the same period in 2022, we paid $4,673.0 million of net cash settlements on derivatives, composed of $4,525.4 million of net cash settlements paid on our NYMEX natural gas hedge positions and $147.6 million of net cash settlements paid on our basis and liquids hedge positions. Net cash settlements received (paid) on derivatives are included in average realized price but may not be included in operating revenues. For the nine months ended September 30, 2023 and 2022, we paid premiums for derivatives that settled during the period of $232.1 million and $31.3 million, respectively.

Sales volume decreased for the nine months ended September 30, 2023 compared to the same period in 2022 primarily as a result of sales volume decreases from natural decline of producing wells, fewer wells turned-in-line throughout 2022 as a result of third-party supply chain constraints and delays in the development schedule of certain non-operated wells in which we have a working interest, partly offset by sales volume increases of 25 Bcfe from the assets acquired in the Tug Hill and XcL Midstream Acquisition as well as sales volume increases from our operated wells as a result of efficiencies in our drilling and completions operations and wells, including the Rescheduled Wells, turned-in-line during 2023.

Gain (loss) on derivatives. For the nine months ended September 30, 2023, we recognized a gain on derivatives of $1,167.1 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices, partly offset by a loss on the derivative liability related to the Henry Hub Cash Bonus (defined and discussed in Note 3 to the Condensed Consolidated Financial Statements). For the same period in 2022, we recognized a loss on derivatives of $5,550.0 million related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices, partly offset by a gain on the derivative liability related to the Henry Hub Cash Bonus.

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EQT CORPORATION AND SUBSIDIARIES

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

Operating Expenses

Three Months Ended September 30, 2023 Compared to Three Months Ended September 30, 2022


	Three Months Ended September 30,
	2023		2022		Change		% Change

	(Thousands, unless otherwise noted)
Operating expenses:
Gathering	$	328,549	$	337,532	$	(8,983)	(2.7)
Transmission	166,572		151,425		15,147		10.0
Processing	59,667		52,135		7,532		14.4
Lease operating expense (LOE)	44,318		39,934		4,384		11.0
Production taxes	22,775		41,851		(19,076)		(45.6)


Exploration	447		357		90		25.2
Selling, general and administrative	56,942		67,231		(10,289)		(15.3)

Production depletion	$	439,613	$	413,706	$	25,907	6.3
Other depreciation and depletion	7,273		4,989		2,284		45.8
Total depreciation and depletion	$	446,886	$	418,695	$	28,191	6.7

Per Unit ($/Mcfe):
Gathering	$	0.63	$	0.69	$	(0.06)	(8.7)
Transmission	0.32		0.31		0.01		3.2
Processing	0.11		0.11		—		—
LOE	0.08		0.08		—		—
Production taxes	0.04		0.09		(0.05)		(55.6)

Selling, general and administrative	0.11		0.14		(0.03)		(21.4)
Production depletion	0.84		0.85		(0.01)		(1.2)

Gathering. Gathering expense decreased on an absolute and per Mcfe basis for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to lower gathering rates on certain contracts indexed to price as well as the impact of the gathering assets acquired in the Tug Hill and XcL Midstream Acquisition, which are wholly-owned by us and, therefore, reduce our gathering cost structure on a per Mcfe basis.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to additional capacity acquired.

Processing. Processing expense increased on an absolute basis for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to processing expenses for the liquids-rich assets acquired in the Tug Hill and XcL Midstream Acquisition.

LOE. LOE increased on an absolute basis for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to the assets acquired in the Tug Hill and XcL Midstream Acquisition, partly offset by lower salt water disposal costs and increased recycling. Saltwater disposal costs and recycle rates were favorably impacted by increased use of our internally developed produced water gathering and storage system, which was placed in service during the fourth quarter of 2022.

Production taxes. Production taxes decreased on an absolute and per Mcfe basis for the three months ended September 30, 2023 compared to the same period in 2022 due to lower West Virginia severance taxes and Pennsylvania impact fees, which decreased due to lower TETCO M2 and NYMEX prices, respectively.

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EQT CORPORATION AND SUBSIDIARIES

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

Selling, general and administrative. Selling, general and administrative expense decreased on an absolute and per Mcfe basis for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to lower long-term incentive compensation costs as a result of decreases in awards outstanding and changes in the fair value of awards. Long-term incentive compensation may fluctuate with changes in our stock price and performance conditions.

Depreciation and depletion. Production depletion expense increased on an absolute basis for the three months ended September 30, 2023 compared to the same period in 2022 due to increased sales volume.

Impairment and expiration of leases. During the three months ended September 30, 2023 and 2022, we recognized impairment and expiration of leases of $6.4 million and $20.5 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses increased for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to transaction costs associated with the Tug Hill and XcL Midstream Acquisition, partly offset by decreased legal reserves, including from settlements.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022


	Nine Months Ended September 30,
	2023		2022		Change		% Change

	(Thousands, unless otherwise noted)
Operating expenses:
Gathering	$	954,304	$	997,161	$	(42,857)	(4.3)
Transmission	473,651		447,914		25,737		5.7
Processing	164,979		151,825		13,154		8.7
LOE	108,334		122,577		(14,243)		(11.6)
Production taxes	61,737		112,776		(51,039)		(45.3)


Exploration	2,602		2,870		(268)		(9.3)
Selling, general and administrative	168,999		195,603		(26,604)		(13.6)

Production depletion	$	1,212,499	$	1,254,566	$	(42,067)	(3.4)
Other depreciation and depletion	17,756		15,370		2,386		15.5
Total depreciation and depletion	$	1,230,255	$	1,269,936	$	(39,681)	(3.1)

Per Unit ($/Mcfe):
Gathering	$	0.66	$	0.67	$	(0.01)	(1.5)
Transmission	0.33		0.30		0.03		10.0
Processing	0.11		0.10		0.01		10.0
LOE	0.07		0.08		(0.01)		(12.5)
Production taxes	0.04		0.08		(0.04)		(50.0)

Selling, general and administrative	0.12		0.13		(0.01)		(7.7)
Production depletion	0.83		0.85		(0.02)		(2.4)

Gathering. Gathering expense decreased on an absolute basis for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to lower gathering rates on certain contracts indexed to price as well as decreased sales volume. Gathering expense decreased on a per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to lower gathering rates on certain contracts indexed to price.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to additional capacity acquired, partly offset by credits received from the Texas Eastern Transmission Pipeline.

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EQT CORPORATION AND SUBSIDIARIES

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

Processing. Processing expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to processing expenses for the liquids-rich assets acquired in the Tug Hill and XcL Midstream Acquisition as well as inflation of contracted processing rates.

LOE. LOE decreased on an absolute and per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to lower salt water disposal costs and increased recycling. Saltwater disposal costs and recycle rates were favorably impacted by increased use of our internally developed produced water gathering and storage system, which was placed in service during the fourth quarter of 2022.

Production taxes. Production taxes decreased on an absolute and per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due to lower West Virginia severance taxes and Pennsylvania impact fees, which decreased due to lower sales volume and lower TETCO M2 and NYMEX prices, respectively.

Selling, general and administrative. Selling, general and administrative expense decreased on an absolute and per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to lower long-term incentive compensation costs as a result of decreases in awards outstanding and changes in the fair value of awards. Long-term incentive compensation may fluctuate with changes in our stock price and performance conditions.

Depreciation and depletion. Production depletion expense decreased on an absolute and per Mcfe basis for the nine months ended September 30, 2023 compared to the same period in 2022 due to a lower annual depletion rate and decreased sales volume.

Loss (gain) on sale/exchange of long-lived assets. During the nine months ended September 30, 2023, we recognized a loss on sale/exchange of long-lived assets of $17.8 million related to acreage trade agreements where the carrying value of the acres traded exceeded the fair value of the acres received.

Impairment of contract asset. During the nine months ended September 30, 2022, we recognized impairment of our contract asset of $184.9 million. See Note 8 to the Condensed Consolidated Financial Statements.

Impairment and expiration of leases. During the nine months ended September 30, 2023 and 2022, we recognized impairment and expiration of leases of $22.3 million and $97.5 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses increased for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to transaction costs associated with the Tug Hill and XcL Midstream Acquisition, partly offset by decreased legal reserves, including from settlements.

Other Income Statement Items

(Income) loss from investments. For the nine months ended September 30, 2023, we recognized income from investments due to equity earnings on our equity method investments and a gain on our investment in the Investment Fund (defined in Note 4 to the Condensed Consolidated Financial Statements). For the nine months ended September 30, 2022, we recognized a loss from investments due to a loss on our sale of our investment in Equitrans Midstream, partly offset by equity earnings on our equity method investments and a gain on our investment in the Investment Fund.

Dividend and other income. Dividend and other income decreased for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to lower dividends received on our investment in the Investment Fund as well as dividends received on our investment in Equitrans Midstream in 2022.

Loss (gain) on debt extinguishment. During the three and nine months ended September 30, 2022, we recognized a loss on debt extinguishment of $27.8 million and $139.1 million, respectively, due to the repayment and repurchase of debt discussed in Note 6 to the Condensed Consolidated Financial Statements.

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EQT CORPORATION AND SUBSIDIARIES

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

Interest expense, net. Interest expense, net was flat for the three months ended September 30, 2023 compared to the same period in 2022 due primarily to higher interest expense on debt as a result of senior notes issuances in the fourth quarter of 2022 as well as the draw down of the Term Loan Facility (defined and discussed in Note 6 to the Condensed Consolidated Financial Statements) in August 2023, wholly offset by higher interest income earned as well as lower interest expense on our revolving credit facility from lower borrowings thereunder.

Interest expense, net decreased for the nine months ended September 30, 2023 compared to the same period in 2022 due primarily to higher interest income earned as well as lower interest expense on our revolving credit facility from lower borrowings and reduced letters of credit balances thereunder, partly offset by higher interest expense on debt as a result of senior notes issuances in the fourth quarter of 2022 as well as the draw down of the Term Loan Facility in August 2023.

Income tax (benefit) expense. See Note 5 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 our revolving credit facility should be sufficient to meet our cash requirements inclusive of, but not limited to, normal operating needs, debt service obligations, planned capital expenditures and commitments for at least the next twelve months and, based on current expectations, for the long term.

Planned Capital Expenditures and Sales Volume. In the fourth quarter of 2023, we expect to spend approximately $525 million to $575 million in total capital expenditures. We expect to fund our capital expenditures with cash generated from operations and, if required, borrowings under our revolving credit facility. Because we are the operator of a high percentage of our developed acreage, the amount and timing of certain of our capital expenditures is largely discretionary. We could choose to defer a portion of our planned 2023 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 2023, we expect our sales volume to be 525 Bcfe to 575 Bcfe.

Operating Activities. Net cash provided by operating activities was $2,554 million for the nine months ended September 30, 2023 compared to $2,402 million for the same period in 2022. The increase was due primarily to net cash settlements received on derivatives in 2023 compared to net cash settlements paid on derivatives in 2022, favorable changes in working capital driven by declining accounts receivable and lower margin postings as well as lower cash operating expenses and interest expense, partly offset by lower cash operating revenues.

Our cash flows from operating activities are affected by movements in the market price for commodities. We are unable to predict such movements outside of the current market view as reflected in forward strip pricing. For a discussion of potential commodity market risks, refer to "Risk Factors – Natural gas, NGLs and oil price volatility, or a prolonged period of low natural gas, NGLs and oil prices, may have an adverse effect on our revenue, profitability, future rate of growth, liquidity and financial position" in our Annual Report on Form 10-K for the year ended December 31, 2022.

Investing Activities. Net cash used in investing activities was $3,774 million for the nine months ended September 30, 2023 compared to $1,017 million for the same period in 2022. The increase was attributable primarily to cash paid for the Tug Hill and XcL Midstream Acquisition in 2023 and increased capital expenditures.

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EQT CORPORATION AND SUBSIDIARIES

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

The following table summarizes our capital expenditures.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Millions)
Reserve development	$	355	$	271	$	1,147	$	797
Land and lease (a)	41		34		101		122
Capitalized overhead	15		14		44		39
Capitalized interest	8		7		27		19
Other production infrastructure	17		27		49		59
Other	9		3		19		6
Total capital expenditures	445		356		1,387		1,042
Add: Non-cash items (b)	59		6		99		5
Total cash capital expenditures	$	504	$	362	$	1,486	$	1,047

(a)Capital expenditures attributable to noncontrolling interests were $6.6 million for the three months ended September 30, 2022 and $8.5 million and $11.0 million for the nine months ended September 30, 2023 and 2022, respectively. There were no capital expenditures attributable to noncontrolling interests for the three months ended September 30, 2023.

(b)Represents the net impact of non-cash capital expenditures, including the effect of timing of receivables from working interest partners, accrued capital expenditures 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 $174 million for the nine months ended September 30, 2023 compared to $1,411 million for the same period in 2022. For the nine months ended September 30, 2023, the primary source of financing cash flows was proceeds from the Term Loan Facility borrowings, and the primary uses of financing cash flows were repayment and retirement of debt, repurchase and retirement of EQT Corporation common stock and payment of dividends. For the nine months ended September 30, 2022, the primary uses of financing cash flows were repayment and repurchase of debt, repurchase and retirement of EQT Corporation common stock and payment of dividends.

See Note 6 to the Condensed Consolidated Financial Statements for further discussion of our debt and borrowings under our revolving credit facility and the Term Loan Facility.

On October 12, 2023, our Board of Directors declared a quarterly cash dividend of $0.1575 per share of EQT Corporation common stock, payable on December 1, 2023, to shareholders of record at the close of business on November 8, 2023.

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 6 to the Condensed Consolidated Financial Statements for discussion of redemptions and repurchases of debt.

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EQT CORPORATION AND SUBSIDIARIES

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

Security Ratings and Financing Triggers

The table below reflects the credit ratings and rating outlooks assigned to our debt instruments as of September 30, 2023. 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 independent 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 3 to the Condensed Consolidated Financial Statements for a description of what is deemed investment grade.

Rating agency

Senior notes

Outlook

Moody's Investors Service (Moody's)

Baa3

Stable

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

BBB–

Stable

Fitch Ratings Service (Fitch)

BBB–

Stable

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

Our debt agreements and other financial obligations contain various provisions that, if not complied with, could result in default or event of default under our revolving credit facility and the Term Loan Facility, mandatory partial or full repayment of amounts outstanding, reduced loan capacity or other similar actions. The most significant covenants and events of default under our debt agreements relate to maintenance of a debt-to-total capitalization ratio, limitations on transactions with affiliates, insolvency events, nonpayment of scheduled principal or interest payments, acceleration of other financial obligations and change of control provisions. Our revolving credit facility and the Term Loan Facility contain financial covenants that require us to have a total debt to total capitalization ratio no greater than 65%. As of September 30, 2023, we were in compliance with all debt provisions and covenants under our debt agreements.

See Note 6 to the Condensed Consolidated Financial Statements for a discussion of borrowings under our revolving credit facility and the Term Loan Facility.

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EQT CORPORATION AND SUBSIDIARIES

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

Commodity Risk Management

The substantial majority of our commodity risk management program is related to hedging sales of our produced natural gas. The overall objective of our hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices. The derivative commodity instruments that we use are primarily swap, collar and option agreements. The following table summarizes the approximate volume and prices of our NYMEX hedge positions as of October 20, 2023. 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 2023 (a)		Q1 2024		Q2 2024		Q3 2024		Q4 2024
Hedged Volume (MMDth)	377		263		239		237		98
Hedged Volume (MMDth/d)	4.1		2.9		2.6		2.6		1.1

Swaps – Long
Volume (MMDth)	14		—		—		—		—
Avg. Price ($/Dth)	$	4.77	$	—	$	—	$	—	$	—

Swaps – Short
Volume (MMDth)	97		113		191		188		65
Avg. Price ($/Dth)	$	3.01	$	3.59	$	3.28	$	3.28	$	3.28

Calls – Long
Volume (MMDth)	58		13		13		13		13
Avg. Strike ($/Dth)	$	3.28	$	3.20	$	3.20	$	3.20	$	3.20

Calls – Short
Volume (MMDth)	243		162		61		62		46
Avg. Strike ($/Dth)	$	4.78	$	6.16	$	4.22	$	4.22	$	4.27

Puts – Long
Volume (MMDth)	294		150		48		49		33
Avg. Strike ($/Dth)	$	3.67	$	4.17	$	3.93	$	3.93	$	4.04









Option Premiums
Cash Settlement of Deferred Premiums (millions)	$	(91)	$	(34)	$	(4)	$	(4)	$	—

(a)October 1 through December 31.

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

See "Quantitative and Qualitative Disclosures About Market Risk" and Note 3 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 for such matters when we believe that a loss is probable and the amount of the loss can be reasonably estimated. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event we determine that (i) a loss is probable but the amount of the loss cannot be reasonably estimated, or (ii) a loss is less likely than probable but is reasonably possible, then we are required to disclose the matter in our Annual Report on Form 10-K or this Quarterly Report on Form 10-Q, as applicable, although we are not required to accrue such loss.

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EQT CORPORATION AND SUBSIDIARIES

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

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 our Annual Report on Form 10-K for the year ended December 31, 2022 for a discussion of our commitments and contingencies, including certain pending legal and regulatory proceedings and other contingent matters. As of September 30, 2023, there have been no material changes to such matters as disclosed therein. See also "Legal Proceedings" for a description of certain other pending environmental matters for which we accrued contingent liabilities.

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

Critical Accounting Policies and Estimates

Our critical accounting policies, including a discussion regarding the estimation uncertainty and the impact that our critical accounting estimates have had, or are reasonably likely to have, on our financial condition or results of operations, are described in the "Management's Discussion and Analysis of Financial Condition and Results of Operations" section of our Annual Report on Form 10-K for the year ended December 31, 2022. The application of our critical accounting policies 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. Due to the volatility of commodity prices, we are unable to predict future potential movements in the market prices for natural gas and NGLs at our ultimate sales points and, thus, cannot predict the ultimate impact of prices on our operations. Prolonged low, or significant, extended declines in, natural gas and NGLs prices could adversely affect, among other things, our development plans, which would decrease the pace of development and the level of our proved reserves. Increases in natural gas and NGLs prices may be accompanied by, or result in, increased well drilling costs, increased production taxes, increased LOE, increased volatility in seasonal gas price spreads for our storage assets and increased end-user conservation or conversion to alternative fuels. In addition, to the extent we have hedged our production at prices below the current market price, we will not benefit fully from an increase in the price of natural gas, and, depending on our then-current credit ratings and the terms of our hedging contracts, we may be required to post additional margin with our hedging counterparties.

The overall objective of our hedging program is to protect our cash flows from undue exposure to the risk of changing commodity prices. Our use of derivatives is further described in Note 3 to the Condensed Consolidated Financial Statements and "Management's Discussion and Analysis of Financial Condition and Results of Operations – Capital Resources and Liquidity – Commodity Risk Management." Our OTC derivative commodity instruments are placed primarily with financial institutions and the creditworthiness of those institutions is regularly monitored. We primarily enter into derivative instruments to hedge forecasted sales of production. We also enter into derivative instruments to hedge basis. Our use of derivative instruments is implemented under a set of policies approved by our management-level Hedge and Financial Risk Committee and is reviewed by our Board of Directors.

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

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

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

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A hypothetical decrease of 10% in the NYMEX natural gas price on September 30, 2023 and December 31, 2022 would increase the fair value of our natural gas derivative commodity instruments by approximately $319 million and $727 million, respectively. A hypothetical increase of 10% in the NYMEX natural gas price on September 30, 2023 and December 31, 2022 would decrease the fair value of our natural gas derivative commodity instruments by approximately $323 million and $333 million, respectively. For purposes of this analysis, we applied the 10% change in the NYMEX natural gas price on September 30, 2023 and December 31, 2022 to our natural gas derivative commodity instruments as of September 30, 2023 and December 31, 2022 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 4 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. Changes in market interest rates affect the amount of interest we earn on cash, cash equivalents and short-term investments and the interest rate we pay on borrowings under our revolving credit facility and the Term Loan Facility. None of the interest we pay on our senior notes fluctuates based on changes to market interest rates. A 1% increase in interest rates on the borrowings under our revolving credit facility and the Term Loan Facility during the nine months ended September 30, 2023 would have increased interest expense by approximately $13 million.

Interest rates for our revolving credit facility, the Term Loan Facility, our 6.125% senior notes due 2025 and our 7.000% senior notes due 2030 fluctuate based on changes to the credit ratings assigned to our senior notes by Moody's, S&P and Fitch. Interest rates on our other outstanding senior notes do not fluctuate based on changes to the credit ratings assigned to our senior notes by Moody's, S&P and Fitch. For a discussion of credit rating downgrade risk, see "Risk Factors – Our exploration and production operations have substantial capital requirements, and we may not be able to obtain needed capital or financing on satisfactory terms" in our Annual Report on Form 10-K for the year ended December 31, 2022. Changes in interest rates affect the fair value of our fixed rate debt. See Note 6 to the Condensed Consolidated Financial Statements for further discussion of our debt and Note 4 to the Condensed Consolidated Financial Statements for a discussion of fair value measurements, including the fair value measurement of our debt.

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

Approximately 70%, or $536 million, of our OTC derivative contracts outstanding at September 30, 2023 had a positive fair value. Approximately 36%, or $710 million, of our OTC derivative contracts outstanding at December 31, 2022 had a positive fair value.

As of September 30, 2023, we were not in default under any derivative contracts and had no knowledge of default by any counterparty to our derivative contracts. During the three months ended September 30, 2023, we made no adjustments to the fair value of our derivative contracts due to credit related concerns outside of the normal non-performance risk adjustment included in our established fair value procedure. We monitor market conditions that may impact the fair value of our derivative contracts.

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

No one lender of the large group of financial institutions in the syndicate for our revolving credit facility and the Term Loan Facility holds more than 10% and 15%, respectively, of the financial commitments under such facility. The large syndicate group and relatively low percentage of participation by each lender are expected to limit our exposure to disruption or consolidation in the banking industry.

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 2023 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

During the third quarter of 2023, we completed the Tug Hill and XcL Midstream Acquisition and began integrating the acquired assets into our internal control over financial reporting. We will continue to evaluate and monitor our internal control over financial reporting and will continue to evaluate the operating effectiveness of related key controls.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts claimed may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We accrue legal and other direct costs related to loss contingencies when actually incurred. We have established reserves in amounts that we believe to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, we believe that the ultimate outcome of any pending matter involving us will not materially affect our financial position, results of operations or liquidity.

There are no material updates to the matters previously disclosed in the "Legal Proceedings" section of our Annual Report on Form 10-K for the year ended December 31, 2022 and in the "Legal Proceedings" sections of our Quarterly Reports on Form 10-Q for the periods ended March 31, 2023 and June 30, 2023.

Item 1A. Risk Factors

There are no material changes to the risk factors previously disclosed in the "Risk Factors" section of our Annual Report on Form 10-K for the year ended December 31, 2022.

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Item 2. Unregistered Sales of Equity Securities, Use of Proceeds, and Issuer Purchases of Equity Securities

Conversion of Certain Convertible Notes. During the third quarter of 2023, we settled conversion notices submitted by holders of Convertible Notes (defined and discussed in Note 6 to the Condensed Consolidated Financial Statements) requesting the conversion of certain Convertible Notes (the Converted Notes) by issuing to such converting holders shares of EQT Corporation common stock as stated in the below table. Such shares were issued in transactions exempt from registration under the Securities Act by virtue of Section 3(a)(9) thereof because no commission or other remuneration was paid in connection with conversion of the Converted Notes.


Settlement Date	Principal Converted		Shares Issued	Fair Market Value
	(Thousands)			(Thousands)
July 5, 2023	$	7	477	$	20
July 25, 2023	3		205	8
September 13, 2023	6		411	17

Repurchases of Equity Securities. We did not repurchase any equity securities registered under Section 12 of the Exchange Act during the third quarter of 2023.

On December 13, 2021, we announced that our Board of Directors approved a share repurchase program (the Share Repurchase Program) authorizing us to repurchase shares of our outstanding common stock for an aggregate purchase price of up to $1 billion, excluding fees, commissions and expenses. On September 6, 2022, we announced that our Board of Directors approved a $1 billion increase to the Share Repurchase Program, pursuant to which approval we are authorized to repurchase shares of our outstanding common stock for an aggregate purchase price of up to $2 billion, excluding fees, commissions and expenses. Repurchases under the Share Repurchase Program may be made from time to time in amounts and at prices we deem appropriate and will be subject to a variety of factors, including the market price of our common stock, general market and economic conditions, applicable legal requirements and other considerations. The Share Repurchase Program was originally scheduled to expire on December 31, 2023; however, on April 26, 2023, we announced that our Board of Directors approved a one-year extension of the Share Repurchase Program. As a result of such extension, the Share Repurchase Program will expire on December 31, 2024, but it may be suspended, modified or discontinued at any time without prior notice. As of September 30, 2023, 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, 2023, none of our directors or "officers" (as such term is defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a "Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement" (as each term is defined in Item 408(a) of Regulation S-K).

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Item 6. Exhibits

Exhibit No.

Description

Method of Filing

2.01(a)*

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

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

2.01(b)

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

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

2.01(c)

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

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

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.

3.02

Amended and Restated Bylaws of EQT Corporation (as amended through May 1, 2020).

Incorporated herein by reference to Exhibit 3.4 to Form 8-K (#001-3551) filed on May 4, 2020.

10.01

Registration Rights Agreement, dated August 22, 2023, among EQT Corporation and certain security holders thereof party thereto, including THQ Appalachia I, LLC and THQ-XcL Holdings I, LLC.

Incorporated herein by reference to Exhibit 4.3 to Form S-3ASR (#333-274147) filed on August 22, 2023.

10.02(a)*

Letter Agreement, dated October 3, 2023, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC and EQM Gathering Opco, LLC, amending that certain Gas Gathering and Compression Agreement, dated February 26, 2020, as amended.

Filed herewith as Exhibit 10.02(a).

10.02(b )*

Fifth Amendment to Gas Gathering and Compression Agreement, dated October 4, 2023, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC and EQM Gathering OpCo, LLC.

Filed herewith as Exhibit 10.02(b).

10.02(c )*

Letter Agreement (Fuel Gas), dated October 5, 2023, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC, EQM Gathering Opco, LLC and Equitrans, L.P., relating to that certain Fifth Amendment to Gas Gathering and Compression Agreement, dated October 4, 2023.

Filed herewith as Exhibit 10.02(c).

10.02(d )*

Amended and Restated Letter Agreement, dated October 12, 2023, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC and EQM Gathering Opco, LLC, amending that certain Letter Agreement, dated October 3, 2023 and further that certain Gas Gathering and Compression Agreement, dated February 26, 2020, as amended.

Filed herewith as Exhibit 10.02(d).

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Exhibit No.

Description

Method of Filing

31.01

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

Filed herewith as Exhibit 31.01.

31.02

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

Filed herewith as Exhibit 31.02.

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

Furnished herewith as Exhibit 32.

101

Interactive Data File.

Filed herewith as Exhibit 101.

104

Cover Page Interactive Data File.

Formatted as Inline XBRL and contained in Exhibit 101.

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

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SIGNATURE

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


						EQT CORPORATION
						(Registrant)


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

Date: October 26, 2023

Exhibit 10.02(a)

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

October 3, 2023

Rice Drilling B LLC

625 Liberty Avenue, Suite 1700

Pittsburgh, Pa 15222-3111

Attn: J.E.B. Bolen

RE: Letter Agreement – [***]

Dear Mr. Bolen:

Reference is made to that certain Gas Gathering and Compression Agreement dated as of February 26, 2020 by and among EQT Corporation, EQT Production Company, Rice Drilling B LLC and EQT Energy, LLC (collectively, “Producer”), and EQM Gathering Opco, LLC (“Gatherer”), as the same was amended by that certain First Amendment to Gas Gathering and Compression Agreement dated August 26, 2020, that Second Amendment to Gas Gathering and Compression Agreement dated December 6, 2021 and that Third Amendment to Gas Gathering Compression Agreement dated December 21, 2021 and that Fourth Amendment to Gas Gathering Compression Agreement dated January 23, 2023 between Producer and Gatherer (as amended, the “Gathering Agreement”). All capitalized terms used but not otherwise defined in this letter agreement (“Letter Agreement”) shall have the meanings (if any) ascribed to them in the Gathering Agreement.

WHEREAS, the Producer’s Well Pad known as the [***] Well Pad, which is or will be connected to a Receipt Point located on the [***] System AMI and depicted on Exhibit A attached hereto (“[***] Well Pad”), has an Anticipated Production Date of [***] based on the applicable Additional Confirmation Notice;

WHEREAS, Producer has requested that Gatherer commence receiving Dedicated Gas into the Gathering System at the [***] Well Pad (“[***] Receipt Point”) as of [***] or such earlier date as the Parties mutually agree in writing (including email) (“Requested Service Date”); and

WHEREAS, Gatherer is willing to commence receiving Dedicated Gas at the [***] Receipt Point from and after the Requested Service Date, subject to the terms and conditions hereof.

NOW, THEREFORE, Gatherer and Producer (collectively, “Parties” and each a “Party”), by execution of this Letter Agreement and in consideration of the mutual covenants contained herein, do hereby agree as follows:

1. Service Commencement; [***] Shut-In Period. Subject to the terms and conditions of this Letter Agreement:

(a)Gatherer agrees to begin accepting Dedicated Gas into the Gathering System at the [***] Receipt Point on the Requested Service Date, and Producer’s and Gatherer’s rights, remedies and obligations with respect to the delivery and receipt of Dedicated Gas shall apply to Dedicated Gas delivered at the [***] Receipt Point following the Requested Service Date;

(b)Producer agrees to shut-in production of Dedicated Gas from its Well Pads known as the [***] (each a “[***] Receipt Point” and collectively, the “[***] Receipt Points”) during the period commencing on or before the Requested Service Date and continuing until the earlier of (i) Gatherer’s completion of the installation work described in clause (c) below and (ii) [***] (the “[***] Shut-In Period”). For the avoidance of doubt, Producer acknowledges and agrees that the shut-in of the [***] Receipt Points during the [***] Shut-In Period is intended to prevent [***] in the Gathering System and does not represent a failure by Gatherer to receive Dedicated Gas at the [***] Receipt Points which could result in a Temporary Release as contemplated in Section 3.8 of the Gathering Agreement;

(c)Gatherer agrees to complete the installation of (i) pad-level dehydration facilities upstream of each [***] Receipt Point and (ii) a heater at the [***] Well Pad, which facilities and installation shall be completed, in each case, to applicable industry standards and not later than [***];

(d)Producer agrees that Dedicated Gas delivered to the [***] Receipt Point during the [***] Shut-In Period shall maintain a minimum temperature of [***];

(e)Notwithstanding anything herein to the contrary, this Letter Agreement shall not amend or otherwise modify the obligations of the Parties with respect to the connection of any future Receipt Points to the Gathering System under the Gathering Agreement and the other terms and conditions thereof.

2. Miscellaneous. The terms and provisions of this Letter Agreement shall be binding on, and shall inure to the benefit of, the Parties and their respective successors and permitted assigns. This Letter Agreement may be executed in any number of counterparts, and each such counterpart hereof shall be deemed to be an original instrument, but all of such counterparts shall constitute for all purposes one agreement. Any signature hereto delivered by a Party by facsimile or other electronic transmission (including scanned documents delivered by email) shall be deemed an original signature hereto, and execution and delivery by such means shall be binding upon the Parties.

3. Effect of Letter Agreement. The Parties acknowledge and agree that this Letter Agreement constitutes a written instrument executed by the Parties and fulfills the requirements of an amendment contemplated by Section 18.7 of the Gathering Agreement. The Parties hereby ratify and confirm the Gathering Agreement, as amended hereby. Except as expressly provided herein, the provisions of the Gathering Agreement shall remain in full force and effect in accordance with their respective terms following the execution of this Letter Agreement. In the event of any conflict or inconsistencies between this Letter Agreement and the Gathering Agreement, the terms and conditions of this Letter Agreement shall prevail.

4. Governing Law; Jury Waiver. This Letter Agreement shall be governed by, construed, and enforced in accordance with the laws of the Commonwealth of Pennsylvania without regard to choice of law principles. The Parties agree that the appropriate, exclusive and convenient forum for any disputes among any of the Parties arising out of this Letter Agreement or the transactions contemplated hereby shall be in any state or federal court in the City of Pittsburgh and County of Allegheny, Pennsylvania, and each of the Parties irrevocably submits to the jurisdiction of such courts solely in respect of any proceeding arising out of or related to this Letter Agreement. The Parties further agree that the Parties shall not bring suit with respect to any disputes arising out of this Letter Agreement or the transactions contemplated hereby in any court or jurisdiction other than the above specified courts. EACH PARTY HEREBY WAIVES ITS RIGHT TO TRIAL BY JURY IN ANY PROCEEDING ARISING OUT OF OR RELATING TO THIS LETTER AGREEMENT, WHETHER SOUNDING IN CONTRACT, TORT OR OTHERWISE.

[SIGNATURE PAGE FOLLOWS]

IN WITNESS WHEREOF, the Parties have executed this Letter Agreement as of the date first written above.

GATHERER:

EQM GATHERING OPCO, LLC,

a Delaware limited liability company

By: /s/ John M. Quinn

Name: John M. Quinn

Title: _VP Business Development & Commercial Services

PRODUCER:

EQT CORPORATION,

a Pennsylvania corporation

By: /s/ Jeremy Knop

Name: Jeremy Knop

Title: Chief Financial Officer

EQT PRODUCTION COMPANY,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Vice President Operations Planning

RICE DRILLING B LLC,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Vice President Operations Planning

EQT ENERGY, LLC,

a Delaware limited liability company

By: /s/ Keith Shoemaker

Name: Keith Shoemaker

Title: SVP Commercial

EXHIBIT A

[***] System AMI

[***]

Exhibit 10.02(b)

FIFTH AMENDMENT TO

GAS GATHERING AND COMPRESSION AGREEMENT

THIS FIFTH AMENDMENT TO GAS GATHERING AGREEMENT AND COMPRESSION AGREEMENT (this “Amendment”), dated October 4, 2023 (“Effective Date”), is made and entered into by and among EQT Corporation, EQT Production Company, Rice Drilling B LLC, and EQT Energy, LLC (collectively, “Producer”), and EQM Gathering Opco, LLC (“Gatherer”) (as amended, the “Gathering Agreement”). Producer and Gatherer may be referred to herein individually as a “Party” or collectively as the “Parties.”

1.RECITALS

WHEREAS, the Parties entered into that certain Gas Gathering and Compression Agreement dated as of February 26, 2020, as amended by that certain First Amendment to Gas Gathering and Compression Agreement among the Parties dated August 26, 2020, that certain Second Amendment to Gas Gathering and Compression Agreement among the Parties dated December 6, 2021, that certain Third Amendment to Gas Gathering and Compression Agreement among the Parties dated December 21, 2021 and that certain Fourth Amendment to Gas Gathering and Compression Agreement among the Parties dated January 23, 2023 (the “Gathering Agreement”); and

WHEREAS, the Parties desire to amend the Gathering Agreement in accordance with the terms and conditions set forth in this Amendment and in connection with that certain Letter Agreement re: Fuel Gas by and among the Parties and Equitrans, L.P., dated as of the date hereof (the “Letter Agreement”).

NOW, THEREFORE, in consideration of the mutual covenants set forth herein and in the Letter Agreement, and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Parties hereby agree as follows:

2.AGREEMENT

1.Defined Terms. Defined terms used but not defined herein shall have the meanings given to such terms in the Gathering Agreement.

2.New Definitions. The following definitions are added to Article I of the Gathering Agreement:

“Capital Costs” – means, with respect to Transitional Work Costs approved pursuant to the terms hereof and properly invoiced to Produced hereunder, an amount equal to (i) such Transitional Work Costs multiplied by (ii) [***].

“Mining Operations” – means surface or subsurface activity necessary to operate a coal mine and/or extract coal, including development mining, long wall mining, surface mining, coal processing, pre-mining and post-mining removal of methane from coal or surrounding coal strata, drilling exploration holes and gob vent boreholes, and installing or operating portals, shafts, fans, other surface structures, pipelines, power lines, water lines, pumps and compressors and all operations, ground control, subsidence and/or subsidence control measures reasonably related to or arising from the foregoing.

“Mining Operator” – means any Third Party operator, owner or controller that conducts Mining Operations, including without limitation, [***].

“Mining Period” – means the duration of Planned Mining Operations.

“Planned Mining Operations” – means any and all present or future Mining Operations which are planned to be conducted in the vicinity of a portion of the Gathering System by a Mining Operator which would reasonably be expected to require Gatherer to (i) interrupt or curtail Services during the Mining Period and/or (ii) perform Transitional Work and incur expense in order to ensure the continued safe operation of such portion of the Gathering System during the Mining Period, as indicated by Gatherer in a written Work Notice.

“Returned Revenues” – means, with respect to a Planned Mining Operation that would in the absence of the performance of the Transitional Work proposed by Gatherer in the applicable Work Notice require the curtailment of any portion of the Gathering System, the [***]. To the extent the Work Notice includes multiple longwall panels or sections (as reasonably defined by the Mining Operator), Returned Revenues shall be calculated in a manner such that they are not double counted.

“Transitional Work” – As defined in Section 7.5(b).

“Transitional Work Costs” – means the third party out-of-pocket costs that Gatherer incurs in order to perform the Transitional Work impacted by the Planned Mining Operations during the Mining Period. To the extent the Work Notice includes multiple longwall panels or sections (as reasonably defined by the Mining Operator), Transactional Work Costs shall be calculated in a manner such that they are not double counted.

“Work Rejection” – As defined in Section 7.5(b).

“Work Notice” – As defined in Section 7.5(a).

3.Temporary Release. The first parenthetical in the first sentence of Section 3.8 of the Gathering Agreement is hereby deleted in its entirety and replaced with the following:

“(other than those caused or contributed to by (a) the actions or inactions of any member of the Producer Group resulting in Gatherer being unable to accept or deliver Gas or comply with the terms hereof, (b) any event of Force Majeure declared by Producer, (c) Maintenance (except to the extent such Maintenance results in a Maintenance Deficiency), (d) the breach of this Agreement by any member of Producer Group or (e) a Work Rejection in connection with Planned Mining Operations)”

4.Permanent Release. The first parenthetical in the first sentence of Section 3.9(a) of the Gathering Agreement is hereby deleted in its entirety and replaced with the following:

“(other than those caused or contributed to by (i) the actions or inactions of any member of the Producer Group resulting in Gatherer being unable to accept or deliver Gas or comply with the terms hereof, (ii) an event of Force Majeure, (iii) Maintenance, (iv) the breach of this Agreement by any member of Producer Group or (v) a Work Rejection in connection with Planned Mining Operations)”

5.Planned Mining Operations. Section 7.5 is added to the Gathering Agreement to read as follows:

“Section 7.5 Planned Mining Operations. The following process shall apply in the event of Planned Mining Operations:

(a)Gatherer shall provide Producer with written notice (“Work Notice”) of the anticipated commencement of Planned Mining Operations not later than the later of (i) [***] ([***]) following the delivery to Gatherer of a notice thereof from a Mining Operator (including any updates to prior notices), and (ii) at least [***] ([***]) prior to the anticipated commencement of a Mining Period. Each Work Notice shall set forth the estimated duration of the Mining Period, the mine section (as reasonably defined by the Mining Operator) in which the Planned Mining Operations are located, and the portions of the Gathering System affected thereby and describe (i) the work, including without limitation exposing, bracing, shutting in and/or relocating such portion of the Gathering System, as applicable, that would be required for Gatherer to ensure the continued operation of the affected portion of the Gathering System during the Mining Period (“Transitional Work”), (ii) the Transitional Work Costs associated therewith, and (iii) the Returned Revenues associated therewith. A Work Notice with respect to the Planned Mining Operations of [***] described on Schedule A to this Amendment shall be deemed to have been timely delivered, and Producer shall have elected to approve the Transitional Work proposed by Gatherer therein.

(b)If Gatherer delivers the Work Notice in accordance with Section 7.5(a), Producer may, within [***] of receiving such Work Notice, by written notice to Gatherer, elect to approve or reject the Transitional Work proposed by Gatherer therein. In the event that Producer elects to reject the proposal set forth in such Work Notice (or does not approve the proposal within such [***] period) (a “Work Rejection”), then Gatherer shall (i) have no obligation to perform the Transitional Work, and (ii) shall be permitted to interrupt or curtail Service during the Mining Period with respect to the portions of the Gathering System described as affected in the Work Notice to the extent such interruption or curtailment is a result of the Mining Operations, free and clear of any claim of a reduction in the Minimum Volume Commitment, permanent release or other remedy hereunder; provided, however, that Producer may elect to treat the Dedicated Gas subject to such curtailment as Temporarily Released for the duration of the applicable Mining Period.

(c)If Producer approves the Transitional Work, Gatherer will complete the Transitional Work prior to the commencement of the Mining Period at Gatherer’s sole cost and expense, subject to the terms of this Section 7.5(d). Following the expiration of the applicable Mining Period and Gatherer’s determination of the actual Transitional Work Costs, Gatherer shall notify Producer in writing of the actual, reasonable and documented Transitional Work Costs (with reasonable supporting documentation thereof), and (i) if the Returned Revenues are equal to or greater than the actual Transitional Work Costs, Producer shall have no further obligation with respect thereto, or (ii) if the Returned Revenues are less than the actual Transitional Work Costs, Gatherer shall, in addition to and delivered contemporaneously with the following Month’s invoice for fees delivered pursuant to Section 13.1, send a separate invoice to Producer setting forth such actual, reasonable and documented Transitional Works Costs and the associated Capital Costs, and Producer shall reimburse Gatherer for all such invoiced Transitional Work Costs, plus the associated Capital Costs. The terms of Section 13.1, 13.2, 13.3, 13.4 and 13.5 shall, for the avoidance of doubt, apply to all Transitional Work Costs included on any invoices. Notwithstanding anything herein to the contrary, in the event that the information included in a Work Notice is materially changed by the Mining Operator after the delivery by Gatherer of the initial Work Notice and prior to the commencement of the applicable Mining Period, Gatherer shall propose to Producer an updated Work Notice under Section 7.5(a).

(d)The Gatherer and Producer agree to coordinate their activities and otherwise cooperate in good faith to minimize, where practical, the incurrence of any additional expense or the loss of revenues by the other in effectuating the curtailment of Services attributable to Planned Mining Operations. Subject to the other terms of this Agreement, the Parties acknowledge and agree that, to the extent that any curtailment is attributable to Planned Mining Operations, such curtailment shall not constitute a breach of any Gatherer obligations set forth in this Agreement.

(e)The Parties hereby acknowledge and agree that in the event that (i) Gatherer (A) fails to timely deliver a Work Notice or (B) fails to perform the Transitional Work set forth in a Work Notice to the extent that Producer elects to approve the Transitional Work, then, in each case, any resulting failure or inability of Gatherer to receive all Gas up to the MDQ that is tendered to Gatherer (or that would have been tendered, but for such curtailment) shall be subject to the terms and conditions of Section 3.8, and shall not be deemed to be caused by Maintenance; and (ii) Gatherer performs the Transitional Work set forth in a Work Notice but such Transitional Work fails to mitigate the curtailment required by the Mining Operations, then any resulting failure or inability of Gatherer to receive all Gas up to the MDQ that is tendered to Gatherer (or that would have been tendered, but for such curtailment) shall be deemed to be caused by Maintenance, and Producer’s remedies shall be limited accordingly, until such time as a Maintenance Deficiency accrues pursuant to the terms hereof.

6.Incremental Compression Fee. All Dedicated Gas delivered from the Gathering System to the Taurus Equitrans Delivery Point shall be subject to an [***] and calculated in accordance with Section 5.1(d)(i) of the Gathering Agreement.

7.Force Majeure. The first sentence of Section 14.2 of the Gathering Agreement is hereby deleted in its entirety and replaced with the following:

“The term “Force Majeure” as used in this Agreement shall mean, to the extent not reasonably within the control of the Party claiming relief and that, by the exercise of reasonable diligence, such Party is unable to prevent or overcome, any of the following events: acts of God, strikes, lockouts or other industrial disturbances, acts of the public enemy, acts of terror, sabotage, wars, blockades, military action, insurrections, riots, epidemics, landslides, unplanned subsidence, unplanned mining operations, lightning, earthquakes, fires, storms or storm warnings, crevasses, floods, washouts, civil disturbances, explosions, breakage or accident to wells, machinery, equipment or lines of pipe, the necessity for testing or making repairs or alterations to wells, machinery, equipment or lines of pipe, freezing of wells, equipment or lines of pipe, inability of any Party hereto to obtain, after the exercise of reasonable diligence, necessary materials, supplies, rights of way, or government authorizations, any action or restraint by any Governmental Authority (so long as the Party claiming relief has not applied for or assisted in the application for, and has opposed where and to the extent reasonable, such action or restraint, and as long as such action or restraint is not the result of a failure by the claiming Party to comply with applicable laws, rules, regulations, or orders).” Notwithstanding anything in this Agreement to the contrary, for the purposes of Section 3.3(e), Force Majeure shall include Planned Mining Operations to the extent they cause or contribute to delay in providing service on or before the Completion Deadline.

8.Effect. The Parties acknowledge and agree that this Amendment constitutes a written instrument executed by the Parties and fulfills the requirements of an amendment contemplated by Section 18.7 of the Gathering Agreement. The Parties hereby ratify and confirm the Gathering Agreement, as amended hereby. Except as expressly provided herein, the provisions of the Gathering Agreement shall remain in full force and effect in accordance with their respective terms following the execution of this Amendment.

9.Governing Law. This Amendment shall be governed by, construed, and enforced in accordance with the laws of the Commonwealth of Pennsylvania without regard to choice of law principles. The Parties agree that the appropriate, exclusive and convenient forum for any disputes among any of the Parties arising out of this Amendment or the transactions contemplated hereby shall be in any state or federal court in the City of Pittsburgh and County of Allegheny, Pennsylvania, and each of the Parties irrevocably submits to the jurisdiction of such courts solely in respect of any proceeding arising out of or related to this Amendment. The Parties further agree that the Parties shall not bring suit with respect to any disputes arising out of this Amendment or the transactions contemplated hereby in any court or jurisdiction other than the above specified courts. EACH PARTY HEREBY WAIVES ITS RIGHT TO TRIAL BY JURY IN ANY PROCEEDING ARISING OUT OF OR RELATING TO THIS AMENDMENT, WHETHER SOUNDING IN CONTRACT, TORT OR OTHERWISE.

10.Counterpart Execution; Approval. This Amendment may be executed in any number of counterparts, each of which shall be considered an original, and all of which shall be considered one and the same instrument. Execution of this Amendment by Gatherer is subject to the approval from Gatherer’s Board of Directors or that of its parent company or equivalent governance body, of the capital necessary for Gatherer to comply with its obligations set forth herein.

11.Miscellaneous Provisions. The provisions of Article 18 of the Gathering Agreement, other than Sections 18.2, 18.3, 18.15, 18.16 and 18.17, shall apply to this Amendment mutatis mutandis.

[Signature Page Follows]

IN WITNESS WHEREOF, the Parties have executed this Amendment as of the date first written above.

PRODUCER:

EQT CORPORATION,

a Pennsylvania corporation

By: /s/ Jeremy Knop

Name: Jeremy Knop

Title: Chief Financial Officer

EQT PRODUCTION COMPANY,

a Pennsylvania corporation

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Senior Vice President of Operations Planning

RICE DRILLING B LLC,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Senior Vice President of Operations Planning

EQT ENERGY, LLC,

a Delaware limited liability company

By: /s/ Keith Shoemaker

Name: Keith Shoemaker

Title: Senior Vice President, Commercial

[Signature Page to Fifth Amendment to Gas Gathering and Compression Agreement]

GATHERER:

EQM GATHERING OPCO, LLC,

a Delaware limited liability company

By: /s/ John M. Quinn

Name: John M. Quinn

Title: VP Business Development & Commercial Services

[Signature Page to Fifth Amendment to Gas Gathering and Compression Agreement]

Schedule A

Pre-Approved Transitional Work

See Attached information provided to Producer via Work Notice dated September 18, 2023

[***]

Schedule A

Exhibit 10.02(c)

October 5, 2023

Rice Drilling B LLC

625 Liberty Avenue, Suite 1700

Pittsburgh, Pa 15222-3111

Attn: J.E.B. Bolen

RE: Fuel Gas Letter Agreement

Dear Mr. Bolen:

Reference is made to (A) that certain Gathering Agreement for the Hammerhead Gas Gathering System dated February 12, 2018 (as amended, the “Hammerhead Gathering Agreement”) by and between EQT Production Company (“EQT Production”) and EQT Energy, LLC (“EE”) and EQM Gathering Opco, LLC (“Gatherer”), as amended by that certain First Amendment to Gas Gathering Agreement dated June 1, 2019 and that Second Amendment to Gas Gathering Agreement dated April 3, 2020, and (B) that certain Gas Gathering and Compression Agreement dated as of February 26, 2020 by and among EQT Corporation, EQT Production, Rice Drilling B LLC and EE (collectively, “Producer”), and Gatherer, as the same was amended by that certain First Amendment to Gas Gathering and Compression Agreement dated August 26, 2020, that Second Amendment to Gas Gathering and Compression Agreement dated December 6, 2021, that Third Amendment to Gas Gathering Compression Agreement dated December 21, 2021 and that Fourth Amendment to Gas Gathering Compression Agreement dated January 23, 2023 between Producer and Gatherer (as amended, the “Trifecta Gathering Agreement”). All capitalized terms used but not otherwise defined in this letter agreement (“Letter Agreement”) shall have the meanings (if any) ascribed to them in the Hammerhead Gathering Agreement and the Trifecta Gathering Agreement, as applicable.

WHEREAS, Producer has requested that Gatherer commence delivering certain Dedicated Gas to the Delivery Points listed in Exhibit A attached hereto (the “Redelivery Points”, and the Dedicated Gas delivered thereto, “Buyback Gas”) for the purpose of supporting Producer’s hydraulic fracturing operations at the Producer’s Well Pad known as the Teamwork South Pad (“Buyback Gas Well Pad”);

WHEREAS, Producer has requested that Gatherer commence delivering certain Dedicated Gas to the Delivery Point depicted on Exhibit A attached hereto (the “[***] Delivery Point”, and the Dedicated Gas delivered thereto, “[***] Fuel Gas”), via the Hammerhead Gathering System, for the purpose of supporting Producer’s hydraulic fracturing operations at the Producer’s Well Pad known as the [***] Well Pad (“[***] Well Pad”);

WHEREAS, Producer has requested that Gatherer deliver certain Dedicated Gas to the Delivery Points depicted on Exhibit A attached hereto (the “HH Fuel Gas Delivery Points”, and the Dedicated Gas delivered thereto, “HH Fuel Gas”), via the Hammerhead Gathering System, for the purpose of supporting Producer’s hydraulic fracturing operations at the Producer’s Well Pads known as the Heart North Pad and the Radcliff South Pad (each an “HH Fuel Gas Well Pad” and collectively, the “HH Fuel Gas Well Pads”);

WHEREAS, Producer has requested that Equitrans, L.P. (“Equitrans”) deliver Gas sourced from its interstate natural gas transmission and storage pipeline system (“Transmission Fuel Gas” and together with the [***] Fuel Gas and the HH Fuel Gas, “Fuel Gas”) to the Delivery Points depicted on Exhibit A attached hereto (the “Transmission Fuel Gas Delivery Point” and, together with the [***] Delivery Point and the HH Fuel Gas Delivery Points, the “Fuel Gas Delivery Points”) for the purpose of supporting Producer’s hydraulic fracturing operations at the Producer’s Well Pads within the Dedication Area and known as the Carnegie North Pad and the Vanderbilt South Pad (“Transmission Fuel Gas Well Pads”); and

WHEREAS, Gatherer and Equitrans are willing to deliver Buyback Gas to the Redelivery Points and deliver Fuel Gas to the Fuel Gas Delivery Points, as applicable, subject to the terms and conditions hereof.

NOW, THEREFORE, Gatherer, Equitrans and Producer (collectively, “Parties” and each a “Party”), by execution of this Letter Agreement and in consideration of the mutual covenants contained herein, do hereby agree as follows:

1.Buyback Gas.

(a)Following the delivery by Producer to Gatherer of an Additional Confirmation Notice for a Buyback Gas Well Pad, Producer may deliver to Gatherer notice of the date on which Producer requests that buyback service commence at such Buyback Gas Well Pad; provided, however that such date may not be earlier than the “Frac Start Date” for such Buyback Gas Well Pad identified on Exhibit A (each a “Buyback Gas Service Commencement Date”). Beginning on the Buyback Gas Service Commencement Date and continuing thereafter until such time as Producer has completed its hydraulic fracturing operations at the applicable Redelivery Point, Gatherer agrees to make available not less than [***]/day of Buyback Gas for delivery to such Redelivery Point.

(b)Upon the delivery by Producer to Gatherer of an Additional Confirmation Notice for each Buyback Gas Well Pad, Producer shall pay to Gatherer a one-time fee in the amount of [***] Dollars ($[***]), as consideration for Gatherer’s obligation to deliver Buyback Gas to the Redelivery Points in accordance with the terms hereof (“Buyback Gas Fee”).

(c)In the event that Gatherer does not timely commence delivering the volumes of Buyback Gas to a Redelivery Point on or before the applicable Buyback Gas Service Commencement Date for a reason other than Force Majeure or the fault of Producer, then (i) if Gatherer commences delivering Buyback Gas to such Redelivery Point pursuant to the terms hereof within [***] ([***]) , Gatherer shall be obligated to repay a portion of the Buyback Gas Fee applicable thereto to Producer in an amount equal to the product of $[***] and the number of [***] between the (A) applicable Buyback Gas Service Commencement Date and (B) the date on which Gatherer has commenced delivering Buyback Gas to such Redelivery Point, and (ii) except as otherwise provided in this Agreement, if Gatherer does not commence delivering Buyback Gas to such Redelivery Point pursuant to the terms hereof within [***], Gatherer shall be obligated to repay [***] percent ([***]%) of the Buyback Gas Fee applicable thereto to Producer. Gatherer agrees to repay all or such applicable portions of the Buyback Gas Fee within [***] after such obligation accrues.

2.[***] Fuel Gas.

(a)During the period commencing upon April 7, 2023 and continuing thereafter until such time as Producer has completed its hydraulic fracturing operations at the [***] Well Pad, Gatherer agrees to make available not less than [***]/day of [***] Fuel Gas received into the Trifecta Gathering System for delivery to the [***] Delivery Point via the Hammerhead Gathering System. The Parties acknowledge and agree that such [***] Fuel Gas shall be received into the Hammerhead Gathering System at the Throckmorton Receipt Point (“Throckmorton Receipt Point”) and delivered to the [***] Delivery Point.

(b)In addition to the Overrun Fee or any other fees payable under the Trifecta Gathering Agreement with respect to [***] Fuel Gas, Producer agrees to pay Gatherer a Fee equal to $[***] per dth for all [***] Fuel Gas volumes flowing to the [***] Delivery Point hereunder (“HH Fee”), which HH Fee shall be invoiced under the Hammerhead Gathering Agreement

(c)All [***] Fuel Gas volumes flowing to the [***] Delivery Point hereunder shall be [***].

3.HH Fuel Gas.

(a)Producer may deliver to Gatherer at any time notice of the date on which Producer requests fuel gas service commence at each HH Fuel Gas Well Pad; provided, however, that such date shall not be earlier than the “Frac Start Date” for such HH Fuel Gas Well Pad identified on Exhibit A (each, “HH Fuel Gas Service Commencement Date”). Beginning on the HH Fuel Gas Service Commencement Date and continuing thereafter until such time as Producer has completed its hydraulic fracturing operations, Gatherer agrees to make available not less than [***]/day of HH Fuel Gas for delivery to the applicable HH Fuel Gas Delivery Point.

(b)Upon the delivery by Producer to Gatherer of an Additional Confirmation Notice for each HH Fuel Gas Well Pad, Producer shall pay to Gatherer a one-time fee in the amount of [***] Dollars ($[***]), as consideration for Gatherer’s obligation to deliver HH Fuel Gas to such HH Fuel Gas Delivery Point (“HH Fuel Gas Delivery Fee”).

(c)In the event that Gatherer does not timely commence delivering the volumes of HH Fuel Gas to an HH Fuel Gas Delivery Point on or before the applicable HH Fuel Gas Service Commencement Date for a reason other than Force Majeure or the fault of Producer, then (i) if Gatherer commences delivering HH Fuel Gas to such HH Fuel Gas Delivery Point pursuant to the terms hereof within [***], Gatherer shall be obligated to repay a portion of the HH Fuel Gas Delivery Fee applicable thereto to Producer in an amount equal to the product of $[***] and the number of [***] between the (A) applicable HH Fuel Gas Service Commencement Date and (B) the date on which Gatherer has commenced delivering HH Fuel Gas to such HH Fuel Gas Delivery Point, and (ii) except as otherwise provided in this Agreement, if Gatherer does not commence delivering HH Fuel Gas to such HH Fuel Gas Delivery Point pursuant to the terms hereof with [***], Gatherer shall be obligated to repay [***] percent ([***]%) of the HH Fuel Gas Delivery Fee applicable thereto to Producer. Gatherer agrees to repay all or such applicable portions of the HH Fuel Gas Delivery Fee within [***] after such obligation accrues.

4.Transmission Fuel Gas.

(a) Producer may deliver to Gatherer at any time notice of the date on which Producer requests fuel gas service commence at each Transmission Fuel Gas Well Pad; provided, however, that such date shall not be earlier than the “Frac Start Date” for such Transmission Fuel Gas Well Pad identified on Exhibit A (each, a “Transmission Fuel Gas Service Commencement Date”). Beginning on the Transmission Fuel Gas Service Commencement Date, Equitrans agrees to make available not less than [***]/day of Transmission Fuel Gas for delivery to the applicable Transmission Fuel Gas Delivery Point during the period commencing upon the Transmission Fuel Gas Service Commencement Date and continuing thereafter until such time as Producer has completed its hydraulic fracturing operations.

(b)Upon the delivery by Producer to Gatherer of an Additional Confirmation Notice for each Transmission Fuel Gas Well Pad, Producer shall pay to Equitrans a one-time fee in the amount of [***] Dollars ($[***]), as consideration for Equitrans’ obligation to deliver Transmission Fuel Gas to such Transmission Fuel Gas Delivery Point (“Transmission Fuel Gas Delivery Fee”).

(c)In the event that Equitrans does not timely commence delivering the volumes of Transmission Fuel Gas to a Transmission Fuel Gas Delivery Point on or before the applicable Transmission Fuel Gas Service Commencement Date for a reason other than Force Majeure or the fault of Producer, then (i) if Equitrans commences delivering Transmission Fuel Gas to such Transmission Fuel Gas Delivery Point pursuant to the terms hereof within [***], Equitrans shall be obligated to repay a portion of the Transmission Fuel Gas Delivery Fee applicable thereto to Producer in an amount equal to the product of $[***] and the number of [***] between the (i) applicable Transmission Fuel Gas Service Commencement Date and (ii) the date on which Gatherer has commenced delivering Transmission Fuel Gas to such Transmission Fuel Gas Delivery Point, and (ii) except as otherwise provided in this Agreement, if Equitrans does not commence delivering Transmission Fuel Gas to such Transmission Fuel Gas Delivery Point pursuant to the terms hereof with [***], Equitrans shall be obligated to repay [***] percent ([***]%) of the Transmission Fuel Gas Delivery Fee applicable thereto to Producer. Gatherer agrees to repay all or such applicable portions of the Transmission Fuel Gas Delivery Fee within [***] ([***]) Days after such obligation accrues.

(d)The Transmission Fuel Gas shall be delivered to the Transmission Fuel Gas Delivery Points under and subject to an ITS Transportation Services Agreement (“ITS Agreement”) in the form attached hereto as Exhibit B. Producer and Equitrans will enter into the ITS Agreement contemporaneously with this Letter Agreement.

5.Additional Covenants.

(a)Producer shall be obligated to construct and install a temporary fuel line and any necessary appurtenant facilities extending from Gatherer’s facilities at each Fuel Gas Delivery Point to the applicable Well Pad, consistent with Gatherer’s reasonable and customary operational standards and requirements.

(b)All of the obligations of Producer and Gatherer hereunder shall be performed in compliance with the performance standard set forth in Section 3.1 of the Trifecta Gathering Agreement.

(c)Producer shall provide to Gatherer daily custody measurement data on a weekly basis confirming volumes of Fuel Gas delivered to each Fuel Gas Delivery Point.

(d)Notwithstanding anything herein to the contrary, this Letter Agreement shall not amend or otherwise modify the obligations of the Parties with respect to the connection of any future Redelivery Points to the Gathering System under Section 3.10 of the Gathering Agreement and the other terms and conditions thereof.

6.Indemnification.

(a)Subject to the terms of this Letter Agreement, including Section 6(c), Gatherer shall release, indemnify, defend, and hold harmless Producer and its Affiliates, directors, officers, employees, agents, consultants, representatives, and invitees from and against all claims and losses arising out of or relating to (i) the operations of Gatherer or its Affiliates under this Letter Agreement and (ii) any breach of this Letter Agreement by Gatherer.

(b)Subject to the terms of this Letter Agreement, including Section 6(c), Producer shall release, indemnify, defend, and hold harmless Gatherer and its Affiliates, directors, officers, employees, agents, consultants, representatives, and invitees from and against all claims and losses arising out of or relating to (i) the operations of Producer and its Affiliates under this Letter Agreement, and (ii) any breach of this Letter Agreement by Producer.

(c)NOTWITHSTANDING ANYTHING IN THIS LETTER AGREEMENT TO THE CONTRARY, NEITHER PARTY SHALL BE LIABLE TO THE OTHER PARTY FOR SPECIAL, INDIRECT, CONSEQUENTIAL, PUNITIVE OR EXEMPLARY DAMAGES SUFFERED BY SUCH PARTY RESULTING FROM OR ARISING OUT OF THIS LETTER AGREEMENT OR THE BREACH THEREOF OR UNDER ANY OTHER THEORY OF LIABILITY, WHETHER TORT, NEGLIGENCE, STRICT LIABILITY, BREACH OF CONTRACT, WARRANTY, INDEMNITY OR OTHERWISE, INCLUDING LOSS OF USE, INCREASED COST OF OPERATIONS, LOSS OF PROFIT OR REVENUE, OR BUSINESS INTERRUPTIONS; PROVIDED, HOWEVER, THAT THE FOREGOING LIMITATION SHALL NOT APPLY TO ANY (a) ACTUAL AMOUNT OF FEES TO BE PAID PURSUANT TO THE TERMS HEREOF, OR (b) DAMAGE OR CLAIM ASSERTED BY OR AWARDED TO A THIRD PARTY FOR WHICH A PARTY WOULD OTHERWISE BE LIABLE UNDER ANY INDEMNIFICATION PROVISION SET FORTH HEREIN.

6. Trifecta Fifth Amendment. In consideration for the agreement of Gatherer and Equitrans to deliver Buyback Gas to the Redelivery Point and deliver Fuel Gas to the Fuel Gas Delivery Points in accordance with the terms and conditions hereof, the Parties shall, simultaneously with the execution of this Letter Agreement, enter into that certain Fifth Amendment to the Trifecta Gathering Agreement attached hereto as Exhibit C (the “Fifth Amendment”), which Fifth Amendment shall, among other things, set forth provisions governing over the rights and obligations of Gatherer and Producer in the event of planned mining operations in the vicinity of the Gathering System.

7. Miscellaneous. The terms and provisions of this Letter Agreement shall be binding on, and shall inure to the benefit of, the Parties and their respective successors and permitted assigns. This Letter Agreement may be executed in any number of counterparts, and each such counterpart hereof shall be deemed to be an original instrument, but all of such counterparts shall constitute for all purposes one agreement. Any signature hereto delivered by a Party by facsimile or other electronic transmission (including scanned documents delivered by email) shall be deemed an original signature hereto, and execution and delivery by such means shall be binding upon the Parties.

8. Effect of Letter Agreement. The Parties acknowledge and agree that this Letter Agreement constitutes a written instrument executed by the Parties and fulfills the requirements of an amendment contemplated by (a) Section 17.8 of the Hammerhead Gathering Agreement, and (b) Section 18.7 of the Trifecta Gathering Agreement; provided, however, that except as expressly provided herein, the Parties hereby reserve all of their rights and remedies under the Trifecta Gathering Agreement and the Hammerhead Gathering Agreement, and under applicable law and nothing herein will constitute a waiver, release, modification or alteration of the terms, conditions or covenants of the Trifecta Gathering Agreement and the Hammerhead Gathering Agreement, the provisions of which are intended to remain in full force and effect in accordance with their respective terms, except to the extent expressly contemplated hereby. In the event of any conflict or inconsistencies between this Letter Agreement, the Trifecta Gathering Agreement and the Hammerhead Gathering Agreement, the terms and conditions of this Letter Agreement shall prevail.

9. Governing Law; Jury Waiver. This Letter Agreement shall be governed by, construed, and enforced in accordance with the laws of the Commonwealth of Pennsylvania without regard to choice of law principles. The Parties agree that the appropriate, exclusive and convenient forum for any disputes among any of the Parties arising out of this Letter Agreement or the transactions contemplated hereby shall be in any state or federal court in the City of Pittsburgh and County of Allegheny, Pennsylvania, and each of the Parties irrevocably submits to the jurisdiction of such courts solely in respect of any proceeding arising out of or related to this Letter Agreement. The Parties further agree that the Parties shall not bring suit with respect to any disputes arising out of this Letter Agreement or the transactions contemplated hereby in any court or jurisdiction other than the above specified courts. EACH PARTY HEREBY WAIVES ITS RIGHT TO TRIAL BY JURY IN ANY PROCEEDING ARISING OUT OF OR RELATING TO THIS LETTER AGREEMENT, WHETHER SOUNDING IN CONTRACT, TORT OR OTHERWISE.

[SIGNATURE PAGE FOLLOWS]

IN WITNESS WHEREOF, the Parties have executed this Letter Agreement as of the date first written above.

GATHERER:

EQM GATHERING OPCO, LLC,

a Delaware limited liability company

By: /s/ John M. Quinn

Name: John M. Quinn

Title: VP Business Development & Commercial Services

EQUITRANS, L.P.,

a Pennsylvania limited partnership

By: Equitrans Services, LLC, its general partner

By: Equitrans Investments, LLC, its member

By: EQM Midstream Partners, LP, its sole member

By: EQGP Services, LLC, its general partner

By: /s/ John M. Quinn

Name: John M. Quinn

Title: VP Business Development & Commercial Services

PRODUCER:

RICE DRILLING B LLC,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Senior Vice President of Operations Planning

EQT CORPORATION,

a Pennsylvania corporation

By: /s/ Jeremy Knop

Name: Jeremy Knop

Title: Chief Financial Officer

EQT ENERGY, LLC,

a Delaware limited liability company

By:/s/ Keith Shoemaker

Name: Keith Shoemaker

Title: Senior Vice President, Commercial

EQT PRODUCTION COMPANY,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Senior Vice President of Operations Planning

EXHIBIT A

Redelivery Points; Fuel Gas Delivery Points


Well Pad	Category	Frac Start Date
[***]	[***] Fuel Gas Well Pad	[***]
Heart North	HH Fuel Gas Well Pad	[***]
Radcliff South	HH Fuel Gas Well Pad	[***]
Teamwork South	Buyback Gas Well Pad	[***]
Carnegie North	Transmission Fuel Gas Well Pads	[***]
Vanderbilt South	Transmission Fuel Gas Well Pads	[***]

EXHIBIT B

ITS Agreement

[See Attached]

OPTIONAL EXHIBIT B

to the

TRANSPORTATION SERVICE AGREEMENT

between EQUITRANS, L.P.

and

EQT Energy, LLC, pursuant to Rate Schedule ITS

Contract No. 1832 Dated 8/12/21

Date of this Optional Exhibit B: 10/5/23

Effective Date of this Optional Exhibit B: 7/1/24

Supersedes Optional Exhibit B Dated:

Discounted Rate Agreement

1.In accordance with Section 6.25 of the General Terms and Conditions of Equitrans’ Tariff, Equitrans and Customer agree that the following discounted rates and any discount terms will apply under the Agreement:

The rates for service to be paid by Customer to Equitrans to the Delivery Points of Carnegie North (Meter # FR-TRNS-ML) or Vanderbilt South (Meter # FR-TRNS-ML) shall be:

Usage Charge: [***]

Customer shall pay all applicable surcharges, including FERC ACA surcharge.

Except as expressly stated herein, Equitrans’ applicable maximum rates and charges set forth in the Statement of Rates of its Tariff continue to apply.

2.This Exhibit B is effective 7/1/24 and continues in effect through 12/31/25.

3.All rates and services described in the Agreement and this Exhibit B are subject to the terms and conditions of Equitrans’ Tariff. If one rate component which was at or below the applicable maximum rate at the time the discount agreement was executed subsequently exceeds the applicable maximum rate or is less than the applicable minimum rate due to a change in Equitrans’ maximum (minimum) rates so that such rate component must be adjusted downward (upward) to equal the new applicable maximum (minimum) rate, the other rate components may be adjusted upward (downward) to

achieve the agreed overall rate, so long as none of the resulting rate components exceed the maximum rate or are less than the minimum rate applicable to that rate component. Such changes to rate components shall be applied prospectively, commencing with the date a Commission order accepts revised tariff sections. Nothing contained herein shall be construed to alter a refund obligation under applicable law for any period during which rates which had been charged under a discount agreement exceeded rates which ultimately are found to be just and reasonable.

4.In the event any provision of this Exhibit B is held to be invalid, illegal or unenforceable by any court, regulatory agency, or tribunal of competent jurisdiction, the validity, legality, and enforceability of the remaining provisions, terms or conditions shall not in any way be affected or impaired thereby, and the term, condition, or provision which is held illegal or invalid shall be deemed modified to conform to such rule of law, but only for the period of time such order, rule, regulation, or law is in effect.

5.Other Special Provisions:

None.

IN WITNESS WHEREOF, Customer and Equitrans have executed this Exhibit B by their duly authorized officers, effective as of the date indicated above.


CUSTOMER:			EQUITRANS, L.P.:
By

(Date) Keith Shoemaker			(Date) John M. Quinn
Title: Senior Vice President, Commercial			Title Vice President, Business Development and Commercial Services

EXHIBIT C

Fifth Amendment to Gas Gathering and Compression Agreement

[See Attached]

FIFTH AMENDMENT TO

GAS GATHERING AND COMPRESSION AGREEMENT

1.RECITALS

2.AGREEMENT

1.Defined Terms. Defined terms used but not defined herein shall have the meanings given to such terms in the Gathering Agreement.

2.New Definitions. The following definitions are added to Article I of the Gathering Agreement:

“Mining Operator” – means any Third Party operator, owner or controller that conducts Mining Operations, including without limitation, [***].

“Mining Period” – means the duration of Planned Mining Operations.

“Transitional Work” – As defined in Section 7.5(b).

“Work Rejection” – As defined in Section 7.5(b).

“Work Notice” – As defined in Section 7.5(a).

3.Temporary Release. The first parenthetical in the first sentence of Section 3.8 of the Gathering Agreement is hereby deleted in its entirety and replaced with the following:

4.Permanent Release. The first parenthetical in the first sentence of Section 3.9(a) of the Gathering Agreement is hereby deleted in its entirety and replaced with the following:

5.Planned Mining Operations. Section 7.5 is added to the Gathering Agreement to read as follows:

“Section 7.5 Planned Mining Operations. The following process shall apply in the event of Planned Mining Operations:

(a)Gatherer shall provide Producer with written notice (“Work Notice”) of the anticipated commencement of Planned Mining Operations not later than the later of (i) [***] ([***])following the delivery to Gatherer of a notice thereof from a Mining Operator (including any updates to prior notices), and (ii) at least [***] ([***]) prior to the anticipated commencement of a Mining Period. Each Work Notice shall set forth the estimated duration of the Mining Period, the mine section (as reasonably defined by the Mining Operator) in which the Planned Mining Operations are located, and the portions of the Gathering System affected thereby and describe (i) the work, including without limitation exposing, bracing, shutting in and/or relocating such portion of the Gathering System, as applicable, that would be required for Gatherer to ensure the continued operation of the affected portion of the Gathering System during the Mining Period (“Transitional Work”), (ii) the Transitional Work Costs associated therewith, and (iii) the Returned Revenues associated therewith. A Work Notice with respect to the Planned Mining Operations of [***] described on Schedule A to this Amendment shall be deemed to have been timely delivered, and Producer shall have elected to approve the Transitional Work proposed by Gatherer therein.

7.Force Majeure. The first sentence of Section 14.2 of the Gathering Agreement is hereby deleted in its entirety and replaced with the following:

11.Miscellaneous Provisions. The provisions of Article 18 of the Gathering Agreement, other than Sections 18.2, 18.3, 18.15, 18.16 and 18.17, shall apply to this Amendment mutatis mutandis.

[Signature Page Follows]

IN WITNESS WHEREOF, the Parties have executed this Amendment as of the date first written above.

PRODUCER:

EQT CORPORATION,

a Pennsylvania corporation

By:

Name: Jeremy Knop

Title: Chief Financial Officer

EQT PRODUCTION COMPANY,

a Pennsylvania corporation

By:

Name: J.E.B. Bolen

Title: Senior Vice President of Operations Planning

RICE DRILLING B LLC,

a Delaware limited liability company

By:

Name: J.E.B. Bolen

Title: Senior Vice President of Operations Planning

EQT ENERGY, LLC,

a Delaware limited liability company

By:

Name: Keith Shoemaker

Title: Senior Vice President, Commercial

[Signature Page to Fifth Amendment to Gas Gathering and Compression Agreement]

GATHERER:

EQM GATHERING OPCO, LLC,

a Delaware limited liability company

By:

Name: John M. Quinn

Title: VP Business Development & Commercial Services

[Signature Page to Fifth Amendment to Gas Gathering and Compression Agreement]

Schedule A

Pre-Approved Transitional Work

See Attached information provided to Producer via Work Notice dated September 18, 2023

[***]

Exhibit 10.02(d)

October 12, 2023

Rice Drilling B LLC

625 Liberty Avenue, Suite 1700

Pittsburgh, Pa 15222-3111

Attn: J.E.B. Bolen

RE: Amended and Restated Letter Agreement – [***]

Dear Mr. Bolen:

Reference is made to that certain Gas Gathering and Compression Agreement dated as of February 26, 2020 by and among EQT Corporation, EQT Production Company, Rice Drilling B LLC and EQT Energy, LLC (collectively, “Producer”), and EQM Gathering Opco, LLC (“Gatherer”), as the same was amended by that certain First Amendment to Gas Gathering and Compression Agreement dated August 26, 2020, that Second Amendment to Gas Gathering and Compression Agreement dated December 6, 2021, that Third Amendment to Gas Gathering Compression Agreement dated December 21, 2021, that Fourth Amendment to Gas Gathering Compression Agreement dated January 23, 2023 and that Fifth Amendment to Gas Gathering Compression Agreement dated October 4, 2023 between Producer and Gatherer (as amended, the “Gathering Agreement”). All capitalized terms used but not otherwise defined in this letter agreement (“Letter Agreement”) shall have the meanings (if any) ascribed to them in the Gathering Agreement.

WHEREAS, Gatherer is willing to commence receiving Dedicated Gas at the [***] Receipt Point from and after the Requested Service Date, subject to the terms and conditions hereof;

WHEREAS, Producer and Gatherer are parties to that certain Letter Agreement – [***] dated October 3, 2023 (“Original Letter Agreement”); and

WHEREAS, Producer and Gatherer desire to amend and restate the Original Letter Agreement and accordingly, the Parties are entering into this Letter Agreement, which shall amend and restate the Original Letter Agreement in its entirety.

1. Service Commencement; [***] Shut-In Period. Subject to the terms and conditions of this Letter Agreement:

(c)Gatherer agrees to complete the installation of (i) pad-level dehydration facilities upstream of each [***] Receipt Point except for the [***] and (ii) a heater at the [***] Well Pad, which facilities and installation shall be completed, in each case, to applicable industry standards and not later than [***];

(d)Producer agrees that Dedicated Gas delivered to the [***] Receipt Point during the [***] Shut-In Period shall maintain a minimum temperature of [***];

[SIGNATURE PAGE FOLLOWS]

IN WITNESS WHEREOF, the Parties have executed this Letter Agreement as of the date first written above.

GATHERER:

EQM GATHERING OPCO, LLC,

a Delaware limited liability company

By: /s/ John M. Quinn

Name: John M. Quinn

Title: _VP Business Development & Commercial Services

PRODUCER:

EQT CORPORATION,

a Pennsylvania corporation

By: /s/ Jeremy Knop

Name: Jeremy Knop

Title: Chief Financial Officer

EQT PRODUCTION COMPANY,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Vice President Operations Planning

RICE DRILLING B LLC,

a Delaware limited liability company

By: /s/ J.E.B. Bolen

Name: J.E.B. Bolen

Title: Vice President Operations Planning

EQT ENERGY, LLC,

a Delaware limited liability company

By: /s/ Keith Shoemaker

Name: Keith Shoemaker

Title: SVP Commercial

EXHIBIT A

[***] System AMI

[***]

Exhibit 31.01

CERTIFICATION

I, Toby Z. Rice, certify that:

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

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

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

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

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

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

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

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

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

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

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


Date:	October 26, 2023

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

Exhibit 31.02

CERTIFICATION

I, Jeremy T. Knop, certify that:

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

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


Date:	October 26, 2023

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

Exhibit 32

CERTIFICATION

In connection with the Quarterly Report of EQT Corporation ("EQT") on Form 10-Q for the period ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the "Report"), each of the undersigned certify pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to their knowledge:

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

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


/s/ Toby Z. Rice						October 26, 2023
Toby Z. Rice
President and Chief Executive Officer


/s/ Jeremy T. Knop						October 26, 2023
Jeremy T. Knop
Chief Financial Officer

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

Cover - shares shares in Thousands	9 Months Ended
Cover - shares shares in Thousands	Sep. 30, 2023	Oct. 20, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	001-03551
Entity Registrant Name	EQT CORPORATION
Entity Incorporation, State or Country Code	PA
Entity Tax Identification Number	25-0464690
Entity Address, Street	625 Liberty Avenue
Entity Address, Suite	Suite 1700
Entity Address, City or Town	Pittsburgh
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	15222
City Area Code	412
Local Phone Number	553-5700
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	EQT
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		411,332
Entity Central Index Key	0000033213
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Amendment Flag	false

STATEMENTS OF CONDENSED CONSOLIDATED OPERATIONS (UNAUDITED) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$ 1,001,883	$ 3,694,194	$ 3,680,566	$ 9,546,029
Gain (loss) on derivatives	177,906	(1,627,296)	1,167,144	(5,550,028)
Total operating revenues	1,186,102	2,069,463	4,865,924	4,017,861
Operating expenses:
Transportation and processing	554,788	541,092	1,592,934	1,596,900
Production	67,093	81,785	170,071	235,353
Exploration	447	357	2,602	2,870
Selling, general and administrative	56,942	67,231	168,999	195,603
Depreciation and depletion	446,886	418,695	1,230,255	1,269,936
Loss (gain) on sale/exchange of long-lived assets	1,511	(265)	17,814	(2,455)
Impairment of contract asset	0	0	0	184,945
Impairment and expiration of leases	6,419	20,497	22,290	97,536
Other operating expenses	36,209	15,485	69,265	38,952
Total operating expenses	1,170,295	1,144,877	3,274,230	3,619,640
Operating income	15,807	924,586	1,591,694	398,221
Loss (income) from investments	546	(2,877)	(5,310)	14,331
Dividend and other income	(132)	(157)	(869)	(11,066)
Loss (gain) on debt extinguishment	1,089	27,814	(55)	139,085
Interest expense, net	60,427	60,138	146,856	194,025
(Loss) income before income taxes	(46,123)	839,668	1,451,072	61,846
Income tax (benefit) expense	(126,853)	152,206	217,975	(5,257)
Net income	80,730	687,462	1,233,097	67,103
Less: Net (loss) income attributable to noncontrolling interests	(525)	3,792	(80)	8,120
Net income attributable to EQT Corporation	$ 81,255	$ 683,670	$ 1,233,177	$ 58,983
Income per share of common stock attributable to EQT Corporation:
Weighted average common stock outstanding - Basic (in shares)	383,359	369,987	368,936	371,308
Net income attributable to EQT Corporation - Basic (in dollars per share)	$ 0.21	$ 1.85	$ 3.34	$ 0.16
Weighted average common stock outstanding - Diluted (in shares)	416,190	403,889	401,859	377,028
Net income attributable to EQT Corporation - Diluted (in dollars per share)	$ 0.20	$ 1.69	$ 3.08	$ 0.16
Sales of natural gas, natural gas liquids and oil
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$ 1,001,883	$ 3,694,194	$ 3,680,566	$ 9,546,029
Net marketing services and other
Operating revenues:
Net marketing services and other	$ 6,313	$ 2,565	$ 18,214	$ 21,860

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Comprehensive Income [Abstract]
Net income	$ 80,730	$ 687,462	$ 1,233,097	$ 67,103
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax expense: $15, $20, $44 and $61	57	63	270	190
Comprehensive income	80,787	687,525	1,233,367	67,293
Less: Comprehensive (loss) income attributable to noncontrolling interests	(525)	3,792	(80)	8,120
Comprehensive income attributable to EQT Corporation	$ 81,312	$ 683,733	$ 1,233,447	$ 59,173

STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Comprehensive Income [Abstract]
Other post-retirement benefits liability adjustment, tax expense	$ 15	$ 20	$ 44	$ 61

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 64,750	$ 1,458,644
Accounts receivable (less provision for doubtful accounts: $235 and $605)	559,348	1,608,089
Derivative instruments, at fair value	577,926	812,371
Prepaid expenses and other	45,214	135,337
Total current assets	1,247,238	4,014,441
Property, plant and equipment	33,313,666	27,393,919
Less: Accumulated depreciation and depletion	10,391,586	9,226,586
Net property, plant and equipment	22,922,080	18,167,333
Other assets	385,670	488,152
Total assets	24,554,988	22,669,926
Current liabilities:
Current portion of debt	414,592	422,632
Accounts payable	1,159,743	1,574,610
Derivative instruments, at fair value	274,684	1,393,487
Other current liabilities	269,925	341,491
Total current liabilities	2,118,944	3,732,220
Term Loan Facility borrowings	1,243,280	0
Senior notes	4,174,163	5,167,849
Note payable to EQM Midstream Partners, LP	83,831	88,484
Deferred income taxes	1,751,388	1,442,406
Other liabilities and credits	973,825	1,025,639
Total liabilities	10,345,431	11,456,598
Equity:
Common stock, no par value, shares authorized: 640,000, shares issued: 411,311 and 365,363	11,958,441	9,891,890
Retained earnings	2,245,615	1,283,578
Accumulated other comprehensive loss	(2,724)	(2,994)
Total common shareholders' equity	14,201,332	11,172,474
Noncontrolling interest in consolidated subsidiaries	8,225	40,854
Total equity	14,209,557	11,213,328
Total liabilities and equity	$ 24,554,988	$ 22,669,926

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - USD ($) shares in Thousands, $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Provision for doubtful accounts	$ 235	$ 605
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, authorized shares (in shares)	640,000	640,000
Common stock, shares issued (in shares)	411,311	365,363

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Cash flows from operating activities:
Net income	$ 1,233,097	$ 67,103
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax expense (benefit)	227,701	(14,229)
Depreciation and depletion	1,230,255	1,269,936
Impairment of long-lived assets and loss/gain on sale/exchange of long-lived assets	40,104	280,026
(Income) loss from investments	(5,310)	14,331
(Gain) loss on debt extinguishment	(55)	139,085
Share-based compensation expense	38,179	33,706
Distribution of earnings from equity method investments	18,073	38,750
Amortization, accretion and other	12,022	24,937
(Gain) loss on derivatives	(1,167,144)	5,550,028
Net cash settlements received (paid) on derivatives	625,051	(4,672,998)
Net premiums (paid) received on derivative instruments	(231,343)	13,809
Changes in other assets and liabilities:
Accounts receivable	1,122,843	(507,050)
Accounts payable	(515,879)	343,925
Other current assets	91,946	(27,960)
Other items, net	(165,076)	(151,641)
Net cash provided by operating activities	2,554,464	2,401,758
Cash flows from investing activities:
Capital expenditures	(1,485,898)	(1,047,475)
Cash paid for acquisitions	(2,288,201)	(150,000)
Proceeds from sale/exchange of assets	4,831	5,394
Proceeds from sale of investment shares	0	189,249
Other investing activities	(4,841)	(14,306)
Net cash used in investing activities	(3,774,109)	(1,017,138)
Cash flows from financing activities:
Proceeds from revolving credit facility borrowings	313,000	10,242,000
Repayment of revolving credit facility borrowings	(313,000)	(10,242,000)
Proceeds from Term Loan Facility borrowings	1,250,000	0
Debt issuance costs	(5,336)	(17,852)
Repayment and retirement of debt	(1,014,346)	(833,029)
Discounts received (premiums paid) on debt extinguishment	5,313	(135,248)
Dividends paid	(162,567)	(148,765)
Repurchase and retirement of common stock	(201,029)	(270,345)
Net (distribution to) contribution from noncontrolling interest	(7,322)	4,050
Other financing activities	(38,962)	(9,853)
Net cash used in financing activities	(174,249)	(1,411,042)
Net change in cash and cash equivalents	(1,393,894)	(26,422)
Cash and cash equivalents at beginning of period	1,458,644	113,963
Cash and cash equivalents at end of period	$ 64,750	$ 87,541

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED) - USD ($)
shares in Thousands, $ in Thousands

Total

Common Stock

Treasury Stock

(Accumulated Deficit) Retained Earnings

Accumulated Other Comprehensive Loss

Noncontrolling Interest in Consolidated Subsidiaries

Beginning balance (in shares) at Dec. 31, 2021

376,399

Beginning balance at Dec. 31, 2021

$ 9,970,999

$ 10,071,820

$ (18,046)

$ (94,400)

$ (4,611)

^[1]

$ 16,236

Comprehensive income, net of tax:

Net income (loss)

67,103

58,983

8,120

Other post-retirement benefits liability adjustment, net of tax expense

190

^[1]

Dividends

(148,765)

Share-based compensation plans (in shares)

2,061

Share-based compensation plans

28,807

$ 11,340

17,467

Convertible Notes settlements (in shares)

Convertible Notes settlements

$ 48

Repurchase and retirement of common stock (in shares)

(10,301)

Repurchase and retirement of common stock

(275,064)

$ (159,669)

(115,395)

Distribution to noncontrolling interest

(7,200)

Contribution from noncontrolling interest

11,250

Other

11,233

Ending balance (in shares) at Sep. 30, 2022

368,162

Ending balance at Sep. 30, 2022

9,658,601

$ 9,923,539

(579)

(299,577)

(4,421)

^[2]

39,639

Beginning balance (in shares) at Jun. 30, 2022

369,720

Beginning balance at Jun. 30, 2022

9,090,090

$ 9,948,646

(2,848)

(880,127)

(4,484)

^[2]

28,903

Comprehensive income, net of tax:

Net income (loss)

687,462

683,670

3,792

Other post-retirement benefits liability adjustment, net of tax expense

^[2]

Dividends

(55,493)

Share-based compensation plans (in shares)

209

Share-based compensation plans

4,561

$ 2,292

2,269

Convertible Notes settlements (in shares)

Convertible Notes settlements

$ 10

Repurchase and retirement of common stock (in shares)

(1,768)

Repurchase and retirement of common stock

(75,036)

$ (27,409)

(47,627)

Distribution to noncontrolling interest

(4,306)

Contribution from noncontrolling interest

11,250

Ending balance (in shares) at Sep. 30, 2022

368,162

Ending balance at Sep. 30, 2022

9,658,601

$ 9,923,539

(579)

(299,577)

(4,421)

^[2]

39,639

Beginning balance (in shares) at Dec. 31, 2022

365,363

Beginning balance at Dec. 31, 2022

11,213,328

$ 9,891,890

1,283,578

(2,994)

^[1]

40,854

Comprehensive income, net of tax:

Net income (loss)

1,233,097

1,233,177

(80)

Other post-retirement benefits liability adjustment, net of tax expense

270

^[1]

Dividends

(162,567)

Share-based compensation plans (in shares)

2,247

Share-based compensation plans

5,367

$ 5,367

Convertible Notes settlements (in shares)

Convertible Notes settlements

$ 98

Repurchase and retirement of common stock (in shares)

(5,906)

Repurchase and retirement of common stock

(201,029)

$ (91,545)

(109,484)

Tug Hill and XcL Midstream Acquisition (in shares)

49,600

Tug Hill and XcL Midstream Acquisition

2,152,631

$ 2,152,631

Distribution to noncontrolling interest

(11,072)

Contribution from noncontrolling interest

3,750

Dissolution of consolidated variable interest entity

(25,227)

Other

911

Ending balance (in shares) at Sep. 30, 2023

411,311

Ending balance at Sep. 30, 2023

14,209,557

$ 11,958,441

2,245,615

(2,724)

^[1]

8,225

Beginning balance (in shares) at Jun. 30, 2023

361,654

Beginning balance at Jun. 30, 2023

12,045,028

$ 9,790,855

2,217,698

(2,781)

^[2]

39,256

Comprehensive income, net of tax:

Net income (loss)

80,730

81,255

(525)

Other post-retirement benefits liability adjustment, net of tax expense

^[2]

Dividends

(54,249)

Share-based compensation plans (in shares)

Share-based compensation plans

14,939

$ 14,939

Convertible Notes settlements (in shares)

Convertible Notes settlements

$ 16

Tug Hill and XcL Midstream Acquisition (in shares)

49,600

Tug Hill and XcL Midstream Acquisition

2,152,631

$ 2,152,631

Distribution to noncontrolling interest

(5,279)

Dissolution of consolidated variable interest entity

(25,227)

Other

911

Ending balance (in shares) at Sep. 30, 2023

411,311

Ending balance at Sep. 30, 2023

$ 14,209,557

$ 11,958,441

$ 0

$ 2,245,615

$ (2,724)

^[1]

$ 8,225

[1]	Amounts included in accumulated other comprehensive loss are related to other postretirement benefits liability adjustments, net of tax, which are attributable to net actuarial losses and net prior service costs.
[2]	Amounts included in accumulated other comprehensive loss are related to other postretirement benefits liability adjustments, net of tax, which are attributable to net actuarial losses and net prior service costs.

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Stockholders' Equity [Abstract]
Other post-retirement benefits liability adjustment, tax expense	$ 15	$ 20	$ 44	$ 61
Dividends (in dollars per share)	$ 0.15	$ 0.15	$ 0.45	$ 0.40
Common stock, authorized shares (in shares)	640,000,000	640,000,000	640,000,000	640,000,000
Preferred stock authorized (in shares)	3,000,000	3,000,000	3,000,000	3,000,000
Preferred stock issued (in shares)	0	0	0	0
Preferred stock outstanding (in shares)	0	0	0	0

Financial Statements

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Financial Statements

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,
	2023		2022

	(Thousands)
Cash paid during the period for:
Interest, net of amount capitalized	$	145,787	$	208,239
Income taxes, net	13,441		10,529

Non-cash activity during the period for:
Tug Hill and XcL Midstream Acquisition	$	2,152,631	$	—
Increase in right-of-use assets and lease liabilities, net	25,849		1,651
Dissolution of consolidated variable interest entity	25,227		—
Increase in asset retirement costs and obligations	5,216		14,102
Capitalization of non-cash equity share-based compensation	4,587		3,923
Issuance of common stock for Convertible Notes settlement	98		48

Revenue from Contracts with Customers

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands)
Revenues from contracts with customers:
Natural gas sales	$	859,512	$	3,543,706	$	3,337,600	$	9,008,226
NGLs sales	108,205		134,636		274,932		475,988
Oil sales	34,166		15,852		68,034		61,815
Total revenues from contracts with customers	$	1,001,883	$	3,694,194	$	3,680,566	$	9,546,029

Other sources of revenue:
Gain (loss) on derivatives	177,906		(1,627,296)		1,167,144		(5,550,028)
Net marketing services and other	6,313		2,565		18,214		21,860
Total operating revenues	$	1,186,102	$	2,069,463	$	4,865,924	$	4,017,861


	2023 (a)		2024		Total

	(Thousands)
Natural gas sales	$	1,007	$	469	$	1,476

(a)October 1 through December 31.

Derivative Instruments

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments


	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, 2023
Asset derivative instruments, at fair value	$	577,926	$	(198,511)	$	—	$	379,415
Liability derivative instruments, at fair value	274,684		(198,511)		(14,570)		61,603

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	(756,495)	$	—	$	55,876
Liability derivative instruments, at fair value	1,393,487		(756,495)		(100,623)		536,369

Fair Value Measurements

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value Measurements

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, 2023
Asset derivative instruments, at fair value	$	577,926	$	42,352	$	535,574	$	—
Liability derivative instruments, at fair value	274,684		45,464		229,220		—

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	103,028	$	709,343	$	—
Liability derivative instruments, at fair value	1,393,487		154,601		1,238,886		—

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2023
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes For the nine months ended September 30, 2023 and 2022, the Company calculated the provision for income taxes for interim periods by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the nine months ended September 30, 2023. For the nine months ended September 30, 2023 and 2022, the Company recorded income tax expense (benefit) at an effective tax rate of 15.0% and (8.5)%, respectively. The Company's effective tax rate for the nine months ended September 30, 2023 was lower compared to the U.S. federal statutory rate due primarily as a result of the release of valuation allowances limiting certain state deferred tax assets and net state deferred tax benefit related to a rate reduction from a Pennsylvania tax law change enacted on July 8, 2022 and the Tug Hill and XcL Midstream Acquisition. The Company's effective tax rate for the nine months ended September 30, 2022 was lower compared to the U.S. federal statutory rate due primarily to a reduction to deferred state taxes from a Pennsylvania tax law change enacted on July 8, 2022, partly offset by nondeductible repurchase premiums on the Convertible Notes (defined in Note 6). The Company recognizes a valuation allowance when it is more likely than not that all or a portion of a deferred tax asset (DTA) will not be realized. All available evidence, both positive and negative, is considered when determining the need for a valuation allowance. To determine whether a valuation allowance is required, the Company uses judgement to estimate future taxable income and considers the tax consequences in the jurisdiction where such taxable income is generated as well as evidence including the Company's current financial position, actual and forecasted results of operations, the reversal of deferred tax liabilities and tax planning strategies in addition to the current and forecasted business economics of the oil and gas industry. During the three months ended September 30, 2023, the Company concluded that the positive evidence, including the Company's change in its cumulative income position from loss to income and its forecasted income, more likely than not outweighed the negative evidence regarding the realization of the Company's DTA for certain state tax net operating loss (NOL) carryforwards. As a result, the Company recorded a state deferred tax benefit of $101 million related to its valuation allowance for its state NOL carryforwards in the Statement of Condensed Consolidated Operations for the three months ended September 30, 2023. The Company has retained a valuation allowance related to its NOLs for certain entities and jurisdictions in which it is more likely than not that the benefit from the related DTA will not be realized as well as a valuation allowance against the portion of its federal and state DTAs, such as capital losses, which may expire before being fully utilized due to the limitation to offset only capital gains.

Debt

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Debt

The table below summarizes the Company's outstanding debt.


	September 30, 2023				December 31, 2022
	Principal Value		Carrying Value (a)		Principal Value		Carrying Value (a)

	(Thousands)

Term Loan Facility due June 30, 2025 (b)	$	1,250,000	$	1,243,280	$	—	$	—
Senior notes:
7.42% series B notes due 2023	—		—		10,000		10,000
6.125% notes due February 1, 2025 (b)	601,521		600,128		911,467		908,168
5.678% notes due October 1, 2025	—		—		500,000		496,578
1.75% convertible notes due May 1, 2026	414,732		408,450		414,832		406,796
3.125% notes due May 15, 2026	392,915		389,674		440,857		436,198
7.75% debentures due July 15, 2026	115,000		113,591		115,000		113,218
3.90% notes due October 1, 2027	1,169,503		1,165,167		1,233,008		1,227,582
5.700% notes due April 1, 2028	500,000		489,810		500,000		493,941
5.00% notes due January 15, 2029	318,494		314,956		327,101		322,956
7.000% notes due February 1, 2030 (b)	674,800		670,865		714,800		710,138
3.625% notes due May 15, 2031	435,165		429,972		465,165		459,070
Note payable to EQM	89,973		89,973		94,320		94,320
Total debt	5,962,103		5,915,866		5,726,550		5,678,965
Less: Current portion of debt (c)	420,874		414,592		430,668		422,632
Long-term debt	$	5,541,229	$	5,501,274	$	5,295,882	$	5,256,333

Debt Repayments. The Company redeemed or repurchased the following debt during the nine months ended September 30, 2023.


Debt Tranche	Principal		Premiums/(Discounts) (a)		Accrued but Unpaid Interest		Total Cost

	(Thousands)
6.125% notes due February 1, 2025	$	309,946	$	1,832	$	6,801	$	318,579
5.678% notes due October 1, 2025	500,000		—		6,940		506,940

3.125% notes due May 15, 2026	47,942		(3,042)		296		45,196
3.90% notes due October 1, 2027	63,505		(3,534)		781		60,752

5.00% notes due January 15, 2029	8,607		(309)		137		8,435
7.000% notes due February 1, 2030	40,000		2,736		1,313		44,049
3.625% notes due May 15, 2031	30,000		(4,011)		167		26,156
Total	$	1,000,000	$	(6,328)	$	16,435	$	1,010,107

(a)Includes third-party costs and fees paid to dealer managers and brokers.

Revolving Credit Facility. The Company has a $2.5 billion revolving credit facility that matures in June 2027.

As of September 30, 2023 and December 31, 2022, the Company had approximately $15 million and $25 million, respectively, of letters of credit outstanding under its revolving credit facility.

Holders of the Convertible Notes may convert their Convertible Notes at their option at any time prior to the close of business on January 30, 2026 under the following circumstances:

•upon the occurrence of certain corporate events set forth in the Convertible Notes indenture.

Dividend Paid

Effective Date of Adjustment to Conversion Rate

Conversion Shares of EQT Corporation Common Stock per $1,000 Principal Amount

First Quarter of 2023

February 17, 2023

68.0740

Second Quarter of 2023

May 9, 2023

68.3917

Third Quarter of 2023

August 8, 2023

68.6360


Settlement Month	Principal Converted		Shares Issued	Average Conversion Price

	(Thousands)
January 2023	$	7	473	$	33.70
February 2023	8		541	30.77
March 2023	6		408	31.46
April 2023	58		3,948	32.01
June 2023	4		272	39.06
July 2023	10		682	40.92
September 2023	6		411	42.35

The table below summarizes the net carrying value and fair value of the Convertible Notes.


	September 30, 2023		December 31, 2022

	(Thousands)
Principal	$	414,732	$	414,832
Less: Unamortized debt issuance costs	6,282		8,036
Net carrying value of Convertible Notes	$	408,450	$	406,796

Fair value of Convertible Notes (a)	$	1,155,337	$	967,728

(a)The fair value is a Level 2 fair value measurement. See Note 4.

The table below summarizes the components of interest expense related to the Convertible Notes. The effective interest rate for the Convertible Notes is 2.4%.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands)
Contractual interest expense	$	1,814	$	1,821	$	5,443	$	6,191
Amortization of issuance costs	588		574		1,752		1,945
Total Convertible Notes interest expense	$	2,402	$	2,395	$	7,195	$	8,136

Income Per Share

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

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,
	2023		2022		2023		2022

	(Thousands, except per share amounts)
Net income attributable to EQT Corporation – Basic income available to shareholders	$	81,255	$	683,670	$	1,233,177	$	58,983
Add back: Interest expense on Convertible Notes, net of tax (a)	2,042		921		6,117		—
Diluted income available to shareholders	$	83,297	$	684,591	$	1,239,294	$	58,983

Weighted average common stock outstanding – Basic	383,359		369,987		368,936		371,308
Options, restricted stock, performance awards and stock appreciation rights	4,398		5,880		4,606		5,720
Convertible Notes (a)	28,433		28,022		28,317		—
Weighted average common stock outstanding – Diluted	416,190		403,889		401,859		377,028

Income per share of common stock attributable to EQT Corporation:
Basic	$	0.21	$	1.85	$	3.34	$	0.16
Diluted	$	0.20	$	1.69	$	3.08	$	0.16

Impairment of Contract Asset	9 Months Ended
Impairment of Contract Asset	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Impairment of Contract Asset	Impairment of Contract AssetDuring the first quarter of 2020, the Company sold to Equitrans Midstream Corporation (Equitrans Midstream) approximately 50% of the Company's then-owned equity interest in Equitrans Midstream in exchange for a combination of cash and rate relief under certain of the Company's gathering contracts with an affiliate of Equitrans Midstream (the Equitrans Share Exchange). The rate relief was effected through the execution of a consolidated gas gathering and compression agreement entered into between the Company and an affiliate of Equitrans Midstream (the Consolidated GGA). On the closing date of the Equitrans Share Exchange, the Company recorded in the Condensed Consolidated Balance Sheet a contract asset of $410 million representing the estimated fair value of the rate relief inclusive of the Cash Payment Option (defined below). Because the Mountain Valley Pipeline was not in service by January 1, 2022, the Consolidated GGA provided the Company the option to forgo a portion of the gathering fee relief that would otherwise be applicable following the Mountain Valley Pipeline in-service date in exchange for a cash payment of approximately $196 million (the Cash Payment Option). During the third quarter of 2022, the Company elected to exercise the Cash Payment Option, and, in the fourth quarter of 2022, the Company received the cash proceeds from the Cash Payment Option. During 2022, the Company identified indicators that the carrying value of the contract asset may not be fully recoverable, including increased uncertainty of the estimated timing of completion of the Mountain Valley Pipeline due to court rulings and public statements from Equitrans Midstream with respect to its completion. As a result of the Company's impairment evaluation, the Company recognized impairment of the contract asset during the first quarter of 2022 of $184.9 million in the Statement of Condensed Consolidated Operations. During the fourth quarter of 2022, the Company recognized additional impairment of the contract asset of $29.3 million in the Statement of Condensed Consolidated Operations. As of December 31, 2022, the previously recognized impairments plus the election of the Cash Payment Option reduced the carrying value of the contract asset to zero. The fair value of the contract asset was based on significant inputs that are not observable in the market and, as such, is a Level 3 fair value measurement. See Note 4 for a description of the fair value hierarchy. Key assumptions used in the fair value calculation included the following: (i) a probability-weighted estimate of the in-service date of the Mountain Valley Pipeline; (ii) an estimate of the potential exercise and timing of the Cash Payment Option; (iii) an estimated production volume forecast and (iv) a market-based weighted average cost of capital.

Tug Hill and XcL Midstream Acquisitions

9 Months Ended

Sep. 30, 2023

Business Combination and Asset Acquisition [Abstract]

Tug Hill and XcL Midstream Acquisitions

Tug Hill and XcL Midstream Acquisition


	Preliminary Purchase Price Allocation

	(Thousands)
Consideration:
Equity	$	2,152,631
Cash	2,403,301
Settlement of pre-existing relationships	(31,754)
Total consideration	$	4,524,178

Fair value of assets acquired:
Cash and cash equivalents	$	100
Accounts receivable, net	75,961
Derivative instruments, at fair value	162,455
Prepaid expenses and other	1,825
Property, plant and equipment	4,555,311
Other assets	5,921
Total amount attributable to assets acquired	$	4,801,573

Fair value of liabilities assumed:
Accounts payable	$	162,668
Other current liabilities	47,399
Other liabilities and credits	67,328
Total amount attributable to liabilities assumed	$	277,395

See Note 4 for a description of the fair value hierarchy.


	August 22, 2023 through September 30, 2023

	(Thousands)
Sales of natural gas, NGLs and oil	$	64,541
Loss on derivatives	(6,126)
Net marketing services and other	299
Total operating revenues	$	58,714

Net loss	$	(26,612)


	Nine Months Ended September 30,
	2023		2022

	(Thousands, except per share amounts)
Pro forma sales of natural gas, NGLs and oil	$	4,145,295	$	10,899,338
Pro forma gain (loss) on derivatives	1,324,773		(5,535,540)
Pro forma net marketing services and other	20,720		31,034
Pro forma total operating revenues	$	5,490,788	$	5,394,832

Pro forma net income	$	1,410,143	$	646,609
Less: Pro forma net (loss) income attributable to noncontrolling interests	(80)		8,120
Pro forma net income attributable to EQT Corporation	$	1,410,223	$	638,489

Pro forma income per share of common stock attributable to EQT Corporation:
Pro forma net income attributable to EQT Corporation – Basic	$	3.82	$	1.72
Pro forma net income attributable to EQT Corporation – Diluted	$	3.52	$	1.69

Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Thousands	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net Income (Loss)	$ 81,255	$ 683,670	$ 1,233,177	$ 58,983

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

Financial Statements (Tables)

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

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


	Nine Months Ended September 30,
	2023		2022

	(Thousands)
Cash paid during the period for:
Interest, net of amount capitalized	$	145,787	$	208,239
Income taxes, net	13,441		10,529

Non-cash activity during the period for:
Tug Hill and XcL Midstream Acquisition	$	2,152,631	$	—
Increase in right-of-use assets and lease liabilities, net	25,849		1,651
Dissolution of consolidated variable interest entity	25,227		—
Increase in asset retirement costs and obligations	5,216		14,102
Capitalization of non-cash equity share-based compensation	4,587		3,923
Issuance of common stock for Convertible Notes settlement	98		48

Revenue from Contracts with Customers (Tables)

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands)
Revenues from contracts with customers:
Natural gas sales	$	859,512	$	3,543,706	$	3,337,600	$	9,008,226
NGLs sales	108,205		134,636		274,932		475,988
Oil sales	34,166		15,852		68,034		61,815
Total revenues from contracts with customers	$	1,001,883	$	3,694,194	$	3,680,566	$	9,546,029

Other sources of revenue:
Gain (loss) on derivatives	177,906		(1,627,296)		1,167,144		(5,550,028)
Net marketing services and other	6,313		2,565		18,214		21,860
Total operating revenues	$	1,186,102	$	2,069,463	$	4,865,924	$	4,017,861

Schedule of Transaction Price Allocation


	2023 (a)		2024		Total

	(Thousands)
Natural gas sales	$	1,007	$	469	$	1,476

(a)October 1 through December 31.

Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Offsetting Assets

The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.


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

	(Thousands)
September 30, 2023
Asset derivative instruments, at fair value	$	577,926	$	(198,511)	$	—	$	379,415
Liability derivative instruments, at fair value	274,684		(198,511)		(14,570)		61,603

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	(756,495)	$	—	$	55,876
Liability derivative instruments, at fair value	1,393,487		(756,495)		(100,623)		536,369

Schedule of Offsetting Liabilities

The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.


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

	(Thousands)
September 30, 2023
Asset derivative instruments, at fair value	$	577,926	$	(198,511)	$	—	$	379,415
Liability derivative instruments, at fair value	274,684		(198,511)		(14,570)		61,603

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	(756,495)	$	—	$	55,876
Liability derivative instruments, at fair value	1,393,487		(756,495)		(100,623)		536,369

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis

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


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

	(Thousands)
September 30, 2023
Asset derivative instruments, at fair value	$	577,926	$	42,352	$	535,574	$	—
Liability derivative instruments, at fair value	274,684		45,464		229,220		—

December 31, 2022
Asset derivative instruments, at fair value	$	812,371	$	103,028	$	709,343	$	—
Liability derivative instruments, at fair value	1,393,487		154,601		1,238,886		—

Debt (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Schedule of Long-Term Debt Instruments

The table below summarizes the Company's outstanding debt.


	September 30, 2023				December 31, 2022
	Principal Value		Carrying Value (a)		Principal Value		Carrying Value (a)

	(Thousands)

Term Loan Facility due June 30, 2025 (b)	$	1,250,000	$	1,243,280	$	—	$	—
Senior notes:
7.42% series B notes due 2023	—		—		10,000		10,000
6.125% notes due February 1, 2025 (b)	601,521		600,128		911,467		908,168
5.678% notes due October 1, 2025	—		—		500,000		496,578
1.75% convertible notes due May 1, 2026	414,732		408,450		414,832		406,796
3.125% notes due May 15, 2026	392,915		389,674		440,857		436,198
7.75% debentures due July 15, 2026	115,000		113,591		115,000		113,218
3.90% notes due October 1, 2027	1,169,503		1,165,167		1,233,008		1,227,582
5.700% notes due April 1, 2028	500,000		489,810		500,000		493,941
5.00% notes due January 15, 2029	318,494		314,956		327,101		322,956
7.000% notes due February 1, 2030 (b)	674,800		670,865		714,800		710,138
3.625% notes due May 15, 2031	435,165		429,972		465,165		459,070
Note payable to EQM	89,973		89,973		94,320		94,320
Total debt	5,962,103		5,915,866		5,726,550		5,678,965
Less: Current portion of debt (c)	420,874		414,592		430,668		422,632
Long-term debt	$	5,541,229	$	5,501,274	$	5,295,882	$	5,256,333

Schedule of Debt Instrument Redemption

The Company redeemed or repurchased the following debt during the nine months ended September 30, 2023.


Debt Tranche	Principal		Premiums/(Discounts) (a)		Accrued but Unpaid Interest		Total Cost

	(Thousands)
6.125% notes due February 1, 2025	$	309,946	$	1,832	$	6,801	$	318,579
5.678% notes due October 1, 2025	500,000		—		6,940		506,940

3.125% notes due May 15, 2026	47,942		(3,042)		296		45,196
3.90% notes due October 1, 2027	63,505		(3,534)		781		60,752

5.00% notes due January 15, 2029	8,607		(309)		137		8,435
7.000% notes due February 1, 2030	40,000		2,736		1,313		44,049
3.625% notes due May 15, 2031	30,000		(4,011)		167		26,156
Total	$	1,000,000	$	(6,328)	$	16,435	$	1,010,107

(a)Includes third-party costs and fees paid to dealer managers and brokers.

Schedule of Convertible Debt

Dividend Paid

Effective Date of Adjustment to Conversion Rate

Conversion Shares of EQT Corporation Common Stock per $1,000 Principal Amount

First Quarter of 2023

February 17, 2023

68.0740

Second Quarter of 2023

May 9, 2023

68.3917

Third Quarter of 2023

August 8, 2023

68.6360


Settlement Month	Principal Converted		Shares Issued	Average Conversion Price

	(Thousands)
January 2023	$	7	473	$	33.70
February 2023	8		541	30.77
March 2023	6		408	31.46
April 2023	58		3,948	32.01
June 2023	4		272	39.06
July 2023	10		682	40.92
September 2023	6		411	42.35

The table below summarizes the net carrying value and fair value of the Convertible Notes.


	September 30, 2023		December 31, 2022

	(Thousands)
Principal	$	414,732	$	414,832
Less: Unamortized debt issuance costs	6,282		8,036
Net carrying value of Convertible Notes	$	408,450	$	406,796

Fair value of Convertible Notes (a)	$	1,155,337	$	967,728

(a)The fair value is a Level 2 fair value measurement. See Note 4.

The table below summarizes the components of interest expense related to the Convertible Notes. The effective interest rate for the Convertible Notes is 2.4%.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

	(Thousands)
Contractual interest expense	$	1,814	$	1,821	$	5,443	$	6,191
Amortization of issuance costs	588		574		1,752		1,945
Total Convertible Notes interest expense	$	2,402	$	2,395	$	7,195	$	8,136

Income Per Share (Table)

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

Computation of Basic and Diluted Income 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,
	2023		2022		2023		2022

	(Thousands, except per share amounts)
Net income attributable to EQT Corporation – Basic income available to shareholders	$	81,255	$	683,670	$	1,233,177	$	58,983
Add back: Interest expense on Convertible Notes, net of tax (a)	2,042		921		6,117		—
Diluted income available to shareholders	$	83,297	$	684,591	$	1,239,294	$	58,983

Weighted average common stock outstanding – Basic	383,359		369,987		368,936		371,308
Options, restricted stock, performance awards and stock appreciation rights	4,398		5,880		4,606		5,720
Convertible Notes (a)	28,433		28,022		28,317		—
Weighted average common stock outstanding – Diluted	416,190		403,889		401,859		377,028

Income per share of common stock attributable to EQT Corporation:
Basic	$	0.21	$	1.85	$	3.34	$	0.16
Diluted	$	0.20	$	1.69	$	3.08	$	0.16

Tug Hill and XcL Midstream Acquisitions (Tables)

9 Months Ended

Sep. 30, 2023

Business Combination and Asset Acquisition [Abstract]

Schedule of Allocation of Purchase Price

The table below summarizes the preliminary purchase price and estimated fair values of assets acquired and liabilities assumed as of August 22, 2023. Certain information necessary to complete the purchase price allocation is not yet available, including, but not limited to, final appraisals of assets acquired and liabilities assumed. The Company expects to complete the purchase price allocation once it has received all necessary information, at which time the value of the assets acquired and liabilities assumed will be revised if necessary.


	Preliminary Purchase Price Allocation

	(Thousands)
Consideration:
Equity	$	2,152,631
Cash	2,403,301
Settlement of pre-existing relationships	(31,754)
Total consideration	$	4,524,178

Fair value of assets acquired:
Cash and cash equivalents	$	100
Accounts receivable, net	75,961
Derivative instruments, at fair value	162,455
Prepaid expenses and other	1,825
Property, plant and equipment	4,555,311
Other assets	5,921
Total amount attributable to assets acquired	$	4,801,573

Fair value of liabilities assumed:
Accounts payable	$	162,668
Other current liabilities	47,399
Other liabilities and credits	67,328
Total amount attributable to liabilities assumed	$	277,395

Schedule of Post-Acquisition Operating Results

The table below summarizes amounts contributed by the upstream, gathering and processing assets acquired in the Tug Hill and XcL Midstream Acquisition to the Company's consolidated results for the period from August 22, 2023 through September 30, 2023.


	August 22, 2023 through September 30, 2023

	(Thousands)
Sales of natural gas, NGLs and oil	$	64,541
Loss on derivatives	(6,126)
Net marketing services and other	299
Total operating revenues	$	58,714

Net loss	$	(26,612)

Such unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Tug Hill and XcL Midstream Acquisition occurred on January 1, 2022 nor are they indicative of future consolidated results of operations.


	Nine Months Ended September 30,
	2023		2022

	(Thousands, except per share amounts)
Pro forma sales of natural gas, NGLs and oil	$	4,145,295	$	10,899,338
Pro forma gain (loss) on derivatives	1,324,773		(5,535,540)
Pro forma net marketing services and other	20,720		31,034
Pro forma total operating revenues	$	5,490,788	$	5,394,832

Pro forma net income	$	1,410,143	$	646,609
Less: Pro forma net (loss) income attributable to noncontrolling interests	(80)		8,120
Pro forma net income attributable to EQT Corporation	$	1,410,223	$	638,489

Pro forma income per share of common stock attributable to EQT Corporation:
Pro forma net income attributable to EQT Corporation – Basic	$	3.82	$	1.72
Pro forma net income attributable to EQT Corporation – Diluted	$	3.52	$	1.69

Financial Statements (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Financial Statements (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Cash paid during the period for:
Interest, net of amount capitalized			$ 145,787	$ 208,239
Income taxes, net			13,441	10,529
Non-cash activity during the period for:
Tug Hill and XcL Midstream Acquisition			2,152,631	0
Increase in right-of-use assets and lease liabilities, net			25,849	1,651
Dissolution of consolidated variable interest entity			25,227	0
Increase in asset retirement costs and obligations			5,216	14,102
Capitalization of non-cash equity share-based compensation			4,587	3,923
Issuance of common stock for Convertible Notes settlement	$ 16	$ 10	$ 98	$ 48

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Disaggregation of Revenue
Amounts due from contracts with customers	$ 382.2	$ 1,171.9
Natural Gas, Oil, and NGLs Sales
Disaggregation of Revenue
Number of days in which payment is required	25 days

Revenue from Contracts with Customers - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue
Total revenues from contracts with customers	$ 1,001,883	$ 3,694,194	$ 3,680,566	$ 9,546,029
Gain (loss) on derivatives	177,906	(1,627,296)	1,167,144	(5,550,028)
Total operating revenues	1,186,102	2,069,463	4,865,924	4,017,861
Natural gas sales
Disaggregation of Revenue
Total revenues from contracts with customers	859,512	3,543,706	3,337,600	9,008,226
NGLs sales
Disaggregation of Revenue
Total revenues from contracts with customers	108,205	134,636	274,932	475,988
Oil sales
Disaggregation of Revenue
Total revenues from contracts with customers	34,166	15,852	68,034	61,815
Net marketing services and other
Disaggregation of Revenue
Net marketing services and other	$ 6,313	$ 2,565	$ 18,214	$ 21,860

Revenue from Contracts with Customers - Remaining Performance Obligations (Details) - Natural gas sales $ in Thousands	Sep. 30, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,476
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,007
Remaining performance obligation, expected timing of satisfaction, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 469
Remaining performance obligation, expected timing of satisfaction, period	1 year

Derivative Instruments - Narrative (Details)	9 Months Ended			12 Months Ended
Derivative Instruments - Narrative (Details)	Sep. 30, 2023 USD ($) Bcf	Sep. 30, 2023 USD ($) MBbls	Sep. 30, 2023 USD ($)	Dec. 31, 2022 USD ($) Bcf	Dec. 31, 2022 USD ($) MBbls
Derivative Instruments, Gain (Loss)
Maximum additional collateral as percentage of derivative liability (in percent)			100.00%
Aggregate fair value of derivative instruments with credit-risk related contingencies	$ 0	$ 0	$ 0	$ 347,600,000	$ 347,600,000
Collateral posted				0	0
OTC Derivative Instrument Contracts
Derivative Instruments, Gain (Loss)
Aggregate fair value of derivative instruments with credit-risk related contingencies	0	0	0	0	0
Exchange traded natural gas contracts
Derivative Instruments, Gain (Loss)
Collateral posted	14,600,000	14,600,000	14,600,000	100,600,000	100,600,000
Henry hub cash bonus
Derivative Instruments, Gain (Loss)
Derivative liability	$ 54,400,000	$ 54,400,000	$ 54,400,000	$ 0	$ 0
Cash flow hedging \| Commodity derivatives
Derivative Instruments, Gain (Loss)
Volume of derivative instruments (in Bcf, Mbbls)	1,866,000,000,000	881,000		1,424	1,483

Derivative Instruments - Impact of Netting Agreements and Margin Deposits (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Asset derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	$ 577,926	$ 812,371
Liability derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	274,684	1,393,487
Commodity derivatives
Asset derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	577,926	812,371
Derivative instruments subject to master netting agreements	(198,511)	(756,495)
Margin requirements with counterparties	0	0
Net derivative instruments	379,415	55,876
Liability derivative instruments, at fair value
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets	274,684	1,393,487
Derivative instruments subject to master netting agreements	(198,511)	(756,495)
Margin requirements with counterparties	(14,570)	(100,623)
Net derivative instruments	$ 61,603	$ 536,369

Fair Value Measurements - Derivative Instrument Assets and Liabilities Measured at Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	$ 577,926	$ 812,371
Liability derivative instruments, at fair value	274,684	1,393,487
Recurring \| Quoted prices in active markets for identical assets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	42,352	103,028
Liability derivative instruments, at fair value	45,464	154,601
Recurring \| Significant other observable inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	535,574	709,343
Liability derivative instruments, at fair value	229,220	1,238,886
Recurring \| Significant unobservable inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	0	0
Liability derivative instruments, at fair value	0	0
Recurring \| Fair value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Asset derivative instruments, at fair value	577,926	812,371
Liability derivative instruments, at fair value	$ 274,684	$ 1,393,487

Fair Value Measurements - Narrative (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Net carrying value of convertible notes	$ 5,915,866	$ 5,678,965
Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Net carrying value of convertible notes	4,600,000	5,600,000
Senior Notes \| Significant other observable inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Estimated fair value of long-term debt	5,200,000	6,100,000
Note payable to EQM \| Note payable to EQM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Net carrying value of convertible notes	89,973	94,320
Note payable to EQM \| Significant unobservable inputs (Level 3) \| Note payable to EQM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Estimated fair value of long-term debt	$ 89,000	$ 96,000

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2023	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Effective income tax expense (benefit) (in percent)		15.00%	(8.50%)
State deferred tax benefit	$ 101

Debt - Schedule of Long-Term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2023	May 10, 2023	Dec. 31, 2022	Nov. 09, 2022	Oct. 04, 2022	Apr. 30, 2020
Debt Instrument [Line Items]
Principal Value	$ 5,962,103		$ 5,726,550
Carrying Value	5,915,866		5,678,965
Less: Current portion of debt, principal value	420,874		430,668
Less: Current portion of debt, carrying value	414,592		422,632
Total long-term debt, principal value	5,541,229		5,295,882
Total long-term debt, carrying value	5,501,274		5,256,333
Senior Notes
Debt Instrument [Line Items]
Carrying Value	4,600,000		5,600,000
Term Loan Facility due June 30, 2025 \| Loans Payable
Debt Instrument [Line Items]
Principal Value	1,250,000		0	$ 1,250,000
Carrying Value	$ 1,243,280		$ 0
7.42% series B notes due 2023 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	7.42%		7.42%
Principal Value	$ 0		$ 10,000
Carrying Value	$ 0		10,000
6.125% notes due February 1, 2025 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	6.125%
Principal Value	$ 601,521		911,467
Carrying Value	$ 600,128		908,168
5.678% notes due October 1, 2025 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	5.678%
Principal Value	$ 0		500,000
Carrying Value	$ 0		$ 496,578
1.75% convertible notes due May 1, 2026 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	1.75%		1.75%			1.75%
Principal Value	$ 414,732		$ 414,832			$ 500,000
Carrying Value	$ 408,450		406,796
3.125% notes due May 15, 2026 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	3.125%
Principal Value	$ 392,915		440,857
Carrying Value	$ 389,674		436,198
7.75% debentures due July 15, 2026 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	7.75%
Principal Value	$ 115,000		115,000
Carrying Value	$ 113,591		113,218
3.90% notes due October 1, 2027 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	3.90%
Principal Value	$ 1,169,503		1,233,008
Carrying Value	$ 1,165,167		1,227,582
5.700% notes due April 1, 2028 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	5.70%	5.70%			5.70%
Principal Value	$ 500,000		500,000
Carrying Value	$ 489,810		493,941
5.00% notes due January 15, 2029 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	5.00%
Principal Value	$ 318,494		327,101
Carrying Value	$ 314,956		322,956
7.000% notes due February 1, 2030 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	7.00%
Principal Value	$ 674,800		714,800
Carrying Value	$ 670,865		710,138
3.625% notes due May 15, 2031 \| Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	3.625%
Principal Value	$ 435,165		465,165
Carrying Value	429,972		459,070
Note payable to EQM \| Note payable to EQM
Debt Instrument [Line Items]
Principal Value	89,973		94,320
Carrying Value	$ 89,973		$ 94,320

Debt - Debt Instrument Redemption (Details) - Senior Notes $ in Thousands	9 Months Ended
	Sep. 30, 2023 USD ($)
Debt Instrument [Line Items]
Principal	$ 1,000,000
Premiums/(Discounts)	(6,328)
Accrued but Unpaid Interest	16,435
Total Cost	$ 1,010,107
6.125% notes due February 1, 2025
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	6.125%
Principal	$ 309,946
Premiums/(Discounts)	1,832
Accrued but Unpaid Interest	6,801
Total Cost	$ 318,579
5.678% notes due October 1, 2025
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	5.678%
Principal	$ 500,000
Premiums/(Discounts)	0
Accrued but Unpaid Interest	6,940
Total Cost	$ 506,940
3.125% notes due May 15, 2026
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	3.125%
Principal	$ 47,942
Premiums/(Discounts)	(3,042)
Accrued but Unpaid Interest	296
Total Cost	$ 45,196
3.90% notes due October 1, 2027
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	3.90%
Principal	$ 63,505
Premiums/(Discounts)	(3,534)
Accrued but Unpaid Interest	781
Total Cost	$ 60,752
5.00% notes due January 15, 2029
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	5.00%
Principal	$ 8,607
Premiums/(Discounts)	(309)
Accrued but Unpaid Interest	137
Total Cost	$ 8,435
7.000% notes due February 1, 2030
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	7.00%
Principal	$ 40,000
Premiums/(Discounts)	2,736
Accrued but Unpaid Interest	1,313
Total Cost	$ 44,049
3.625% notes due May 15, 2031
Debt Instrument [Line Items]
Interest rate, stated percentage (in percent)	3.625%
Principal	$ 30,000
Premiums/(Discounts)	(4,011)
Accrued but Unpaid Interest	167
Total Cost	$ 26,156

Debt - Conversion Shares of EQT Common Stock (Details)	Aug. 08, 2023	May 09, 2023	Feb. 17, 2023
1.75% convertible notes due May 1, 2026 \| Senior Notes
Debt Instrument [Line Items]
Conversion ratio	0.0686360	0.0683917	0.0680740

Debt - Narrative (Details) $ / shares in Units, $ in Thousands					1 Months Ended		3 Months Ended		9 Months Ended
	Sep. 29, 2023 USD ($) $ / shares	Aug. 22, 2023 USD ($)	Aug. 21, 2023 USD ($)	May 10, 2023 USD ($)	Sep. 30, 2023 USD ($)	Apr. 30, 2020 USD ($) d $ / shares	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Nov. 09, 2022 USD ($)	Oct. 04, 2022
Line of Credit Facility
Principal					$ 5,962,103		$ 5,962,103		$ 5,962,103		$ 5,726,550
Redemption price, percentage						100.00%
Convertible note, measurement period trading days \| d						5
Convertible notes, measurement period consecutive trading days \| d						5
Strike price (in dollars per share) \| $ / shares						$ 15.00
Capped price (in dollars per share) \| $ / shares						$ 18.75
Closing stock price (in dollars per share) \| $ / shares	$ 40.58
5.700% notes due April 1, 2028 \| Senior Notes
Line of Credit Facility
Principal					$ 500,000		$ 500,000		$ 500,000		500,000
Interest rate, stated percentage (in percent)				5.70%	5.70%		5.70%		5.70%				5.70%
Debt instrument, covenant, consent solicitation statement, consent fee				$ 5,300
1.75% convertible notes due May 1, 2026 \| Senior Notes
Line of Credit Facility
Principal					$ 414,732	$ 500,000	$ 414,732		$ 414,732		$ 414,832
Interest rate, stated percentage (in percent)					1.75%	1.75%	1.75%		1.75%		1.75%
Convertible notes, trading days \| d						20
Convertible notes, consecutive trading days \| d						30
Redemption price, percentage						130.00%
Minimum trigger price as percentage						98.00%
If-converted value	$ 740,000
Term Loan Facility due June 30, 2025 \| Loans Payable
Line of Credit Facility
Weighted average interest rates (percent)					7.00%
Principal					$ 1,250,000		$ 1,250,000		$ 1,250,000		$ 0	$ 1,250,000
Surety bonds issued, amount		$ 1,250,000
Debt issuance costs			$ 7,100
Proceeds from debt			$ 1,242,900
Financial commitments under facility percentage (in percent)					65.00%		65.00%		65.00%
Revolving credit facility \| EQT 2.5 Billion Facility
Line of Credit Facility
Line of credit facility, maximum borrowing capacity					$ 2,500,000		$ 2,500,000		$ 2,500,000
Letters of credit outstanding under revolving credit facility					$ 15,000		15,000		15,000		$ 25,000
Maximum amount of outstanding short-term loans at any time during the period							158,000	$ 1,216,000	158,000	$ 1,300,000
Average daily balance of short-term loans outstanding during the period							$ 28,000	$ 717,000	$ 9,000	$ 624,000
Weighted average interest rates (percent)							6.90%	3.80%	6.90%	2.80%

Debt - Summary of Convertible Notes Settlements and Conversions (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended
	Sep. 30, 2023	Jul. 31, 2023	Jun. 30, 2023	Apr. 30, 2023	Mar. 31, 2023	Feb. 28, 2023	Jan. 31, 2023
January 2023
Line of Credit Facility
Principal Converted							$ 7
Shares Issued (in shares)							473
Average Conversion Price (in USD per share)							$ 33.70
February 2023
Line of Credit Facility
Principal Converted						$ 8
Shares Issued (in shares)						541
Average Conversion Price (in USD per share)						$ 30.77
March 2023
Line of Credit Facility
Principal Converted					$ 6
Shares Issued (in shares)					408
Average Conversion Price (in USD per share)					$ 31.46
April 2023
Line of Credit Facility
Principal Converted				$ 58
Shares Issued (in shares)				3,948
Average Conversion Price (in USD per share)				$ 32.01
June 2023
Line of Credit Facility
Principal Converted			$ 4
Shares Issued (in shares)			272
Average Conversion Price (in USD per share)			$ 39.06
July 2023
Line of Credit Facility
Principal Converted		$ 10
Shares Issued (in shares)		682
Average Conversion Price (in USD per share)		$ 40.92
September 2023
Line of Credit Facility
Principal Converted	$ 6
Shares Issued (in shares)	411
Average Conversion Price (in USD per share)	$ 42.35

Debt - Summary of Net Carrying Amount of Convertible Notes (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Apr. 30, 2020
Line of Credit Facility
Principal	$ 5,962,103	$ 5,726,550
Net carrying value of Convertible Notes	5,915,866	5,678,965
Senior Notes
Line of Credit Facility
Net carrying value of Convertible Notes	4,600,000	5,600,000
1.75% convertible notes due May 1, 2026 \| Senior Notes
Line of Credit Facility
Principal	414,732	414,832	$ 500,000
Less: Unamortized debt issuance costs	6,282	8,036
Net carrying value of Convertible Notes	408,450	406,796
Fair value of Convertible Notes	$ 1,155,337	$ 967,728

Debt - Convertible Debt Notes (Details) - 1.75% convertible notes due May 1, 2026 - Senior Notes - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Line of Credit Facility
Effective interest rate (in percent)	2.40%		2.40%
Contractual interest expense	$ 1,814	$ 1,821	$ 5,443	$ 6,191
Amortization of issuance costs	588	574	1,752	1,945
Total Convertible Notes interest expense	$ 2,402	$ 2,395	$ 7,195	$ 8,136

Income Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Earnings Per Share Reconciliation [Abstract]
Net income attributable to EQT Corporation – Basic income available to shareholders	$ 81,255	$ 683,670	$ 1,233,177	$ 58,983
Add back: Interest expense on Convertible Notes, net of tax	2,042	921	6,117	0
Diluted income available to shareholders	$ 83,297	$ 684,591	$ 1,239,294	$ 58,983
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Weighted average common stock outstanding - basic (in shares)	383,359	369,987	368,936	371,308
Weighted average common stock outstanding - diluted (in shares)	416,190	403,889	401,859	377,028
Income per share of common stock attributable to EQT Corporation:
Basic (in dollars per share)	$ 0.21	$ 1.85	$ 3.34	$ 0.16
Diluted (in dollars per share)	$ 0.20	$ 1.69	$ 3.08	$ 0.16
Convertible notes
Income per share of common stock attributable to EQT Corporation:
Shares excluded from potentially dilutive securities (in shares)				31,600
Add back: interest expense on convertible notes, net of tax				$ 6,100
Options, restricted stock, performance awards, and stock appreciation rights
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Potentially dilutive securities included in the calculation of diluted earnings (in shares)	4,398	5,880	4,606	5,720
Convertible notes
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Potentially dilutive securities included in the calculation of diluted earnings (in shares)	28,433	28,022	28,317	0

Impairment of Contract Asset (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022	Mar. 31, 2022	Sep. 30, 2023	Sep. 30, 2022	Jan. 01, 2022	Mar. 31, 2020
Noncontrolling Interest [Line Items]
Contract asset, noncurrent		$ 0						$ 410,000
Cash payment option value for contract asset							$ 196,000
Impairment of contract asset	$ 0	$ 29,300	$ 0	$ 184,900	$ 0	$ 184,945
Equitrans Midstream
Noncontrolling Interest [Line Items]
Percentage of equity interest sold (in percent)								50.00%

Tug Hill and XcL Midstream Acquisitions - Narrative (Details) $ in Thousands		9 Months Ended
	Aug. 22, 2023 USD ($) MMcfe / d mi a shares	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Nov. 09, 2022 USD ($)
Business Acquisition [Line Items]
Cash		$ 2,288,201	$ 150,000
Principal		5,962,103		$ 5,726,550
Term Loan Facility due June 30, 2025 \| Loans Payable
Business Acquisition [Line Items]
Principal		$ 1,250,000		$ 0	$ 1,250,000
Surety bonds issued, amount	$ 1,250,000
Tug Hill and XcL Midstream
Business Acquisition [Line Items]
Equity interest issued or issuable, number of shares (in shares) \| shares	49,599,796
Cash	$ 2,403,301
Cash paid for acquisitions	1,000,000
Cash deposit previously held in escrow	$ 150,000
Acres acquired from asset acquisition (acres) \| a	90,000
Units produced per day (in MMcfe per day) \| MMcfe / d	800
Miles of midstream gathering systems acquired \| mi	145
Miles of connected water infrastructure acquired \| mi	55
Number of facilities acquired \| mi	4

Tug Hill and XcL Midstream Acquisitions - Preliminary Purchase Price Allocation (Details) - USD ($) $ in Thousands		9 Months Ended
	Aug. 22, 2023	Sep. 30, 2023	Sep. 30, 2022
Consideration:
Equity		$ 2,152,631	$ 0
Cash		$ 2,288,201	$ 150,000
Tug Hill and XcL Midstream
Consideration:
Equity	$ 2,152,631
Cash	2,403,301
Settlement of pre-existing relationships	(31,754)
Total consideration	4,524,178
Fair value of assets acquired:
Cash and cash equivalents	100
Accounts receivable, net	75,961
Derivative instruments, at fair value	162,455
Prepaid expenses and other	1,825
Property, plant and equipment	4,555,311
Other assets	5,921
Total amount attributable to assets acquired	4,801,573
Fair value of liabilities assumed:
Accounts payable	162,668
Other current liabilities	47,399
Other liabilities and credits	67,328
Total amount attributable to liabilities assumed	$ 277,395

Tug Hill and XcL Midstream Acquisitions - Post-Acquisition Operating Results (Details) - Tug Hill and XcL Midstream $ in Thousands	1 Months Ended
	Sep. 30, 2023 USD ($)
Business Acquisition [Line Items]
Sales of natural gas, NGLs and oil	$ 64,541
Loss on derivatives	(6,126)
Net marketing services and other	299
Total operating revenues	58,714
Net loss	$ (26,612)

Tug Hill and XcL Midstream Acquisitions - Unaudited Pro Forma Information (Details) - Tug Hill and XcL Midstream - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Business Acquisition [Line Items]
Pro forma sales of natural gas, NGLs and oil	$ 4,145,295	$ 10,899,338
Pro forma gain (loss) on derivatives	1,324,773	(5,535,540)
Pro forma net marketing services and other	20,720	31,034
Pro forma total operating revenues	5,490,788	5,394,832
Pro forma net income	1,410,143	646,609
Less: Pro forma net (loss) income attributable to noncontrolling interests	(80)	8,120
Pro forma net income attributable to EQT Corporation	$ 1,410,223	$ 638,489
Pro forma net income attributable to EQT Corporation – Basic (in dollars per share)	$ 3.82	$ 1.72
Pro forma net income attributable to EQT Corporation – Diluted (in dollars per share)	$ 3.52	$ 1.69