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, ~~2021~~2022

☐

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~~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 ☒

As of October ~~22, 2021, 377,948,658~~21, 2022, 367,046,005 shares of common stock, no par value, of the registrant were outstanding.

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,
2021 2020 2021 2020
(Thousands, except per share amounts)
Operating revenues:
Sales of natural gas, natural gas liquids and oil $ 1,784,050 $ 598,992 $ 3,992,905 $ 1,812,965
Loss on derivatives not designated as hedges (3,257,237) (427,182) (4,791,582) (11,320)
Net marketing services and other 8,349 317 23,646 4,613
Total operating revenues (1,464,838) 172,127 (775,031) 1,806,258
Operating expenses:
Transportation and processing 494,897 427,691 1,404,697 1,273,161
Production 57,823 39,670 152,599 118,379
Exploration 20,495 3,160 23,223 4,959
Selling, general and administrative 49,113 51,654 143,972 129,933
Depreciation and depletion 442,876 341,027 1,200,280 1,021,649
Amortization of intangible assets — 7,478 — 22,433
(Gain) loss on sale/exchange of long-lived assets (391) 4,662 (18,414) 102,721
Impairment and expiration of leases 41,109 50,449 83,500 145,496
Other operating expenses 38,766 6,531 53,434 11,276
Total operating expenses 1,144,688 932,322 3,043,291 2,830,007
Operating loss (2,609,526) (760,195) (3,818,322) (1,023,749)
Gain on Equitrans Share Exchange (see Note 8) — — — (187,223)
(Income) loss from investments (43,184) (3,801) (66,861) 303,844
Dividend and other income (4,260) (2,900) (11,329) (31,204)
Loss on debt extinguishment — 3,749 9,756 20,712
Interest expense 80,349 69,154 232,434 196,914
Loss before income taxes (2,642,431) (826,397) (3,982,322) (1,326,792)
Income tax benefit (662,915) (225,757) (1,025,255) (295,938)
Net loss (1,979,516) (600,640) (2,957,067) (1,030,854)
Less: Net income attributable to noncontrolling interest 601 — 25 —
Net loss attributable to EQT Corporation $ (1,980,117) $ (600,640) $ (2,957,092) $ (1,030,854)
Loss per share of common stock attributable to EQT Corporation:
Basic:
Weighted average common stock outstanding 356,792 255,589 304,961 255,516
Net loss $ (5.55) $ (2.35) $ (9.70) $ (4.03)
Diluted:
Weighted average common stock outstanding 356,792 255,589 304,961 255,516
Net loss $ (5.55) $ (2.35) $ (9.70) $ (4.03)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021

	(Thousands, except per share amounts)
Operating revenues:
Sales of natural gas, natural gas liquids and oil	$	3,694,194	$	1,784,050	$	9,546,029	$	3,992,905
Loss on derivatives	(1,627,296)		(3,257,237)		(5,550,028)		(4,791,582)
Net marketing services and other	2,565		8,349		21,860		23,646
Total operating revenues	2,069,463		(1,464,838)		4,017,861		(775,031)
Operating expenses:
Transportation and processing	541,092		494,897		1,596,900		1,404,697
Production	81,785		57,823		235,353		152,599
Exploration	357		20,495		2,870		23,223
Selling, general and administrative	67,231		49,113		195,603		143,972
Depreciation and depletion	418,695		442,876		1,269,936		1,200,280
Gain on sale/exchange of long-lived assets	(265)		(391)		(2,455)		(18,414)
Impairment of contract asset	—		—		184,945		—
Impairment and expiration of leases	20,497		41,109		97,536		83,500
Other operating expenses	15,485		38,766		38,952		53,434
Total operating expenses	1,144,877		1,144,688		3,619,640		3,043,291
Operating income (loss)	924,586		(2,609,526)		398,221		(3,818,322)
(Income) loss from investments	(2,877)		(43,184)		14,331		(66,861)
Dividend and other income	(157)		(4,260)		(11,066)		(11,329)
Loss on debt extinguishment	27,814		—		139,085		9,756
Interest expense	60,138		75,509		194,025		218,236
Income (loss) before income taxes	839,668		(2,637,591)		61,846		(3,968,124)
Income tax expense (benefit)	152,206		(661,380)		(5,257)		(1,020,650)
Net income (loss)	687,462		(1,976,211)		67,103		(2,947,474)
Less: Net income attributable to noncontrolling interests	3,792		601		8,120		25
Net income (loss) attributable to EQT Corporation	$	683,670	$	(1,976,812)	$	58,983	$	(2,947,499)

Income (loss) per share of common stock attributable to EQT Corporation:
Basic:
Weighted average common stock outstanding	369,987		356,792		371,308		304,961
Net income (loss)	$	1.85	$	(5.54)	$	0.16	$	(9.67)
Diluted:
Weighted average common stock outstanding	403,889		356,792		377,028		304,961
Net income (loss)	$	1.69	$	(5.54)	$	0.16	$	(9.67)

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

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

Three Months Ended
September 30, Nine Months Ended
September 30,
�� 2021 2020 2021 2020
(Thousands)
Net loss $ (1,979,516) $ (600,640) $ (2,957,067) $ (1,030,854)
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax expense: $70, $23, $124 and $71 37 72 198 156
Comprehensive loss (1,979,479) (600,568) (2,956,869) (1,030,698)
Less: Comprehensive income attributable to noncontrolling interests 601 — 25 —
Comprehensive loss attributable to EQT Corporation $ (1,980,080) $ (600,568) $ (2,956,894) $ (1,030,698)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021

	(Thousands)
Net income (loss)	$	687,462	$	(1,976,211)	$	67,103	$	(2,947,474)
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax expense: $20, $70, $61 and $124	63		37		190		198
Comprehensive income (loss)	687,525		(1,976,174)		67,293		(2,947,276)
Less: Comprehensive income attributable to noncontrolling interests	3,792		601		8,120		25
Comprehensive income (loss) attributable to EQT Corporation	$	683,733	$	(1,976,775)	$	59,173	$	(2,947,301)

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


		September 30, 2021		December 31, 2020			September 30, 2022		December 31, 2021

		(Thousands)					(Thousands)
ASSETS	ASSETS					ASSETS
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	$	22,792	$	18,210	Cash and cash equivalents	$	87,541	$	113,963
Accounts receivable (less provision for doubtful accounts: $783 and $6,239)		1,132,364		566,552
Accounts receivable (less provision for doubtful accounts: $357 and $321)						Accounts receivable (less provision for doubtful accounts: $357 and $321)	1,938,717		1,438,031
Derivative instruments, at fair value	Derivative instruments, at fair value	1,428,073		527,073		Derivative instruments, at fair value	1,466,800		543,337
Prepaid expenses and other	Prepaid expenses and other	757,670		103,615		Prepaid expenses and other	409,409		191,435
Total current assets	Total current assets	3,340,899		1,215,450		Total current assets	3,902,467		2,286,766

Property, plant and equipment	Property, plant and equipment	25,890,930		21,995,249		Property, plant and equipment	26,978,974		26,016,092
Less: Accumulated depreciation and depletion	Less: Accumulated depreciation and depletion	7,109,820		5,940,984		Less: Accumulated depreciation and depletion	8,846,789		7,597,172
Net property, plant and equipment	Net property, plant and equipment	18,781,110		16,054,265		Net property, plant and equipment	18,132,185		18,418,920

Contract asset	Contract asset	410,000		410,000		Contract asset	29,250		410,000
Other assets	Other assets	479,711		433,754		Other assets	477,235		491,702
Total assets	Total assets	$	23,011,720	$	18,113,469	Total assets	$	22,541,137	$	21,607,388

LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current liabilities:	Current liabilities:					Current liabilities:
Current portion of debt	Current portion of debt	$	12,441	$	154,161	Current portion of debt	$	421,987	$	1,060,970
Accounts payable	Accounts payable	1,183,194		705,461		Accounts payable	1,678,083		1,339,251
Derivative instruments, at fair value	Derivative instruments, at fair value	5,715,608		600,877		Derivative instruments, at fair value	4,214,888		2,413,608
Other current liabilities	Other current liabilities	317,110		301,911		Other current liabilities	322,944		372,412
Total current liabilities	Total current liabilities	7,228,353		1,762,410		Total current liabilities	6,637,902		5,186,241

Credit facility borrowings		704,000		300,000

Senior notes	Senior notes	5,377,439		4,371,467		Senior notes	4,257,359		4,435,782
Note payable to EQM Midstream Partners, LP	Note payable to EQM Midstream Partners, LP	95,728		99,838		Note payable to EQM Midstream Partners, LP	89,973		94,320
Deferred income taxes	Deferred income taxes	347,392		1,371,967		Deferred income taxes	893,139		907,306
Other liabilities and credits	Other liabilities and credits	999,083		945,057		Other liabilities and credits	1,004,163		1,012,740
Total liabilities	Total liabilities	14,751,995		8,850,739		Total liabilities	12,882,536		11,636,389

Equity:	Equity:					Equity:
Common stock, no par value, shares authorized: 640,000, shares issued: 378,793 and 280,003		10,180,652		8,241,684
Treasury stock, shares at cost: 1,041 and 1,658		(18,202)		(29,348)
Retained earnings		(1,908,833)		1,048,259
Common stock, no par value, shares authorized: 640,000, shares issued: 368,194 and 377,432						Common stock, no par value, shares authorized: 640,000, shares issued: 368,194 and 377,432	9,923,539		10,071,820
Treasury stock, shares at cost: 32 and 1,033						Treasury stock, shares at cost: 32 and 1,033	(579)		(18,046)
Accumulated deficit						Accumulated deficit	(299,577)		(94,400)
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(5,157)		(5,355)		Accumulated other comprehensive loss	(4,421)		(4,611)
Total common shareholders' equity	Total common shareholders' equity	8,248,460		9,255,240		Total common shareholders' equity	9,618,962		9,954,763
Noncontrolling interests in consolidated subsidiaries		11,265		7,490
Noncontrolling interest in consolidated subsidiaries						Noncontrolling interest in consolidated subsidiaries	39,639		16,236
Total equity	Total equity	8,259,725		9,262,730		Total equity	9,658,601		9,970,999
Total liabilities and equity	Total liabilities and equity	$	23,011,720	$	18,113,469	Total liabilities and equity	$	22,541,137	$	21,607,388

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED)

Nine Months Ended September 30,
2021 2020
(Thousands)
Cash flows from operating activities:
Net loss $ (2,957,067) $ (1,030,854)
Adjustments to reconcile net loss to net cash provided by operating activities:
Deferred income tax benefit (1,024,699) (182,244)
Depreciation and depletion 1,200,280 1,021,649
Amortization of intangible assets — 22,433
Gain/loss on sale/exchange of long-lived assets and impairment and expiration of leases 65,086 248,217
Gain on Equitrans Share Exchange — (187,223)
(Income) loss from investments (66,861) 303,844
Loss on debt extinguishment 9,756 20,712
Share-based compensation expense 20,822 15,226
Amortization, accretion and other 32,095 25,236
Loss on derivatives not designated as hedges 4,791,582 11,320
Cash settlements (paid) received on derivatives not designated as hedges (729,445) 813,218
Net premiums paid on derivative instruments (53,429) (53,473)
Changes in other assets and liabilities:
Accounts receivable (404,442) 139,713
Accounts payable 276,509 (62,853)
Income tax receivable and payable (27,055) 248,101
Other current assets (642,554) (140,466)
Other items, net 924 (80,979)
Net cash provided by operating activities 491,502 1,131,577
Cash flows from investing activities:
Capital expenditures (706,938) (788,384)
Cash paid for acquisitions, net of cash acquired (1,021,510) —
Proceeds from sale of assets — 113,236
Cash received for Equitrans Share Exchange — 52,323
Other investing activities 13,590 117
Net cash used in investing activities (1,714,858) (622,708)
Cash flows from financing activities:
Proceeds from credit facility borrowings 6,216,000 1,772,750
Repayment of credit facility borrowings (5,812,000) (1,822,250)
Proceeds from issuance of debt 1,000,000 2,250,000
Debt issuance costs and Capped Call Transactions (See Note 6) (19,713) (65,102)
Repayment and retirement of debt (146,005) (2,609,785)
Premiums paid on debt extinguishment (9,599) (17,150)
Contributions from noncontrolling interests 3,750 —
Dividends paid — (7,664)
Cash paid for taxes related to net settlement of share-based incentive awards (3,805) (596)
Other financing activities (690) —
Net cash provided by (used in) financing activities 1,227,938 (499,797)
Net change in cash and cash equivalents 4,582 9,072
Cash and cash equivalents at beginning of period 18,210 4,596
Cash and cash equivalents at end of period $ 22,792 $ 13,668


	Nine Months Ended September 30,
	2022		2021

	(Thousands)
Cash flows from operating activities:
Net income (loss)	$	67,103	$	(2,947,474)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Deferred income tax benefit	(14,229)		(1,020,094)
Depreciation and depletion	1,269,936		1,200,280
Impairments of long-lived assets and gain on sale/exchange of long-lived assets	280,026		65,086
Loss (income) from investments	14,331		(66,861)
Loss on debt extinguishment	139,085		9,756
Share-based compensation expense	33,706		20,822
Amortization, accretion and other	63,687		17,897
Loss on derivatives	5,550,028		4,791,582
Net cash settlements paid on derivatives	(4,672,998)		(729,445)
Net premiums received (paid) on derivative instruments	13,809		(53,429)
Changes in other assets and liabilities:
Accounts receivable	(507,050)		(404,442)
Accounts payable	343,925		276,509
Other current assets	(27,960)		(642,554)
Other items, net	(151,641)		(26,131)
Net cash provided by operating activities	2,401,758		491,502
Cash flows from investing activities:
Capital expenditures	(1,047,475)		(706,938)
Deposit on acquisition	(150,000)		—
Cash paid for acquisitions	—		(1,021,510)
Proceeds from sale/exchange of assets	5,394		—
Proceeds from sale of investment shares	189,249		—
Other investing activities	(14,306)		13,590
Net cash used in investing activities	(1,017,138)		(1,714,858)
Cash flows from financing activities:
Proceeds from credit facility borrowings	10,242,000		6,216,000
Repayment of credit facility borrowings	(10,242,000)		(5,812,000)
Proceeds from issuance of debt	—		1,000,000
Debt issuance costs	(17,852)		(19,713)
Repayment and retirement of debt	(833,029)		(146,005)
Premiums paid on debt extinguishment	(135,248)		(9,599)
Dividends paid	(148,765)		—
Cash paid for taxes related to net settlement of share-based incentive awards	(24,193)		(3,805)
Proceeds from exercises under employee compensation plans	15,505		—
Repurchase and retirement of common stock	(270,345)		—
Net contribution from noncontrolling interest	4,050		3,750
Other financing activities	(1,165)		(690)
Net cash (used in) provided by financing activities	(1,411,042)		1,227,938
Net change in cash and cash equivalents	(26,422)		4,582
Cash and cash equivalents at beginning of period	113,963		18,210
Cash and cash equivalents at end of period	$	87,541	$	22,792

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

See Note 1 for supplemental cash flow information.

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)

Common Stock Accumulated Other
Comprehensive Loss (a) Noncontrolling Interests in Consolidated Subsidiaries
Shares No Par
Value Treasury Stock Retained Earnings Total Equity
(Thousands, except per share amounts)
Balance at July 1, 2020 255,290 $ 7,889,072 $ (30,341) $ 1,585,211 $ (5,115) $ — $ 9,438,827
Comprehensive loss, net of tax:
Net loss (600,640) (600,640)
Other postretirement benefits liability adjustment, net of tax expense: $23 72 72
Share-based compensation plans 55 6,556 994 7,550
Balance at September 30, 2020 255,345 $ 7,895,628 $ (29,347) $ 984,571 $ (5,043) $ — $ 8,845,809
Balance at July 1, 2021 278,858 $ 8,245,752 $ (20,084) $ 71,284 $ (5,194) $ 10,664 $ 8,302,422
Comprehensive loss, net of tax:
Net (loss) income (1,980,117) 601 (1,979,516)
Other postretirement benefits liability adjustment, net of tax expense: $70 37 37
Share-based compensation plans 105 9,495 1,882 11,377
Alta Acquisition (See Note 10) 98,789 1,925,405 1,925,405
Balance at September 30, 2021 377,752 $ 10,180,652 $ (18,202) $ (1,908,833) $ (5,157) $ 11,265 $ 8,259,725


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

	(Thousands, except per share amounts)
Balance at July 1, 2021	278,858	$	8,149,607	$	(20,084)	$	85,939	$	(5,194)	$	10,664	$	8,220,932
Comprehensive loss, net of tax:
Net (loss) income						(1,976,812)				601		(1,976,211)
Other postretirement benefits liability adjustment, net of tax expense: $70								37				37
Share-based compensation plans	105	9,495		1,882								11,377
Alta Acquisition (Note 9)	98,789	1,925,405										1,925,405
Balance at September 30, 2021	377,752	$	10,084,507	$	(18,202)	$	(1,890,873)	$	(5,157)	$	11,265	$	8,181,540

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 (Note 6)	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

Common shares authorized: 640,000. Preferred shares authorized: 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.

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)

Common Stock Accumulated Other
Comprehensive Loss (a) Noncontrolling Interests in Consolidated Subsidiaries
Shares No Par
Value Treasury Stock Retained Earnings Total Equity
(Thousands, except per share amounts)
Balance at January 1, 2020 255,171 $ 7,818,205 $ (32,507) $ 2,023,089 $ (5,199) $ — $ 9,803,588
Comprehensive loss, net of tax:
Net loss (1,030,854) (1,030,854)
Other postretirement benefits liability adjustment, net of tax expense: $71 156 156
Dividends ($0.03 per share) (7,664) (7,664)
Share-based compensation plans 174 13,778 3,160 16,938
Equity component of convertible senior notes (See Note 6) 63,645 63,645
Balance at September 30, 2020 255,345 $ 7,895,628 $ (29,347) $ 984,571 $ (5,043) $ — $ 8,845,809
Balance at January 1, 2021 278,345 $ 8,241,684 $ (29,348) $ 1,048,259 $ (5,355) $ 7,490 $ 9,262,730
Comprehensive loss, net of tax:
Net (loss) income (2,957,092) 25 (2,957,067)
Other postretirement benefits liability adjustment, net of tax expense: $124 198 198
Share-based compensation plans 618 13,563 11,146 24,709
Contributions from noncontrolling interests 3,750 3,750
Alta Acquisition (See Note 10) 98,789 1,925,405 1,925,405
Balance at September 30, 2021 377,752 $ 10,180,652 $ (18,202) $ (1,908,833) $ (5,157) $ 11,265 $ 8,259,725


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

	(Thousands, except per share amounts)
Balance at January 1, 2021	278,345	$	8,145,539	$	(29,348)	$	1,056,626	$	(5,355)	$	7,490	$	9,174,952
Comprehensive loss, net of tax:
Net (loss) income						(2,947,499)				25		(2,947,474)
Other postretirement benefits liability adjustment, net of tax expense: $124								198				198
Share-based compensation plans	618	13,563		11,146								24,709
Contribution from noncontrolling interest										3,750		3,750
Alta Acquisition (Note 9)	98,789	1,925,405										1,925,405
Balance at September 30, 2021	377,752	$	10,084,507	$	(18,202)	$	(1,890,873)	$	(5,157)	$	11,265	$	8,181,540

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 (Note 6)	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

Common shares authorized: 640,000. Preferred shares authorized: 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, ~~2021~~2022 and December 31, ~~2020,~~2021, the results of its operations and equity for the three and nine month periods ended September 30, ~~2021~~2022 and ~~2020~~2021 and its cash flows for the nine month periods ended September 30, ~~2021~~2022 and ~~2020.~~2021. 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," "EQT Corporation" and "the Company" refer collectively to EQT Corporation and its consolidated subsidiaries.

~~The Condensed Consolidated Balance Sheet at December 31, 2020 has been derived from~~These financial statements and accompanying notes should be read in conjunction with the audited consolidated financial statements ~~at that date. For further information, refer to the Consolidated Financial Statements~~ and accompanying notes included in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021.

Recently Issued Accounting Standards

In ~~December 2019,~~August 2020, the Financial Accounting Standards Board ~~(FASB)~~ issued Accounting Standards Update (ASU) ~~2019-12,~~ ~~Income Taxes: Simplifying the Accounting for Income Taxes. This ASU simplifies accounting for income taxes by eliminating certain exceptions to Accounting Standards Codification (ASC) 740,~~ ~~Income Taxes,~~ related to the general approach for intraperiod tax allocation, methodology for calculating income taxes in an interim period and recognition of deferred taxes when there are investment ownership changes. In addition, this ASU simplifies aspects of accounting for franchise taxes and interim period effects of enacted changes in tax laws or rates and provides clarification on accounting for transactions that result in a step up in the tax basis of goodwill and allocation of consolidated income tax expense to separate financial statements of entities not subject to income tax. This ASU is effective for fiscal years beginning after December 15, 2020, including interim periods within those fiscal years, and early adoption is permitted. The Company adopted this ASU in the first quarter of 2021 with no material changes to its financial statements or disclosures.

~~In August 2020, the FASB issued ASU~~ 2020-06, Debt with Conversion and Other Options and Derivatives and Hedging: Accounting for Convertible Instruments and Contracts in an Entity's Own Equity. This ASU simplifies accounting for convertible instruments by removing certain separation models for convertible instruments. For convertible instruments with conversion features that are not accounted for as derivatives under ~~ASC~~Accounting Standards Codification 815 or that do not result in substantial premiums accounted for as paid-in capital, the convertible instrument's embedded conversion features are no longer separated from the host contract. Consequently, and as long as no other feature requires bifurcation and recognition as a derivative, the convertible instrument is accounted for as a single liability measured at its amortized cost. ~~This~~Under ASU ~~also amends~~2020-06, entities are required to use the if-converted method to calculate the impact of convertible instruments on ~~the calculation of~~ diluted earnings per share (EPS) ~~and~~. The if-converted method assumes share settlement of the instrument, which increases the number of potentially dilutive securities used to calculate diluted EPS. This ASU also adds several new disclosure requirements. ~~This ASU is effective for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years.~~

The Company ~~plans to adopt~~adopted this ASU oneffective as of January 1, 2022 using the full retrospective method of adoption. The ~~Company is evaluating~~following tables present the impact ~~this standard will have~~of the adoption of ASU 2020-06 on ~~its financial statements and disclosures.~~the Company's previously reported historical results. See Note 6 for discussion of the Convertible Notes (defined in Note 6).


	Three Months Ended September 30, 2021
	As Reported		ASU 2020-06 Adoption Adjustment		As Adjusted

	(Thousands, except per share amounts)
Interest expense	$	80,349	$	(4,840)	$	75,509
Income tax benefit	(662,915)		1,535		(661,380)

Net loss	(1,979,516)		3,305		(1,976,211)
Less: Net income attributable to noncontrolling interest	601		—		601
Net loss attributable to EQT Corporation	$	(1,980,117)	$	3,305	$	(1,976,812)

Basic and diluted:
Weighted average common stock outstanding (a)	356,792		—		356,792
Loss per share of common stock attributable to EQT Corporation	$	(5.55)	$	0.01	$	(5.54)

(a)For the three months ended September 30, 2021, diluted weighted average common stock outstanding did not change because the potentially dilutive securities had an anti-dilutive effect on loss per share.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)


	Nine Months Ended September 30, 2021
	As Reported		ASU 2020-06 Adoption Adjustment		As Adjusted

	(Thousands, except per share amounts)
Interest expense	$	232,434	$	(14,198)	$	218,236
Income tax benefit	(1,025,255)		4,605		(1,020,650)

Net loss	(2,957,067)		9,593		(2,947,474)
Less: Net income attributable to noncontrolling interest	25		—		25
Net loss attributable to EQT Corporation	$	(2,957,092)	$	9,593	$	(2,947,499)

Basic and diluted:
Weighted average common stock outstanding (a)	304,961		—		304,961
Loss per share of common stock attributable to EQT Corporation	$	(9.70)	$	0.03	$	(9.67)

(a)For the nine months ended September 30, 2021, diluted weighted average common stock outstanding did not change because the potentially dilutive securities had an anti-dilutive effect on loss per share.


	December 31, 2021
	As Reported		ASU 2020-06 Adoption Adjustment		As Adjusted

	(Thousands)
Current portion of debt (a)	$	954,900	$	106,070	$	1,060,970
Deferred income taxes	938,612		(31,306)		907,306
Common stock, no par value	10,167,963		(96,143)		10,071,820
Accumulated deficit	(115,779)		21,379		(94,400)

(a)Pursuant to the terms of the Convertible Notes indenture, a sale price condition for conversion of the Convertible Notes was satisfied as of December 31, 2021, and, accordingly, holders of the Convertible Notes were permitted to convert any of their Convertible Notes at their option at any time during the three months ended March 31, 2022, subject to all terms and conditions set forth in the Convertible Notes indenture. Therefore, as of December 31, 2021, the net carrying value of the Convertible Notes was included in current portion of debt in the Consolidated Balance Sheet.

Certain line items in the Statement of Condensed Consolidated Cash Flows for the nine months ended September 30, 2021 were adjusted to reflect the impact of the adoption of ASU 2020-06; however, the adoption did not impact cash and did not change net cash provided by operating, investing or financing activities.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2021		2020			2022		2021

		(Thousands)					(Thousands)
Cash paid (received) during the period for:
Cash paid during the period for:						Cash paid during the period for:
Interest, net of amount capitalized	Interest, net of amount capitalized	$	220,430	$	145,366	Interest, net of amount capitalized	$	208,239	$	220,430
Income taxes, net	Income taxes, net	22,263		(402,044)		Income taxes, net	10,529		22,263

Non-cash activity during the period for:	Non-cash activity during the period for:					Non-cash activity during the period for:
Increase in right-of-use assets and lease liabilities		$	1,091	$	3,130
Increase in asset retirement costs and obligations	Increase in asset retirement costs and obligations	2,709		9,674		Increase in asset retirement costs and obligations	$	14,102	$	2,709
Capitalization of non-cash equity share-based compensation	Capitalization of non-cash equity share-based compensation	3,728		2,350		Capitalization of non-cash equity share-based compensation	3,923		3,728
Equity issued as consideration for the Alta Acquisition (See Note 10)		1,925,405		—
Increase in right-of-use assets and lease liabilities, net						Increase in right-of-use assets and lease liabilities, net	1,651		1,091
Issuance of common stock for Convertible Notes settlements (Note 6)						Issuance of common stock for Convertible Notes settlements (Note 6)	48		—
Equity issued as consideration for acquisition (Note 9)						Equity issued as consideration for acquisition (Note 9)	—		1,925,405

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.

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 ~~$851.2~~$1,486.8 million and ~~$394.1~~$1,093.9 million in accounts receivable in the Condensed Consolidated Balance Sheets as of September 30, ~~2021~~2022 and December 31, ~~2020,~~2021, respectively.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

The table below provides disaggregated information on the Company's revenues. Certain other revenue contracts ~~that provide for the release of capacity that is not used to transport the Company's produced volume~~ are outside the scope of ASU 2014-09, Revenue from Contracts with Customers. ~~The costs of, and recoveries on, such capacity~~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,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021

		(Thousands)									(Thousands)
Revenues from contracts with customers:	Revenues from contracts with customers:									Revenues from contracts with customers:
Natural gas sales	Natural gas sales	$	1,605,581	$	556,950	$	3,572,046	$	1,698,396	Natural gas sales	$	3,543,706	$	1,605,581	$	9,008,226	$	3,572,046
NGLs sales	NGLs sales	152,046		38,380		354,664		102,897		NGLs sales	134,636		152,046		475,988		354,664
Oil sales	Oil sales	26,423		3,662		66,195		11,672		Oil sales	15,852		26,423		61,815		66,195
Total revenues from contracts with customers	Total revenues from contracts with customers	$	1,784,050	$	598,992	$	3,992,905	$	1,812,965	Total revenues from contracts with customers	$	3,694,194	$	1,784,050	$	9,546,029	$	3,992,905

Other sources of revenue:	Other sources of revenue:									Other sources of revenue:
Loss on derivatives not designated as hedges		(3,257,237)		(427,182)		(4,791,582)		(11,320)
Loss on derivatives										Loss on derivatives	(1,627,296)		(3,257,237)		(5,550,028)		(4,791,582)
Net marketing services and other	Net marketing services and other	8,349		317		23,646		4,613		Net marketing services and other	2,565		8,349		21,860		23,646
Total operating revenues	Total operating revenues	$	(1,464,838)	$	172,127	$	(775,031)	$	1,806,258	Total operating revenues	$	2,069,463	$	(1,464,838)	$	4,017,861	$	(775,031)

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, ~~2021.~~2022. Amounts shown exclude contracts that qualified for the exception to the relative standalone selling price method as of September 30, ~~2021.~~2022.

2021 (a) 2022 2023 Total
(Thousands)
Natural gas sales $ 41,746 $ 8,158 $ 6,794 $ 56,698


	2022 (a)		2023		2024		Total

	(Thousands)
Natural gas sales	$	11,735	$	14,432	$	469	$	26,636

(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.

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 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.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

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

With respect to the derivative commodity instruments held by the Company, the Company hedged portions of its expected sales of production and portions of its basis exposure covering approximately ~~2,554 Bcf~~1,587 billion cubic feet (Bcf) of natural gas and ~~5,146 Mbbl~~1,517 thousand barrels (Mbbl) of NGLs as of September 30, ~~2021~~2022 and ~~1,955~~2,184 Bcf of natural gas and ~~3,462~~3,055 Mbbl of NGLs as of December 31, ~~2020.~~2021. The open positions at both September 30, ~~2021~~2022 and December 31, ~~2020~~2021 had maturities extending through December ~~2027 and December 2024, respectively.~~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) or, 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 ~~S&P~~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 Ratings Service (Fitch).~~Fitch. Anything below these ratings is considered non-investment grade. As of September 30, ~~2021,~~2022, the Company's senior notes were rated "Ba1" by Moody's, ~~and "BB+~~"BBB–" by S~~&P.~~&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, ~~2021~~2022 and December 31, ~~2020,~~2021, the aggregate fair value of all OTC derivative instruments with credit rating risk-related contingent features that were in a net liability position was ~~$1,242.7~~$679.5 million and ~~$137.7~~$594.9 million, respectively, for which the Company deposited and recorded current assets of ~~$332.0~~$142.7 million and ~~$21.1~~$0.1 million, respectively.

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, ~~2021~~2022 and December 31, ~~2020,~~2021, there were no such deposits recorded in the Condensed Consolidated Balance Sheets.

When the Company enters into exchange traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good-faith deposits to guard against the risks associated with changing market conditions. The Company is required to make such deposits based on an established initial margin requirement and the net liability position, if any, of the fair value of the associated contracts. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. When the fair value of such contracts is in a net asset position, the broker may remit funds to the Company. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the contract. The margin requirements are subject to change at the exchanges' discretion. As of September 30, ~~2021~~2022 and December 31, ~~2020,~~2021, the Company recorded ~~$381.4~~$45.2 million and ~~$61.5~~$147.7 million, respectively, of such deposits as current assets in the Condensed Consolidated Balance Sheets.

~~Refer to Note 8 for a discussion of the derivative liability recorded in connection with the Equitrans Share Exchange (defined in Note 8).~~

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

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			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)									(Thousands)
September 30, 2021
September 30, 2022										September 30, 2022
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	1,428,073	$	(1,313,856)	$	—	$	114,217	Asset derivative instruments, at fair value	$	1,466,800	$	(1,404,502)	$	—	$	62,298
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	5,715,608		(1,313,856)		(713,432)		3,688,320		Liability derivative instruments, at fair value	4,214,888		(1,404,502)		(187,933)		2,622,453

December 31, 2020
December 31, 2021										December 31, 2021
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	527,073	$	(328,809)	$	—	$	198,264	Asset derivative instruments, at fair value	$	543,337	$	(468,266)	$	—	$	75,071
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	600,877		(328,809)		(82,552)		189,516		Liability derivative instruments, at fair value	2,413,608		(468,266)		(147,773)		1,797,569

The Consolidated GGA (defined in Note 8) executed in connection with the Equitrans Share Exchange (defined in Note 8) provides for additional 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 September 30, 2022 and December 31, 2021, the derivative liability related to the Henry Hub Cash Bonus had a fair value of approximately $53 million and $111 million, respectively. 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.

During the second quarter of 2020, the Company closed a transaction to sell certain non-strategic assets located in Pennsylvania and West Virginia (the 2020 Divestiture), the purchase and sale agreement for which, among other things, provides for additional cash bonus payments (the Contingent Consideration) payable to the Company of up to $20 million, conditioned upon the three-month average of the NYMEX Henry Hub natural gas settlement price relative to stated floor and target price thresholds beginning on August 31, 2020 and ending on November 30, 2022. As of September 30, 2022 and December 31, 2021, the derivative asset related to the Contingent Consideration had a fair value of approximately $2.0 million and $8.2 million, respectively. During the nine months ended September 30, 2022 and 2021, the Company received cash from the Contingent Consideration of $6.5 million and $5.6 million, respectively. Changes in fair value are recorded in gain on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations. The fair value of the derivative asset related to the Contingent Consideration 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.

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.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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, LIBOR-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 LIBOR-based discount rates.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

~~Notes to the Condensed Consolidated Financial Statements (Unaudited)~~

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


		Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets			Fair value measurements at reporting date using:													Fair value measurements at reporting date using:
				Quoted prices in active markets for identical assets (Level 1)			Significant other observable inputs (Level 2)			Significant unobservable inputs (Level 3)			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)													(Thousands)
September 30, 2021
September 30, 2022														September 30, 2022
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	1,428,073		$	216,702		$	1,211,371		$	—		Asset derivative instruments, at fair value	$	1,466,800		$	315,991		$	1,150,809		$	—
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	5,715,608			460,180			5,255,428			—			Liability derivative instruments, at fair value	4,214,888			222,171			3,992,717			—

December 31, 2020
December 31, 2021														December 31, 2021
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	527,073		$	70,603		$	456,470		$	—		Asset derivative instruments, at fair value	$	543,337		$	66,833		$	476,504		$	—
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	600,877			93,361			507,516			—			Liability derivative instruments, at fair value	2,413,608			126,053			2,287,555			—

The carrying values of cash equivalents, accounts receivable and accounts payable approximate fair value due to their short-term maturities. The December 31, 2021 carrying value of the Company's investment in Equitrans Midstream Corporation (Equitrans Midstream) approximates fair value as Equitrans Midstream is a publicly traded company. In April 2022, the Company sold the remaining balance of its Equitrans Midstream common stock for net proceeds of approximately $189 million. The carrying value of borrowings under the Company's credit facility approximates fair value as the interest rate is based on prevailing market rates. The Company considered all of these fair values to be Level 1 fair value measurements.

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

The Company estimates the fair value of its senior notes using established fair value methodology. Because not all of the Company's senior notes are actively traded, their fair value is a Level 2 fair value measurement. As of September 30, ~~2021~~2022 and December 31, ~~2020,~~2021, the Company's senior notes had a fair value of approximately ~~$6.4~~$5.2 billion and ~~$5.2~~$6.5 billion, respectively, and a carrying value of approximately ~~$5.4~~$4.7 billion and ~~$4.5~~$5.5 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, ~~2021~~2022 and December 31, ~~2020,~~2021, the Company's note payable to EQM had a fair value of approximately ~~$120~~$96 million and ~~$130~~$118 million, respectively, and a carrying value of approximately ~~$101~~$96 million and ~~$105~~$100 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 derivative liability recorded in connection with the Equitrans Share Exchange and the embedded derivative recorded in connection with the 2020 Divestiture. See Note 8 for a discussion of the fair value measurement of the Equitrans Share Exchange (defined in Note 8), Note 9 for a discussion of the fair value measurement of the 2020 Asset Exchange Transactions and 2020 Divestiture (each defined in Note 9) and Note 10 for a discussion of the fair value measurement of the Alta Acquisition (defined in Note 10).contract asset. See Note 1 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 for a discussion of the fair value measurement of the Company's oil and gas properties and other long-lived assets, ~~related to the~~including impairment and expiration of leases.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

5. Income Taxes

For the nine months ended September 30, ~~2021~~2022 and ~~2020,~~2021, 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, ~~2021.~~2022.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

~~Notes to~~For the ~~Condensed Consolidated Financial Statements (Unaudited)~~

~~The~~nine months ended September 30, 2022 and 2021, the Company recorded income tax benefit at an effective tax rate of ~~25.7%~~(8.5)% and ~~22.3%~~25.7%, respectively. The Company's effective tax rate for the nine months ended September 30, ~~2021~~2022 was lower compared to the U.S. federal statutory rate due primarily to a reduction to deferred state taxes from the Pennsylvania law change enacted on July 8, 2022 that lowered the corporate net income tax rate from 9.99% to 8.99% in 2023 and ~~2020, respectively.~~by 0.5% thereafter until the corporate net income tax rate reaches 4.99% in 2031, partly offset by nondeductible repurchase premiums on the Convertible Notes. The Company's effective tax rate for the nine months ended September 30, 2021 was higher compared to the U.S. federal statutory rate due primarily to state taxes, including valuation allowances limiting certain state tax benefits and West Virginia tax legislation enacted on April 13, 2021 that changed the way taxable income is apportioned to West Virginia for tax years beginning on or after January 1, 2022.

On August 16, 2022, President Biden signed into law the Inflation Reduction Act of 2022 (IRA). The IRA establishes a 15% corporate alternative minimum tax for certain corporations and a 1% excise tax on stock repurchases made by publicly traded U.S. corporations. The IRA also includes new and renewed options for energy credits. These changes are effective for tax years beginning after December 31, 2022. The Company is evaluating the impact these changes will have on its financial statements and disclosures.

The Company intends to maintain a valuation allowance on certain of its state net operating loss deferred tax assets (DTAs) until there is sufficient evidence to support a reversal of all or a portion of such allowance. However, given the Company's ~~effective~~anticipated future earnings, the Company believes that there is a reasonable possibility that, in the near term, sufficient positive evidence may become available that supports the release of a portion of the Company's valuation allowance, which would result in the recognition of certain DTAs and a decrease to income tax ~~rate~~expense for the period in which the release is recorded. The exact timing and amount of the valuation allowance release would be subject to change based on the level of profitability that the Company can achieve.

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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, 2022				December 31, 2021
	Principal Value		Carrying Value (a)			Principal Value		Carrying Value (a)

	(Thousands)

Senior notes:
3.00% notes due October 1, 2022	$	—	$	—		$	568,823	$	567,909
7.42% series B notes due 2023	10,000		10,000			10,000		10,000
6.125% notes due February 1, 2025 (b)	915,594		911,883			1,000,000		994,643
1.75% convertible notes due May 1, 2026	414,846		406,232			499,991		487,543
3.125% notes due May 15, 2026	463,354		458,098			500,000		493,157
7.75% debentures due July 15, 2026	115,000		113,094			115,000		112,721
3.90% notes due October 1, 2027	1,234,433		1,228,714			1,250,000		1,243,340
5.00% notes due January 15, 2029	336,454		332,015			350,000		344,835
7.000% notes due February 1, 2030 (b)	730,000		725,071			750,000		744,417
3.625% notes due May 15, 2031	495,165		488,484			500,000		492,669
Note payable to EQM	95,728		95,728			99,838		99,838
Total debt	4,810,574		4,769,319			5,643,652		5,591,072
Less: Current portion of debt (c)	430,601		421,987			1,074,332		1,060,970
Long-term debt	$	4,379,973	$	4,347,332		$	4,569,320	$	4,530,102

(a)For the Company's credit facility and 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 this tranche of the Company's 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 senior notes do not fluctuate based on changes to the credit ratings assigned to its senior notes by Moody's, S&P and Fitch.

(c)As of September 30, 2022, the current portion of debt includes the 7.42% series B notes, the 1.75% convertible notes and a portion of the note payable to EQM. As of December 31, 2021, the current portion of debt includes the 3.00% 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, 2020 was higher compared to the U.S. federal statutory rate due primarily to state taxes, including valuation allowances that limit certain state tax benefits, and the benefit related to the settlement of the Company's 2010, 2011 and 2012 audit with the Internal Revenue Service (IRS). These items were partly offset by valuation allowances provided against federal and state deferred tax assets for the additional unrealized losses on the Company's investment in Equitrans Midstream incurred through September 30, 2020 that, if such investment is sold, would become capital losses. The Company believes it is more likely than not that such additional unrealized losses will not be realized for tax purposes.2022.


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

	(Thousands)
3.00% notes due October 1, 2022	$	568,823	$	5,546	$	7,150	$	581,519
6.125% notes due February 1, 2025	84,406		3,046		2,621		90,073
1.75% convertible notes due May 1, 2026	85,096		127,906		250		213,252
3.125% notes due May 15, 2026	36,646		(2,050)		187		34,783
3.90% notes due October 1, 2027	15,567		(643)		188		15,112
5.00% notes due January 15, 2029	13,546		(445)		195		13,296
7.000% notes due February 1, 2030	20,000		1,428		640		22,068
3.625% notes due May 15, 2031	4,835		(601)		28		4,262

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~~6. Debt~~EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Credit ~~facility~~Facility. The Company has a $2.5 billion credit facility. On ~~April 23, 2021,~~June 28, 2022, the Company entered into ~~an Extension Agreement and First Amendment to Second~~the Third Amended and Restated Credit Agreement (the ~~Extension Agreement~~Third Amendment) with the lenders party thereto and ~~First Amendment),~~PNC Bank, National Association, as administrative agent, swing line lender and L/C issuer, amending and restating the Second Amended and Restated Credit Agreement, dated as of July 31, 2017 ~~among the Company, PNC Bank, National Association, as administrative agent, swing line lender and an L/C issuer, and the other lenders party thereto~~ (the Credit Agreement). The ~~Extension Agreement and First~~Third Amendment, among other things, (i) extends the maturity date of the commitments and loans under the Credit Agreement ~~from July 31, 2022~~ to ~~July 31, 2023,~~June 28, 2027 and provides, at the Company's option, two one-year extensions thereafter, subject to the approval of the lenders, (ii) ~~adds customary provisions~~allows for commitment increases of up to ~~provide for~~$500 million, subject to the ~~eventual replacement~~agreement of ~~LIBOR as a benchmark interest rate~~the Company and new or existing lenders and (iii) ~~adds an additional pricing level~~allows for ~~the Applicable~~Base Rate ~~(as~~Loans, Term SOFR Rate Loans and Swing Line Loans (each defined in the ~~Credit Agreement)~~Third Amendment).

The Company had approximately ~~$553~~$27 million and ~~$791~~$440 million of letters of credit outstanding under its credit facility as of September 30, ~~2021~~2022 and December 31, ~~2020,~~2021, respectively.

Under the Company's credit facility, for the three months ended September 30, ~~2021~~2022 and ~~2020,~~2021, the maximum ~~amounts~~amount of outstanding borrowings ~~were $1,652~~was $1,216 million and ~~$399~~$1,652 million, respectively, the average daily balances were approximately ~~$813~~$717 million and ~~$149~~$813 million, respectively, and interest was incurred at a weighted average annual interest ~~rates~~rate of ~~1.9%~~3.8% and ~~2.2%~~1.9%, respectively. Under the Company's credit facility, for the nine months ended September 30, ~~2021~~2022 and ~~2020,~~2021, the maximum ~~amounts~~amount of outstanding borrowings ~~were $1,652~~was $1,300 million and ~~$399~~$1,652 million, respectively, the average daily balances were approximately $624 million and $525 million, ~~and $90 million,~~ respectively, ~~and interest was incurred at weighted average annual interest rates of 2.0% and 2.5%, respectively.~~

~~Term loan facility.~~ The Company had a $1.0 billion term loan facility that was scheduled to mature in May 2021. On June 30, 2020, the Company used proceeds from the offering of its Convertible Notes (see below), cash from its income tax refunds and proceeds from the 2020 Divestiture (see Note 9) to fully repay its term loan facility. Under the Company's term loan facility, for the period beginning January 1, 2020 and ending June 30, 2020, the average daily balance was approximately $692 million and interest was incurred at a weighted average annual interest rate of ~~2.6%.~~2.8% and 2.0%, respectively.

3.125% ~~senior notes~~Senior Notes and 3.625% ~~senior notes~~Senior Notes.. On May 17, 2021, the Company issued $500 million aggregate principal amount of 3.125% senior notes due May 15, 2026 and $500 million aggregate principal amount of 3.625% senior notes due May 15, 2031. After deducting offering costs of $15.6 million, net proceeds from the sale of the notes of $984.4 million were used to partly fund the Alta Acquisition (defined ~~and described~~ in Note ~~10)~~9). The covenants of the 3.125% senior notes and 3.625% senior notes are consistent with the Company's existing senior unsecured ~~notes. Similar to the Company's 5.00% senior notes due January 2029 issued in November 2020,~~notes; however, the 3.125% senior notes and 3.625% senior notes include an offer to repurchase provision applicable upon the occurrence of certain change of control events specified in the applicable indentures.

~~4.875% senior notes~~. On February 1, 2021, the Company redeemed the remaining $125.1 million aggregate principal amount of its 4.875% senior notes at a total cost of $130.7 million, inclusive of redemption premiums of $4.3 million and accrued but unpaid interest of $1.3 million.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

~~Notes to the Condensed Consolidated Financial Statements (Unaudited)~~

Convertible Notes. OnIn April ~~28,~~ 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. The Convertible Notes were issued in a private offering to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, as amended. After deducting offering costs of $16.9 million and Capped Call Transactions (defined and described below) costs of $32.5 million, the net proceeds from the offering of $450.6 million were used to repay $450 million of the Company's term loan facility borrowings as well as for general corporate purposes.

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 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 ~~5-business-day~~five-business-day period after any ~~5-consecutive-trading-day~~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 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 initial conversion rate for the Convertible Notes is 66.6667 shares of EQT common stock per $1,000 principal amount of the Convertible Notes, which is equivalent to an initial conversion price of $15.00 per share of EQT common stock. The initial conversion price represents a premium of 20% to the $12.50 per share closing price of EQT common stock on April 23, 2020. The conversion rate is subject to adjustment under certain circumstances. In addition, following certain corporate events that occur prior to May 1, 2026 or if the Company delivers 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.

Upon conversion of the 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 common stock or a combination thereof.

Pursuant to the terms of the Convertible Notes indenture, the Sale Price Condition for conversion of the Convertible Notes was satisfied as of June 30, 2021, and, accordingly, holders of Convertible Notes were permitted to convert any of their Convertible Notes, at their option, at any time during the quarter beginning on July 1, 2021 and ending on September 30, 2021, subject to all terms and conditions set forth in the Convertible Notes indenture. During the three months ended September 30, 2021, holders of the Convertible Notes exercised their conversion right with respect to $9 thousand in aggregate principal amount of the Convertible Notes. The Company elected to settle all such conversions by issuing to the converting holders of the Convertible Notes 599 shares of EQT common stock in the aggregate at an average conversion price of $19.64.

The Sale Price Condition for conversion of the Convertible Notes was not satisfied as of September 30, 2021, and, accordingly, holders of the Convertible Notes cannot convert any of their Convertible Notes during the fourth quarter of 2021. Therefore, as of September 30, 2021, the net carrying value of the liability portion of the Convertible Notes was included in senior notes on the Condensed Consolidated Balance Sheet.

Upon conversion of the remaining outstanding Convertible Notes, 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 common stock for amounts that exceed the principal amount of the obligation.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

~~Notes to the Condensed Consolidated Financial Statements (Unaudited)~~

~~The~~ Company may not 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 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.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The initial conversion rate for the Convertible Notes was 66.6667 shares of EQT common stock per $1,000 principal amount of the Convertible Notes, which was equivalent to an initial conversion price of $15.00 per share of EQT common stock. The initial conversion price represents a premium of 20% to the $12.50 per share closing price of EQT common stock on April 23, 2020. The conversion rate is subject to adjustment under certain circumstances. In addition, following certain corporate events that occur prior to May 1, 2026 or if the Company delivers 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.

As a result of the cash dividend the Company paid on its common stock in the first quarter of 2022, effective February 11, 2022, the conversion rate for the Convertible Notes was adjusted to 67.0535 shares of EQT common stock per $1,000 principal amount of the Convertible Notes. As a result of the cash dividend the Company paid on its common stock in the second quarter of 2022, effective May 10, 2022, the conversion rate for the Convertible Notes was adjusted to 67.2836 shares of EQT common stock per $1,000 principal amount of the Convertible Notes. As a result of the cash dividend paid by the Company on its common stock in the third quarter of 2022, effective August 8, 2022, the conversion rate for the Convertible Notes was adjusted to 67.5232 shares of EQT common stock per $1,000 principal amount of the Convertible Notes. Future dividend payments by the Company will result in further adjustments to the conversion rate per share of EQT common stock.

The Sale Price Condition for conversion of the Convertible Notes was satisfied as of December 31, 2021 and September 30, 2022, and, accordingly, holders of the Convertible Notes are permitted to convert any of their Convertible Notes at their option at any time beginning on January 1, 2022 and continuing until December 31, 2022, subject to the terms and conditions set forth in the Convertible Notes indenture. Therefore, as of December 31, 2021 and September 30, 2022, the net carrying value of the Convertible Notes was included in current portion of debt on the Condensed Consolidated Balance Sheets.

The following table summarizes Convertible Notes conversion right exercises from issuance through October 21, 2022. The Company elected to settle all such conversions by issuing to the converting holders shares of EQT common stock.


Settlement Month	Principal Converted		Shares Issued	Average Conversion Price

	(Thousands)
September 2021	$	9	599	$	19.64
March 2022	8		536	33.65
April 2022	26		1,742	34.78
July 2022	5		335	36.91
October 2022	10		674	40.14

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 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 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 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 common stock and an initial capped price of $18.75 per share of EQT common stock, each of which are subject to certain customary ~~adjustments.~~

~~For accounting purposes,~~adjustments, including adjustments as a result of the Company separated the Convertible Notes into liability and equity components. The carrying amount of the liability component was calculated by measuring the fair value of similar debt instruments that do not have associated convertible features. The carrying amount of the equity component, representing the conversion option, was determined by deducting the fair value of the liability component from the principal value of the Convertible Notes. The equity component is not remeasured as long as it continues to meet the condition for equity classification. The excess of the principal amount of the liability component overpaying a dividend on its carrying amount (the debt discount) will be amortized to interest expense over the term of the Convertible Notes, which is approximately 6 years, at an effective interest rate of 8.4%. At inception, the Company recorded the Convertible Notes at fair value of approximately $358.1 million, a net deferred tax liability of $41.0 million and an equity component of $100.9 million.

Issuance costs were allocated to the liability and equity components of the Convertible Notes based on their relative fair values. Issuance costs attributable to the liability component of $12.1 million were recorded as a reduction to the liability component of the Convertible Notes and will be amortized to interest expense over the term of the Convertible Notes at an effective interest rate of 8.4%. Issuance costs attributable to the equity component of $4.8 million, representing the conversion option, were netted with the equity component.common stock.

The Capped Call Transactions are separate from the Convertible Notes. The Capped Call Transactions were recorded in shareholders' equity and were not accounted for as derivatives. The cost to purchase the Capped Call Transactions of $32.5 million was recorded as a reduction to equity and will not be remeasured.

~~For~~Based on the ~~second quarter~~closing stock price of ~~2020,~~EQT common stock of $40.75 on September 30, 2022 and excluding the ~~Convertible Notes had a net shareholders' equity~~ impact of ~~$63.6 million, which consisted of the conversion option equity component of $100.9 million less~~ the Capped Call Transactions, ~~costs~~the if-converted value of ~~$32.5 million and issuance costs attributable to~~ the ~~equity component of $4.8~~Convertible Notes exceeded the principal amount by $727 million.

~~The table below summarizes the net carrying amount of the Convertible Notes, including the unamortized debt discount and debt issuance costs.~~

September 30, 2021 December 31, 2020
(Thousands)
Principal $ 499,991 $ 500,000
Less: Unamortized debt discount 113,960 129,103
Less: Unamortized debt issuance costs 10,188 11,263
Net carrying value of Convertible Notes $ 375,843 $ 359,634

1719

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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


	September 30, 2022		December 31, 2021

	(Thousands)
Principal	$	414,846	$	499,991
Less: Unamortized debt issuance costs	8,614		12,448
Net carrying value of Convertible Notes	$	406,232	$	487,543

Fair value of Convertible Notes (a)	$	1,139,843	$	854,985

(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,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021

		(Thousands)									(Thousands)
Contractual interest expense	Contractual interest expense	$	2,188	$	2,188	$	6,563	$	3,695	Contractual interest expense	$	1,821	$	2,188	$	6,191	$	6,563
Amortization of debt discount		5,143		4,767		15,141		7,998
Amortization of issuance costs	Amortization of issuance costs	374		315		1,075		524		Amortization of issuance costs	574		675		1,945		2,016
Total Convertible Notes interest expense	Total Convertible Notes interest expense	$	7,705	$	7,270	$	22,779	$	12,217	Total Convertible Notes interest expense	$	2,395	$	2,863	$	8,136	$	8,579

~~Based on~~5.678% Senior Notes and 5.700% Senior Notes. On October 4, 2022, the ~~closing stock price~~Company issued $500 million aggregate principal amount of ~~EQT common stock~~5.678% senior notes due October 1, 2025 and $500 million aggregate principal amount of ~~$20.46 on September 30, 2021 and excluding~~5.700% senior notes due April 1, 2028. The Company intends to use the ~~impact~~estimated net proceeds from the sale of the ~~Capped Call Transactions,~~notes of $989.5 million (after deducting estimated offering costs of $10.5 million) to partly fund the ~~if-converted value~~Tug Hill and XcL Midstream Acquisition (defined in Note 9). The covenants of the ~~Convertible Notes exceeded~~5.678% senior notes and 5.700% senior notes are consistent with the Company's existing senior unsecured notes. The 5.678% senior notes and 5.700% senior notes have a special mandatory redemption provision that provides that if the consummation of the Tug Hill and XcL Midstream Acquisition does not occur on or before June 30, 2023 or if the Company notifies the trustee of the notes that it will not pursue consummation of the Tug Hill and XcL Midstream Acquisition, the Company is required to redeem the notes of each series then outstanding at a price equal to 101% of the principal amount of the notes to be redeemed plus accrued and unpaid interest to, but excluding, the redemption date.

Term Loan Facility and Bridge Loan Facility. In connection with the Tug Hill and XcL Midstream Purchase Agreement (defined in Note 9), on September 6, 2022, the Company entered into a debt commitment letter, which was amended and restated on September 20, 2022. Pursuant to such amended and restated debt commitment letter, Royal Bank of Canada, PNC Bank, National Association, Mizuho Bank, Ltd. and certain other financial institutions committed to provide the Company with an unsecured bridge loan facility in an aggregate principal amount of $1.25 billion (the Bridge Loan Facility) and an unsecured term loan facility in an aggregate principal amount of $1.25 billion (the Term Loan Facility), subject to satisfaction of standard conditions. In connection with the closing of the offering of the Company’s 5.678% senior notes and 5.700% senior notes on October 4, 2022, the commitments under the Bridge Loan Facility were automatically reduced by ~~$182 million.~~$989.5 million (the estimated net proceeds from the sale of the notes) in accordance with the terms of the Bridge Loan Facility. As of September 30, 2022, neither the Bridge Loan Facility nor the Term Loan Facility had closed, and, accordingly, commitments thereunder remained undrawn.

7. Earnings (Loss) Per Share

For the three and nine months ended September 30, 2022, potentially dilutive securities, composed of the Company's options, restricted stock, performance awards and stock appreciation rights, of 5,879,634 and 5,719,990, respectively, were included in the Company's calculation of diluted earnings per share.

In periods when the Company reports a net loss, all options, restricted stock, performance awards and stock appreciation rights are excluded from the calculation of diluted weighted average shares outstanding because of their anti-dilutive effect on loss per share. As a result, for the three and nine months ended September 30, 2021, ~~and 2020,~~ all such securities of 7,506,075 and 7,642,451, respectively, were excluded from potentially dilutive securities because of their anti-dilutive effect on ~~EPS. Such~~loss per share.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

In addition, the Company uses the if-converted method to calculate the impact of the Convertible Notes on diluted earnings (loss) per share. For the three months ended September 30, 2022, such potentially dilutive securities ~~for~~of approximately 28.0 million were included in the Company's calculation of diluted earnings per share. For the nine months ended September 30, 2022, such if-converted securities of approximately 31.6 million were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share when considering the numerator adjustments. For both the three and nine months ended September 30, 2021, ~~were 7,506,075 and 7,642,451, respectively, and~~ such if-converted securities ~~for the three and nine months ended September 30, 2020 were 6,671,532 and 6,715,083, respectively.~~

As discussed in Note 6, the Company issued the Convertible Notes during the second quarter of 2020 and, upon conversion of the Convertible Notes, intends to use a combined settlement approach to satisfy its obligation under the Convertible Notes. As such, there is no adjustment to the diluted EPS numerator for the cash-settled portion of the instrument. In addition, for all periods presented, the conversion premium of approximately ~~6.7~~33.3 million ~~shares was~~were excluded from potentially dilutive securities because of ~~its~~their anti-dilutive effect on ~~EPS.~~loss per share. See Notes 1 and 6 for further discussion of the Convertible Notes.

8. ~~Equitrans Share Exchange~~Impairment of Contract Asset

During the first quarter of 2020, the Company sold to Equitrans Midstream ~~a total~~approximately 50% of ~~25,299,752 shares of~~the Company's then-owned equity interest in Equitrans ~~Midstream's common stock~~Midstream in exchange for ~~approximately $52 million in~~a combination of cash and rate relief under certain of the Company's gathering contracts with ~~EQM,~~ 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 ~~EQM~~Equitrans Midstream (the Consolidated GGA). ~~The~~

In addition, 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, on October 4, 2022, the Company received the cash proceeds from the Cash Payment Option.

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 ~~and, beginning on~~inclusive of the Cash Payment Option. During the first quarter of 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 ~~(MVP) in-service date, expects~~due to ~~recognize amortization~~recent court rulings. As a result of the Company's impairment evaluation, the Company recognized impairment of $184.9 million in the Statement of Condensed Consolidated Operations. The impairment reduced the carrying value of the contract asset ~~over a period~~to its estimated fair value as of ~~approximately four years in a manner consistent with the expected timing~~March 31, 2022 of ~~the Company's realization~~$225 million, of ~~the economic benefits of the rate relief.~~

~~The Consolidated GGA provides for additional cash bonus payments (the Henry Hub Cash Bonus) payable by the Company to EQM during the period beginning on the first day of the quarter in~~ which the MVP 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 September 30, 2021 and December 31, 2020, the derivative liability related$196 million was attributable to the ~~Henry Hub~~ Cash ~~Bonus was approximately $109 million and $107 million, respectively. In addition,~~Payment Option provided by the Consolidated GGA ~~provides a cash payment option that grants the Company the right to receive payments from EQM~~and presented in prepaid expenses and other in the ~~event that~~Condensed Consolidated Balance Sheet and $29 million was attributable to the ~~MVP~~residual rate relief realizable upon the in-service date ~~has not occurred prior to January 1, 2022.~~

of the Mountain Valley Pipeline and presented in contract asset in the Condensed Consolidated Balance Sheet. 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. Key assumptions used in the fair value calculation included an estimated production volume forecast, a market-based discount rate and a probability-weighted estimate of the in-service date of the MVP. The fair value of the derivative liability related to the Henry Hub Cash Bonus was based on significant inputs that were 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)~~

~~9. Asset Exchange Transactions and Divestiture~~

~~2020 Asset Exchange Transactions.~~ During the nine months ended September 30, 2020, the Company closed on various acreage trade agreements (collectively, the 2020 Asset Exchange Transactions), pursuant to which the Company exchanged approximately 14,600 aggregate net revenue interest acres across Greene, Allegheny, Westmoreland and Washington Counties, Pennsylvania; Wetzel and Marshall Counties, West Virginia; and Belmont County, Ohio for approximately 14,600 aggregate net revenue interest acres across Greene and Washington Counties, Pennsylvania; Wetzel County, West Virginia; and Belmont County, Ohio. As a result of the 2020 Asset Exchange Transactions, the Company recognized a loss of $11.6 million and $67.2 million in (gain) loss on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations for the three and nine months ended September 30, 2020, respectively. The fair value of leases acquired was based on 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 ~~prices~~weighted average cost of capital.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

9. Acquisitions

Tug Hill and XcL Midstream Acquisition. On September 6, 2022, the Company entered into a purchase agreement with EQT Production Company (a wholly-owned indirect subsidiary of the Company), THQ Appalachia I, LLC (Tug Hill) and THQ-XcL Holdings I, LLC (XcL Midstream) (the Tug Hill and XcL Midstream Purchase Agreement), pursuant to which the Company and EQT Production Company agreed to acquire Tug Hill's upstream assets and XcL Midstream's gathering and processing assets through the acquisition of all of the issued and outstanding membership interests of each of THQ Appalachia I Midco, LLC and THQ-XcL Holdings I Midco, LLC (the Tug Hill and XcL Midstream Acquisition) for ~~comparable acreage.~~consideration of approximately $2.6 billion in cash and 55.0 million shares of EQT common stock, as adjusted pursuant to customary closing purchase price adjustments. The Tug Hill and XcL Midstream Purchase Agreement has an effective date of July 1, 2022. The Tug Hill and XcL Midstream Acquisition is expected to close in the fourth quarter of 2022, subject to regulatory approvals. Upon execution of the Tug Hill and XcL Midstream Purchase Agreement, the Company deposited $150 million into an escrow account, which will be credited toward the cash consideration upon closing of the Tug Hill and XcL Midstream Acquisition and is recorded in other assets in the September 30, 2022 Condensed Consolidated Balance Sheet.

~~2020 Divestiture.~~ Alta Acquisition.On May 11, 2020, the Company closed a transaction to sell certain non-strategic assets located in Pennsylvania and West Virginia (the 2020 Divestiture) for an aggregate purchase price of approximately $125 million in cash, subject to customary purchase price adjustments and the Contingent Consideration defined and discussed below. The Pennsylvania assets sold included 80 Marcellus wells and approximately 33 miles of gathering lines; the West Virginia assets sold included 809 conventional wells and approximately 154 miles of gathering lines. In addition, the 2020 Divestiture relieved the Company of approximately $49 million in asset retirement obligations and other liabilities associated with the sold assets. Proceeds from the sale were used to pay down the Company's term loan facility.

The purchase and sale agreement for the 2020 Divestiture provides for additional cash bonus payments (the Contingent Consideration) payable to the Company of up to $20 million. Such Contingent Consideration is conditioned upon the three-month average of the NYMEX Henry Hub natural gas settlement price relative to stated floor and target price thresholds beginning on August 31, 2020 and ending on November 30, 2022. The Contingent Consideration represents an embedded derivative that is recorded at fair value in the Condensed Consolidated Balance Sheets. The Contingent Consideration had a fair value of approximately $12.9 million and $1.9 million as of September 30, 2021 and December 31, 2020, respectively. During the nine months ended September 30, 2021, the Company received cash from the Contingent Consideration of $5.6 million. Changes in fair value are recorded in (gain) loss on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations. The fair value of the Contingent Consideration 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.

As a result of the 2020 Divestiture, the Company recognized a net loss of $36.8 million, including the impact of the change in fair value of the Contingent Consideration, in (gain) loss on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations during the nine months ended September 30, 2020.

~~10. Acquisitions~~

~~Reliance Asset Acquisition~~

On April 1, 2021, the Company closed on the acquisition of certain oil and gas assets (the Reliance Asset Acquisition) from Reliance Marcellus, LLC (Reliance), pursuant to the Company's exercise of a preferential purchase right that was triggered by Northern Oil and Gas, Inc.'s acquisition of Reliance's Marcellus assets. The total purchase price for the acquisition was approximately $69 million, and the assets acquired consisted of approximately 40 MMcfe per day of current production and 4,100 net acres located in southwest Pennsylvania. The Reliance Asset Acquisition was accounted for as an asset acquisition and, as such, its proceeds were allocated to property, plant and equipment.

~~Alta Acquisition~~

On July 21, 2021, the Company completed its ~~previously announced~~ acquisition (the Alta Acquisition) of Alta Marcellus Development, LLC and ARD Operating, LLC and subsidiaries (together, the Alta Target Entities), pursuant to that certain Membership Interest Purchase Agreement, dated May 5, 2021 (the Alta Purchase Agreement), by and among the Company, EQT Acquisition HoldCo LLC (a wholly-owned indirect subsidiary of the Company), Alta Resources Development, LLC (Alta Resources) and the Alta Target Entities. The Alta Target Entities collectively held all of Alta Resources' upstream and midstream assets and liabilities. The purchase price for the Alta Acquisition consisted of approximately $1.0 billion in cash and 98,789,388 shares of EQT common stock, as adjusted pursuant to customary closing purchase price ~~adjustments set forth in the Alta Purchase Agreement.~~adjustments. The Alta Purchase Agreement has an effective date of January 1, 2021.

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~~EQT CORPORATION AND SUBSIDIARIES~~

~~Notes to the Condensed Consolidated Financial Statements (Unaudited)~~

As a result of the Alta Acquisition, the Company acquired approximately 300,000 net Northeast Marcellus acres, approximately 1.0 Bcfe per day of current net production, approximately 300 miles of midstream gathering systems, approximately 100 miles of a freshwater system and a firm transportation portfolio to premium demand markets.

~~Certain of the acquired midstream gathering systems are not wholly-owned but are operated by the~~The Company ~~pursuant to a construction, ownership and operation agreement, through which the Company is entitled to its pro rata share of revenues, expenses, assets and liabilities.~~

~~Allocation of Purchase Price~~. The Alta Acquisition has been accounted for as a business combination using the acquisition method. The table below summarizes the preliminary purchase price and estimated fair values of assets acquired and liabilities assumed as of July 21, 2021. Certain information necessary to completecompleted the purchase price allocation ~~is not yet available, including, but not limited to, final appraisals~~for the Alta Acquisition during the second quarter of ~~assets acquired and liabilities assumed. The Company expects to complete the purchase price allocation once it has received all necessary information,~~2022, at which time the value of the assets acquired and liabilities assumed ~~will be revised, if necessary.~~


	~~Preliminary Purchase Price Allocation~~
	~~(Thousands)~~
~~Consideration:~~
~~Equity~~	$	~~1,925,405~~
~~Cash~~	~~1,000,000~~
~~Total consideration~~	$	~~2,925,405~~

~~Fair value of assets acquired:~~
~~Cash and cash equivalents~~	$	~~43,199~~
~~Accounts receivable, net~~	~~165,048~~


~~Property, plant and equipment~~	~~3,139,781~~
~~Other assets~~	~~6,309~~
~~Amount attributable to assets acquired~~	$	~~3,354,337~~

~~Fair value of liabilities assumed:~~
~~Accounts payable~~	$	~~131,214~~
~~Derivative instruments, at fair value~~	~~169,744~~
~~Other current liabilities~~	~~13,359~~
~~Other liabilities and credits~~	~~114,615~~

~~Amount attributable to liabilities assumed~~	$	~~428,932~~

were revised. The ~~fair value of the acquired natural gas and oil properties was measured using discounted cash flow valuation techniques based on inputs that are~~purchase accounting adjustments recorded in 2022 were 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 were 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 gathering systems 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~~material to the ~~Condensed Consolidated Financial Statements (Unaudited)~~

Company's financial statements.

Post-Acquisition Operating Results. The Alta Target Entities contributed the following to the Company's consolidated ~~results for the period from July 21, 2021 through September 30, 2021.~~results.


	July 21, 2021 through September 30, 2021
	(Thousands)
Sales of natural gas, NGLs and oil	$	251,129
Loss on derivatives not designated as hedges	(293,840)
Net marketing services and other	2,525
Total operating revenues	$	(40,186)

Net loss	$	(129,779)

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

Unaudited Pro Forma Information. The table below summarizes the Company's results as though the Alta Acquisition had been completed on January 1, ~~2020.~~2021. Certain of Alta Resources' historical amounts were reclassified to conform to the Company's financial presentation of operations. The following unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Alta Acquisition occurred on January 1, ~~2020~~2021 nor are they necessarily indicative of future consolidated results of operations.

Nine Months Ended
September 30,
2021 2020
(Thousands, except per share amounts)
Pro forma sales of natural gas, NGLs and oil $ 4,437,755 $ 2,122,092
Pro forma loss on derivatives not designated as hedges (4,918,616) (20,762)
Pro forma net marketing services and other 28,452 11,095
Pro forma total operating revenues $ (452,409) $ 2,112,425
Pro forma net loss $ (2,950,427) $ (1,090,841)
Pro forma net income attributable to noncontrolling interests 25 —
Pro forma net loss attributable to EQT $ (2,950,452) $ (1,090,841)
Pro forma loss per share (basic) $ (9.67) $ (4.27)
Pro forma loss per share (diluted) $ (9.67) $ (4.27)


	Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021

	(Thousands, except per share amounts)
Pro forma sales of natural gas, NGLs and oil	$	1,839,002	$	4,437,755
Pro forma loss on derivatives	(3,268,035)		(4,918,616)
Pro forma net marketing services and other	7,798		28,452
Pro forma total operating revenues	$	(1,421,235)	$	(452,409)

Pro forma net loss	$	(1,974,059)	$	(2,950,427)
Pro forma net loss attributable to noncontrolling interests	601		25
Pro forma net loss attributable to EQT Corporation	$	(1,974,660)	$	(2,950,452)

Pro forma loss per share (basic and diluted)	$	(5.53)	$	(9.67)

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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.

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.~~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~~including availability of capital to complete these plans and ~~programs);~~programs; total resource potential and drilling inventory duration; projected production and sales volume and growth ~~rates (including liquids production and sales volume and growth rates);~~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 ~~ESG~~environmental, social and governance (ESG) initiatives, and achieve the anticipated results of such initiatives; projected ~~reductions of our~~ gathering and compression rates resulting from our consolidated gas gathering and compression agreement with Equitrans Midstream Corporation (Equitrans Midstream), and the anticipated cost savings and other strategic benefits associated with the execution of such agreement;rates; monetization transactions, including asset sales, joint ventures or other transactions involving our assets, and our planned use of the proceeds from such monetization transactions; potential or pending acquisition transactions, including the Tug Hill and XcL Midstream Acquisition (defined in Note 9 to the Condensed Consolidated Financial Statements), or other strategic transactions, the timing thereof and our ability to achieve the intended operational, financial and strategic benefits from any such transactions, including our acquisition of certain upstream and midstream assets from Alta Resources Development, LLC; the timing and structure of any dispositions of our remaining retained shares of Equitrans Midstream's common stock, and the planned use of the proceeds from any such dispositions;transactions; the amount and timing of any repayments, redemptions or repurchases of our common stock, outstanding debt securities or other debt instruments; our ability to reduce our debt and the timing of such reductions, if any; the projected ~~dividends, if any;~~amount and timing of dividends; projected cash flows and free cash ~~flow;~~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; ~~access to and cost of capital;~~ 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 resources among our strategic opportunities; access to and cost of capital, including rising interest rates; 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; availability and cost of drilling rigs, completion services, equipment, supplies, personnel, oilfield services and water required to execute our exploration and development ~~plans;~~plans, including as a result of inflationary pressures, the COVID-19 pandemic or otherwise; 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;~~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.~~transactions, including the Tug Hill and XcL Midstream Acquisition. These and other risks and uncertainties are described under Item 1A., "Risk Factors" and elsewhere in our Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021, as updated by Part II, Item 1A., "Risk Factors" in this Quarterly Report on Form 10-Q and other documents we 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 we do not intend to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by law.

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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 ~~loss~~income attributable to EQT Corporation for the three months ended September 30, ~~2021~~2022 was ~~$1,980.1~~$683.7 million, ~~$5.55~~$1.69 per diluted share, compared to net loss attributable to EQT Corporation for the same period in ~~2020~~2021 of ~~$600.6~~$1,976.8 million, ~~$2.35~~$5.54 per diluted share. The change was attributable primarily to ~~the loss on derivatives not designated as hedges, increased depreciation and depletion, increased transportation and processing expense and increased other operating expenses, partly offset by~~ increased sales of natural gas, NGLs and oil ~~higher~~and a smaller loss on derivatives, partly offset by income tax ~~benefit~~expense, increased transportation and ~~higher~~processing expense and decreased income from investments.

Net ~~loss~~income attributable to EQT Corporation for the nine months ended September 30, ~~2021~~2022 was ~~$2,957.1~~$59.0 million, ~~$9.70~~$0.16 per diluted share, compared to net loss attributable to EQT Corporation for the same period in ~~2020~~2021 of ~~$1,030.9~~$2,947.5 million, ~~$4.03~~$9.67 per diluted share. The change was attributable primarily to ~~the~~increased sales of natural gas, NGLs and oil, partly offset by decreased income tax benefit, a greater loss on derivatives, ~~not designated as hedges,~~increased transportation and processing expense, the ~~gain on Equitrans Share Exchange (defined and discussed~~impairment of our contract asset (discussed in Note 8 to the Condensed Consolidated Financial Statements) ~~recognized~~and increased loss on debt extinguishment.

Results of operations for 2022 and for the period beginning July 21, 2021 and ending September 30, 2021 include the results of our operation of assets acquired in the ~~first quarter of 2020, increased depreciation~~Alta Acquisition (defined and ~~depletion, increased transportation and processing expense and increased other operating expenses, partly offset by increased sales of natural gas, NGLs and oil, higher income tax benefit,~~discussed in Note 9 to the ~~income from investments, the gain on sale of long-lived assets and decreased impairment and expiration of leases.~~Condensed Consolidated Financial Statements).

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.

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,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021

		(Thousands, unless otherwise noted)									(Thousands, unless otherwise noted)
NATURAL GAS	NATURAL GAS									NATURAL GAS
Sales volume (MMcf)	Sales volume (MMcf)	464,574		348,136		1,249,140		1,043,126		Sales volume (MMcf)	463,856		464,574		1,406,715		1,249,140
NYMEX price ($/MMBtu)	NYMEX price ($/MMBtu)	$	4.02	$	1.97	$	3.23	$	1.88	NYMEX price ($/MMBtu)	$	8.18	$	4.02	$	6.75	$	3.23
Btu uplift	Btu uplift	0.19		0.11		0.17		0.10		Btu uplift	0.44		0.19		0.35		0.17
Natural gas price ($/Mcf)	Natural gas price ($/Mcf)	$	4.21	$	2.08	$	3.40	$	1.98	Natural gas price ($/Mcf)	$	8.62	$	4.21	$	7.10	$	3.40

Basis ($/Mcf) (a)	Basis ($/Mcf) (a)	$	(0.76)	$	(0.48)	$	(0.54)	$	(0.35)	Basis ($/Mcf) (a)	$	(0.97)	$	(0.76)	$	(0.70)	$	(0.54)
Cash settled basis swaps not designated as hedges ($/Mcf)		(0.05)		0.01		(0.05)		0.01
Cash settled basis swaps ($/Mcf)										Cash settled basis swaps ($/Mcf)	(0.05)		(0.05)		(0.08)		(0.05)
Average differential, including cash settled basis swaps ($/Mcf)	Average differential, including cash settled basis swaps ($/Mcf)	$	(0.81)	$	(0.47)	$	(0.59)	$	(0.34)	Average differential, including cash settled basis swaps ($/Mcf)	$	(1.02)	$	(0.81)	$	(0.78)	$	(0.59)
Average adjusted price ($/Mcf)	Average adjusted price ($/Mcf)	$	3.40	$	1.61	$	2.81	$	1.64	Average adjusted price ($/Mcf)	$	7.60	$	3.40	$	6.32	$	2.81
Cash settled derivatives not designated as hedges ($/Mcf)		(1.20)		0.72		(0.49)		0.77
Cash settled derivatives ($/Mcf)										Cash settled derivatives ($/Mcf)	(4.32)		(1.20)		(3.24)		(0.49)
Average natural gas price, including cash settled derivatives ($/Mcf)	Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.20	$	2.33	$	2.32	$	2.41	Average natural gas price, including cash settled derivatives ($/Mcf)	$	3.28	$	2.20	$	3.08	$	2.32
Natural gas sales, including cash settled derivatives	Natural gas sales, including cash settled derivatives	$	1,021,529	$	811,122	$	2,891,452	$	2,513,128	Natural gas sales, including cash settled derivatives	$	1,519,597	$	1,021,529	$	4,335,811	$	2,891,452

LIQUIDS	LIQUIDS									LIQUIDS
NGLs, excluding ethane:	NGLs, excluding ethane:									NGLs, excluding ethane:
Sales volume (MMcfe) (b)	Sales volume (MMcfe) (b)	16,504		10,661		47,262		32,053		Sales volume (MMcfe) (b)	13,841		16,504		43,043		47,262
Sales volume (Mbbl)	Sales volume (Mbbl)	2,751		1,777		7,877		5,342		Sales volume (Mbbl)	2,307		2,751		7,174		7,877
Price ($/Bbl)		$	49.39	$	19.83	$	40.67	$	17.33
Cash settled derivatives not designated as hedges ($/Bbl)		(16.35)		—		(9.82)		(0.17)
Average price, including cash settled derivatives ($/Bbl)		$	33.04	$	19.83	$	30.85	$	17.16
NGLs sales		$	90,877	$	35,227	$	243,057	$	91,648
NGLs price ($/Bbl)										NGLs price ($/Bbl)	$	48.77	$	49.39	$	57.25	$	40.67
Cash settled derivatives ($/Bbl)										Cash settled derivatives ($/Bbl)	(3.78)		(16.35)		(4.45)		(9.82)
Average NGLs price, including cash settled derivatives ($/Bbl)										Average NGLs price, including cash settled derivatives ($/Bbl)	$	44.99	$	33.04	$	52.80	$	30.85
NGLs sales, including cash settled derivatives										NGLs sales, including cash settled derivatives	$	103,789	$	90,877	$	378,811	$	243,057
Ethane:	Ethane:									Ethane:
Sales volume (MMcfe) (b)	Sales volume (MMcfe) (b)	10,546		6,442		26,936		18,540		Sales volume (MMcfe) (b)	8,464		10,546		27,071		26,936
Sales volume (Mbbl)	Sales volume (Mbbl)	1,758		1,074		4,490		3,090		Sales volume (Mbbl)	1,411		1,758		4,512		4,490
Price ($/Bbl)		$	9.22	$	2.94	$	7.64	$	3.35
Ethane price ($/Bbl)										Ethane price ($/Bbl)	$	15.68	$	9.22	$	14.47	$	7.64
Ethane sales	Ethane sales	$	16,202	$	3,153	$	34,296	$	10,339	Ethane sales	$	22,123	$	16,202	$	65,276	$	34,296
Oil:	Oil:									Oil:
Sales volume (MMcfe) (b)	Sales volume (MMcfe) (b)	3,389		899		7,460		3,136		Sales volume (MMcfe) (b)	1,505		3,389		4,629		7,460
Sales volume (Mbbl)	Sales volume (Mbbl)	565		150		1,243		523		Sales volume (Mbbl)	251		565		772		1,243
Price ($/Bbl)		$	46.79	$	24.43	$	53.24	$	22.32
Oil price ($/Bbl)										Oil price ($/Bbl)	$	63.20	$	46.79	$	80.12	$	53.24
Oil sales	Oil sales	$	26,423	$	3,662	$	66,195	$	11,672	Oil sales	$	15,852	$	26,423	$	61,815	$	66,195

Total liquids sales volume (MMcfe) (b)	Total liquids sales volume (MMcfe) (b)	30,439		18,002		81,658		53,729		Total liquids sales volume (MMcfe) (b)	23,810		30,439		74,743		81,658
Total liquids sales volume (Mbbl)	Total liquids sales volume (Mbbl)	5,074		3,001		13,610		8,955		Total liquids sales volume (Mbbl)	3,969		5,074		12,458		13,610
Total liquids sales	Total liquids sales	$	133,502	$	42,042	$	343,548	$	113,659	Total liquids sales	$	141,764	$	133,502	$	505,902	$	343,548

TOTAL	TOTAL									TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)	Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,155,031	$	853,164	$	3,235,000	$	2,626,787	Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,661,361	$	1,155,031	$	4,841,713	$	3,235,000
Total sales volume (MMcfe)	Total sales volume (MMcfe)	495,013		366,138		1,330,798		1,096,855		Total sales volume (MMcfe)	487,666		495,013		1,481,458		1,330,798
Average realized price ($/Mcfe)	Average realized price ($/Mcfe)	$	2.33	$	2.33	$	2.43	$	2.39	Average realized price ($/Mcfe)	$	3.41	$	2.33	$	3.27	$	2.43

(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.

2426

Table of Contents

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 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,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021

		(Thousands, unless otherwise noted)									(Thousands, unless otherwise noted)
Total operating revenues	Total operating revenues	$	(1,464,838)	$	172,127	$	(775,031)	$	1,806,258	Total operating revenues	$	2,069,463	$	(1,464,838)	$	4,017,861	$	(775,031)
Add (deduct):	Add (deduct):									Add (deduct):
Loss on derivatives not designated as hedges		3,257,237		427,182		4,791,582		11,320
Net cash settlements (paid) received on derivatives not designated as hedges		(619,864)		252,089		(729,445)		813,218
Premiums (paid) received for derivatives that settled during the period		(9,155)		2,083		(28,460)		604
Loss on derivatives										Loss on derivatives	1,627,296		3,257,237		5,550,028		4,791,582
Net cash settlements paid on derivatives										Net cash settlements paid on derivatives	(2,033,727)		(619,864)		(4,672,998)		(729,445)
Premiums received (paid) for derivatives that settled during the period										Premiums received (paid) for derivatives that settled during the period	894		(9,155)		(31,318)		(28,460)
Net marketing services and other	Net marketing services and other	(8,349)		(317)		(23,646)		(4,613)		Net marketing services and other	(2,565)		(8,349)		(21,860)		(23,646)
Adjusted operating revenues, a non-GAAP financial measure	Adjusted operating revenues, a non-GAAP financial measure	$	1,155,031	$	853,164	$	3,235,000	$	2,626,787	Adjusted operating revenues, a non-GAAP financial measure	$	1,661,361	$	1,155,031	$	4,841,713	$	3,235,000

Total sales volume (MMcfe)	Total sales volume (MMcfe)	495,013		366,138		1,330,798		1,096,855		Total sales volume (MMcfe)	487,666		495,013		1,481,458		1,330,798
Average realized price ($/Mcfe)	Average realized price ($/Mcfe)	$	2.33	$	2.33	$	2.43	$	2.39	Average realized price ($/Mcfe)	$	3.41	$	2.33	$	3.27	$	2.43

Sales Volume and Revenues
Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 % 2021 2020 %
(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):
Marcellus (a) 449,650 318,740 41.1 1,198,707 958,243 25.1
Ohio Utica 41,226 46,523 (11.4) 125,189 134,728 (7.1)
Other 4,137 875 372.8 6,902 3,884 77.7
Total sales volume (b) 495,013 366,138 35.2 1,330,798 1,096,855 21.3
Average daily sales volume (MMcfe/d) 5,381 3,980 35.2 4,875 4,003 21.8
Operating revenues:
Sales of natural gas, NGLs and oil $ 1,784,050 $ 598,992 197.8 $ 3,992,905 $ 1,812,965 120.2
Loss on derivatives not designated as hedges (3,257,237) (427,182) 662.5 (4,791,582) (11,320) 42,228.5
Net marketing services and other 8,349 317 2,533.8 23,646 4,613 412.6
Total operating revenues $ (1,464,838) $ 172,127 (951.0) $ (775,031) $ 1,806,258 (142.9)

~~(a)Includes Upper Devonian wells.~~

~~(b)NGLs, ethane and oil were converted to Mcfe at a rate of six Mcfe per barrel.~~

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

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

~~Three Months Ended September 30, 2021 Compared to Three Months Ended September 30, 2020~~

~~Sales of natural gas, NGLs and oil.~~ Sales of natural gas, NGLs and oil increased for the three months ended September 30, 2021 compared to the same period in 2020 due to increased sales volume. Average realized price for the three months ended September 30, 2021 compared to the same period in 2020 remained consistent due to higher NYMEX prices and higher liquids prices, offset by lower cash settled derivatives and unfavorable differential. For the three months ended September 30, 2021 and 2020, we paid $619.9 million and received $252.1 million, respectively, of net cash settlements on derivatives not designated as hedges, which are included in average realized price but may not be included in operating revenues.

Sales volume increased primarily as a result of sales volume increases of 74 Bcfe from the assets acquired in the Alta Acquisition (defined and discussed in Note 10 to the Condensed Consolidated Financial Statements), sales volume increases of 34 Bcfe from the assets acquired in the Chevron Acquisition (defined below) and prior period sales volume decreases of 15 Bcfe from the 2020 Strategic Production Curtailments (defined below).

~~The Chevron Acquisition refers to our acquisition of upstream assets from Chevron U.S.A. Inc. in the fourth quarter of 2020.~~

The 2020 Strategic Production Curtailments refers to our strategic decisions to temporarily curtail 2020 production. In May 2020, we temporarily curtailed approximately 1.4 Bcf per day of gross production, equivalent to approximately 1.0 Bcf per day of net production. In July 2020, we began a moderated approach to bring back on-line the curtailed production. In September 2020, we curtailed approximately 0.6 Bcf per day of gross production, equivalent to approximately 0.4 Bcf per day of net production. In October 2020, we began a phased approach to bring back on-line the curtailed production, which was completed in November 2020.

~~Loss on derivatives not designated as hedges.~~ For the three months ended September 30, 2021 and 2020, we recognized a loss on derivatives not designated as hedges of $3,257.2 million and $427.2 million, respectively. The losses were related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.

~~Net marketing services and other.~~ Net marketing services and other increased for the three months ended September 30, 2021 compared to the same period in 2020 due primarily to the liquids uplift realized on gas purchased at the wellhead from other operators and third-party gathering revenues recognized on the midstream assets acquired in the Alta Acquisition.

~~Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020~~

~~Sales of natural gas, NGLs and oil.~~ Sales of natural gas, NGLs and oil increased for the nine months ended September 30, 2021 compared to the same period in 2020 due to increased sales volume and a higher average realized price. Average realized price increased due to higher NYMEX prices and higher liquids prices, partly offset by lower cash settled derivatives and unfavorable differential. For the nine months ended September 30, 2021 and 2020, we paid $729.4 million and received $813.2 million, respectively, of net cash settlements on derivatives not designated as hedges, which are included in average realized price but may not be included in operating revenues.

Sales volume increased primarily as a result of sales volume increases of 101 Bcfe from the assets acquired in the Chevron Acquisition, sales volume increases of 74 Bcfe from the assets acquired in the Alta Acquisition and prior period sales volume decreases of 51 Bcfe from the 2020 Strategic Production Curtailments.

~~Loss on derivatives not designated as hedges.~~ For the nine months ended September 30, 2021 and 2020, we recognized a loss on derivatives not designated as hedges of $4,791.6 million and $11.3 million, respectively. The losses were related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.

~~Net marketing services and other.~~ Net marketing services and other increased for the nine months ended September 30, 2021 compared to the same period in 2020 due primarily to the liquids uplift realized on gas purchased at the wellhead from other operators and third-party gathering revenues recognized on the midstream assets acquired in the Alta Acquisition.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

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

~~Operating Expenses~~

~~The following table presents information on our production-related operating expenses.~~
Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 % 2021 2020 %
(Thousands, unless otherwise noted)
Operating expenses:
Gathering $ 316,612 $ 274,196 15.5 $ 883,378 $ 788,012 12.1
Transmission 129,402 120,681 7.2 384,509 387,358 (0.7)
Processing 48,883 32,814 49.0 136,810 97,791 39.9
Lease operating expenses (LOE), excluding production taxes 32,141 28,758 11.8 84,707 82,675 2.5
Production taxes 25,682 10,912 135.4 67,892 35,704 90.2
Exploration 20,495 3,160 548.6 23,223 4,959 368.3
Selling, general and administrative 49,113 51,654 (4.9) 143,972 129,933 10.8
Production depletion $ 437,367 $ 336,672 29.9 $ 1,187,188 $ 1,007,654 17.8
Other depreciation and depletion 5,509 4,355 26.5 13,092 13,995 (6.5)
Total depreciation and depletion $ 442,876 $ 341,027 29.9 $ 1,200,280 $ 1,021,649 17.5
Per Unit ($/Mcfe):
Gathering $ 0.64 $ 0.75 (14.7) $ 0.66 $ 0.72 (8.3)
Transmission 0.26 0.33 (21.2) 0.29 0.35 (17.1)
Processing 0.10 0.09 11.1 0.10 0.09 11.1
LOE, excluding production taxes 0.06 0.08 (25.0) 0.06 0.08 (25.0)
Production taxes 0.05 0.03 66.7 0.05 0.03 66.7
Exploration 0.04 0.01 300.0 0.02 — —
Selling, general and administrative 0.10 0.14 (28.6) 0.11 0.12 (8.3)
Production depletion 0.88 0.92 (4.3) 0.89 0.92 (3.3)

Three Months Ended September 30, ~~2021~~2022 Compared to Three Months Ended September 30, ~~2020~~2021

~~Gathering.~~ Gathering expense increased on an absolute basis for the three months ended September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume from the assets acquired in the Alta Acquisition and Chevron Acquisition. Gathering expense decreased on a per Mcfe basis for the three months ended September 30, 2021 compared to the same period in 2020 due primarily to a lower gathering rate structure on the assets acquired in the Alta Acquisition and Chevron Acquisition.

~~Transmission.~~ Transmission expense increased on an absolute basis for the three months ended September 30, 2021 compared to the same period in 2020 due primarily to additional capacity acquired as part of the Alta Acquisition and fewer capacity releases on the Tennessee Gas Pipeline. Transmission expense decreased on a per Mcfe basis for the three months ended September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume, some of which, particularly sales volume from assets acquired in the Alta Acquisition and Chevron Acquisition, has lower transmission expense on a per Mcfe basis as compared to our historical transmission portfolio.

~~Processing.~~ Processing expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2021 compared to the same period in 2020 due to increased liquid sales volume due primarily to increased development of liquids-rich areas and increased processed volume from assets acquired in the Chevron Acquisition.


	Three Months Ended September 30,
	2022		2021		Change		% Change

	(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):
Marcellus	456,495		449,650		6,845		1.5
Ohio Utica	30,531		41,226		(10,695)		(25.9)
Other	640		4,137		(3,497)		(84.5)
Total sales volume	487,666		495,013		(7,347)		(1.5)

Average daily sales volume (MMcfe/d)	5,301		5,381		(80)		(1.5)

Operating revenues:
Sales of natural gas, NGLs and oil	$	3,694,194	$	1,784,050	$	1,910,144	107.1
Loss on derivatives	(1,627,296)		(3,257,237)		1,629,941		(50.0)
Net marketing services and other	2,565		8,349		(5,784)		(69.3)
Total operating revenues	$	2,069,463	$	(1,464,838)	$	3,534,301	(241.3)

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

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

~~Production taxes.~~

Sales of natural gas, NGLs and oil. ~~Production taxes~~Sales of natural gas, NGLs and oil increased ~~on an absolute and per Mcfe basis~~ for the three months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due ~~primarily~~ to ~~increased West Virginia severance taxes as~~ a ~~result of increased production from the Chevron Acquisition and~~ higher ~~prices as well as increased Pennsylvania impact fees as a result of higher prices and additional wells acquired in the Alta Acquisition and Chevron Acquisition.~~average realized price, partly offset by decreased sales volume.

~~Exploration.~~ ~~Exploration increased on an absolute and per Mcfe basis for thethree months ended September 30, 2021 compared to the same period in 2020 due primarily to our purchase of seismic data following the completion of the Alta Acquisition.~~

~~Depreciation and depletion.~~ ~~Production depletion expense increased on an absolute basis~~Average realized price for the three months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 increased due to ~~increased sales volume,~~higher NYMEX prices, partly offset by unfavorable cash settled derivatives and unfavorable differential. For the three months ended September 30, 2022 and 2021, we paid $2,033.7 million and $619.9 million, respectively, of net cash settlements on derivatives, which are included in average realized price but may not be included in operating revenues.

Sales volume decreased primarily as a ~~lower annual depletion rate. Production depletion expense decreased on a per Mcfe basis~~result of sales volume decreases from natural decline of producing wells and fewer wells turned-in-line, partly offset by sales volume increases from the assets acquired in the Alta Acquisition. Sales volume for the three months ended September 30, ~~2021 compared~~2022 was negatively impacted by fewer wells turned-in-line as a result of third-party supply chain constraints. Supply chain constraints may continue to impact our future operating revenues. The pending Tug Hill and XcL Midstream Acquisition, which is expected to close in the ~~same period in 2020 due~~fourth quarter of 2022, subject to ~~a lower annual depletion rate.~~regulatory approvals, is expected to add approximately 800 MMcfe per day of sales volume, 20% of which is liquids sales volume.

~~Amortization of intangible assets.~~ ~~Amortization of intangible assets~~Loss on derivatives. ~~for~~For the three months ended September 30, ~~2020 was $7.5 million. Our intangible assets were fully amortized in the fourth quarter of 2020.~~

~~(Gain) loss on sale/exchange of long-lived assets.~~ ~~During the three months ended September 30,~~2022 and 2021, we recognized a gain on sale/exchange of long-lived assets of $0.4 million related primarily to changes in the fair value of the Contingent Consideration from the 2020 Divestiture (defined and discussed in Note 9 to the Condensed Consolidated Financial Statements). During the three months ended September 30, 2020, we recognized a loss on ~~sale/exchange~~derivatives of ~~long-lived assets of $4.7~~$1,627.3 million and $3,257.2 million, respectively, related primarily to ~~the 2020 Asset Exchange Transactions (defined and discussed in Note 9 to the Condensed Consolidated Financial Statements), partly offset by changes~~decreases in the fair market value of ~~the Contingent Consideration from the 2020 Divestiture. See Note 9 to the Condensed Consolidated Financial Statements.~~

~~Impairment~~our NYMEX swaps and ~~expiration of leases.~~ Impairment and expiration of leases for the three months ended September 30, 2021 was $41.1 million compared to $50.4 million for the same period in 2020. The decrease was driven by higher lease expirations in 2020options due to ~~changes~~increases in ~~market conditions.~~

~~Other operating expenses.~~ Other operating expenses for the three months ended September 30, 2021 of $38.8 million were attributable primarily to transaction costs associated with the Alta Acquisition. Other operating expenses for the three months ended September 30, 2020 of $6.5 million were attributable primarily to changes in legal reserves, including settlements and reorganization costs.NYMEX forward prices.

Nine Months Ended September 30, ~~2021~~2022 Compared to Nine Months Ended September 30, ~~2020~~2021


	Nine Months Ended September 30,
	2022		2021		Change		% Change

	(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):
Marcellus	1,377,637		1,198,707		178,930		14.9
Ohio Utica	98,206		125,189		(26,983)		(21.6)
Other	5,615		6,902		(1,287)		(18.6)
Total sales volume	1,481,458		1,330,798		150,660		11.3

Average daily sales volume (MMcfe/d)	5,427		4,875		552		11.3

Operating revenues:
Sales of natural gas, NGLs and oil	$	9,546,029	$	3,992,905	$	5,553,124	139.1
Loss on derivatives	(5,550,028)		(4,791,582)		(758,446)		15.8
Net marketing services and other	21,860		23,646		(1,786)		(7.6)
Total operating revenues	$	4,017,861	$	(775,031)	$	4,792,892	(618.4)

~~Gathering.~~Sales of natural gas, NGLs and oil. ~~Gathering expense~~Sales of natural gas, NGLs and oil increased ~~on an absolute basis~~ for the nine months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due to a higher average realized price and increased sales volume. ~~Gathering expense decreased on a per Mcfe basis~~

Average realized price for the nine months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 increased due ~~primarily~~ to ~~increased sales volume, which resulted in our utilization of lower overrun rates as part of the Consolidated GGA (defined~~higher NYMEX prices and ~~discussed in Note 8 to the Condensed Consolidated Financial Statements),~~higher liquids prices, partly offset by unfavorable cash settled derivatives and ~~a lower gathering rate structure on the assets acquired in the Chevron Acquisition and Alta Acquisition.~~

~~Transmission.~~ ~~Transmission expense decreased on an absolute basis for~~unfavorable differential. For the nine months ended September 30, 2022 and 2021, ~~compared to the same period~~we paid $4,673.0 million and $729.4 million, respectively, of net cash settlements on derivatives, which are included in ~~2020 due primarily to released capacity on, and credits received from, the Texas Eastern Transmission Pipeline~~average realized price but may not be included in 2020 and released capacity on the Tennessee Gas Pipeline, partly offset by additional capacity acquired as part of the Alta Acquisition. Transmission expense decreased on a per Mcfe basis for the nine months ended September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume, some of which, particularly volume from the Chevron Acquisition and Alta Acquisition, has lower transmission expense on a per Mcfe basis as compared to our historical transmission portfolio.operating revenues.

~~Processing.~~ ~~Processing expense~~Sales volume increased ~~on an absolute and per Mcfe basis for the nine months ended September 30, 2021 compared to the same period in 2020 due to increased liquid sales volume due~~ primarily ~~to increased development of liquids-rich areas and increased processed volume from the Chevron Acquisition.~~

~~Production taxes.~~ ~~Production taxes increased on an absolute and per Mcfe basis for the nine months ended September 30, 2021 compared to the same period in 2020 due primarily to increased West Virginia severance taxes~~ as a result of ~~increased West Virginia production~~sales volume increases from the ~~Chevron Acquisition and higher prices as well as increased Pennsylvania impact fees as a result of higher prices and additional wells~~assets acquired in the Alta Acquisition, partly offset by natural decline of producing wells and ~~Chevron Acquisition.~~fewer wells turned-in-line. The pending Tug Hill and XcL Midstream Acquisition, which is expected to close in the fourth quarter of 2022, subject to regulatory approvals, is expected to add approximately 800 MMcfe per day of sales volume, 20% of which is liquids sales volume.

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

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

Loss on derivatives. For the nine months ended September 30, 2022 and 2021, we recognized a loss on derivatives of $5,550.0 million and $4,791.6 million, respectively, related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.

Operating Expenses

Three Months Ended September 30, 2022 Compared to Three Months Ended September 30, 2021


	Three Months Ended September 30,
	2022		2021		Change		% Change

	(Thousands, unless otherwise noted)
Operating expenses:
Gathering	$	337,532	$	316,612	$	20,920	6.6
Transmission	151,425		129,402		22,023		17.0
Processing	52,135		48,883		3,252		6.7
Lease operating expenses (LOE)	39,934		32,141		7,793		24.2
Production taxes	41,851		25,682		16,169		63.0
Exploration	357		20,495		(20,138)		(98.3)
Selling, general and administrative	67,231		49,113		18,118		36.9

Production depletion	$	413,706	$	437,367	$	(23,661)	(5.4)
Other depreciation and depletion	4,989		5,509		(520)		(9.4)
Total depreciation and depletion	$	418,695	$	442,876	$	(24,181)	(5.5)

Per Unit ($/Mcfe):
Gathering	$	0.69	$	0.64	$	0.05	7.8
Transmission	0.31		0.26		0.05		19.2
Processing	0.11		0.10		0.01		10.0
LOE	0.08		0.06		0.02		33.3
Production taxes	0.09		0.05		0.04		80.0
Exploration	—		0.04		(0.04)		(100.0)
Selling, general and administrative	0.14		0.10		0.04		40.0
Production depletion	0.85		0.88		(0.03)		(3.4)

Operating expenses on a per Mcfe basis for the three months ended September 30, 2022 compared to the same period in 2021 were negatively impacted by lower sales volume unless otherwise noted. Sales volume for the three months ended September 30, 2022 was negatively impacted by fewer wells turned-in-line as a result of third-party supply chain constraints. Supply chain constraints and inflationary pressures may continue to impact our future operating expenses.

~~Exploration.~~Gathering. ~~Exploration~~Gathering expense increased on an absolute and per Mcfe basis for the~~nine~~ three months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due primarily to higher gathering rates on certain contracts indexed to price.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the three months ended September 30, 2022 compared to the same period in 2021 due primarily to higher rates on and lower credits received from the Texas Eastern Transmission Pipeline and additional capacity acquired on the Rockies Express Pipeline in September 2021.

LOE. LOE increased on an absolute and per Mcfe basis for the three months ended September 30, 2022 compared to the same period in 2021 due primarily to higher salt water disposal costs.

Production taxes. Production taxes increased on an absolute and per Mcfe basis for the three months ended September 30, 2022 compared to the same period in 2021 due to increased West Virginia severance taxes, which resulted primarily from higher prices.

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

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

Exploration. Exploration decreased on an absolute and per Mcfe basis for the three months ended September 30, 2022 compared to the same period in 2021 due primarily to our prior year purchase of seismic data following the completion of the Alta Acquisition.

Selling, general and administrative. Selling, general and administrative expense increased on an absolute and per Mcfe basis for thethree months ended September 30, 2022 compared to the same period in 2021 due primarily to higher long-term incentive compensation costs as a result of 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 three months ended September 30, 2022 compared to the same period in 2021 due to a lower annual depletion rate and decreased sales volume.

Impairment and expiration of leases. During the three months ended September 30, 2022 and 2021, we recognized impairment and expiration of leases of $20.5 million and $41.1 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 for the three months ended September 30, 2022 of $15.5 million were attributable primarily to changes in legal reserves as well as transaction costs associated with the Tug Hill and XcL Midstream Acquisition. Other operating expenses for the three months ended September 30, 2021 of $38.8 million were attributable primarily to transaction costs associated with the Alta Acquisition.

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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, 2022 Compared to Nine Months Ended September 30, 2021


	Nine Months Ended September 30,
	2022		2021		Change		% Change

	(Thousands, unless otherwise noted)
Operating expenses:
Gathering	$	997,161	$	883,378	$	113,783	12.9
Transmission	447,914		384,509		63,405		16.5
Processing	151,825		136,810		15,015		11.0
LOE	122,577		84,707		37,870		44.7
Production taxes	112,776		67,892		44,884		66.1
Exploration	2,870		23,223		(20,353)		(87.6)
Selling, general and administrative	195,603		143,972		51,631		35.9

Production depletion	$	1,254,566	$	1,187,188	$	67,378	5.7
Other depreciation and depletion	15,370		13,092		2,278		17.4
Total depreciation and depletion	$	1,269,936	$	1,200,280	$	69,656	5.8

Per Unit ($/Mcfe):
Gathering	$	0.67	$	0.66	$	0.01	1.5
Transmission	0.30		0.29		0.01		3.4
Processing	0.10		0.10		—		—
LOE	0.08		0.06		0.02		33.3
Production taxes	0.08		0.05		0.03		60.0
Exploration	—		0.02		(0.02)		(100.0)
Selling, general and administrative	0.13		0.11		0.02		18.2
Production depletion	0.85		0.89		(0.04)		(4.5)

Gathering. Gathering expense increased on an absolute and per Mcfe basis for the nine months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due primarily to increased sales volume from the assets acquired in the Alta Acquisition and higher gathering rates on certain contracts indexed to price, partly offset by the lower gathering rate structure on the assets acquired in the Alta Acquisition.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the nine months ended September 30, 2022 compared to the same period in 2021 due primarily to higher rates on and lower credits received from the Texas Eastern Transmission Pipeline, additional capacity acquired as part of the Alta Acquisition and additional capacity acquired on the Rockies Express Pipeline in September 2021.

Processing. Processing expense increased on an absolute basis for the nine months ended September 30, 2022 compared to the same period in 2021 due to increased volumes that require processing as a result of increased development of liquids-rich areas.

LOE. LOE increased on an absolute and per Mcfe basis for the nine months ended September 30, 2022 compared to the same period in 2021 due primarily to higher salt water disposal costs and additional lease operating costs as a result of the Alta Acquisition.

Production taxes. Production taxes increased on an absolute and per Mcfe basis for the nine months ended September 30, 2022 compared to the same period in 2021 due to increased West Virginia severance taxes, which resulted primarily from higher prices, and increased Pennsylvania impact fees, which resulted from the additional wells acquired in the Alta Acquisition, higher prices and inflation.

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EQT CORPORATION AND SUBSIDIARIES

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

Exploration. Exploration decreased on an absolute and per Mcfe basis for the nine months ended September 30, 2022 compared to the same period in 2021 due primarily to our prior year purchase of seismic data following the completion of the Alta Acquisition.

Selling, general and administrative. Selling, general and administrative expense increased on an absolute and per Mcfe basis for thenine months ended September 30, 2022 compared to the same period in 2021 due primarily to higher long-term incentive compensation costs ~~due to~~as a result of changes in the fair value of ~~awards as well as higher litigation expense.~~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 nine months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due to increased sales volume, partly offset by a lower annual depletion rate. Production depletion expense decreased on a per Mcfe basis for the nine months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due to a lower annual depletion rate.

~~Amortization of intangible assets.~~ ~~Amortization of intangible assetsfor the nine months ended September 30, 2020 was $22.4 million. Our intangible assets were fully amortized in the fourth quarter of 2020.~~

~~(Gain) loss~~Gain on sale/exchange of long-lived assets.During the nine months ended September 30, 2022 and 2021, we recognized a gain on ~~sale/exchange~~sale of long-lived assets of $2.5 million and $18.4 million, respectively, related primarily to changes in the fair value of the Contingent Consideration ~~from~~(defined in Note 3 to the ~~2020 Divestiture.~~ Condensed Consolidated Financial Statements).

Impairment of contract asset. During the nine months ended September 30, ~~2020,~~2022, we recognized ~~a loss on sale/exchange~~impairment of ~~long-lived assets~~our contract asset of ~~$102.7 million, of which $67.2 million related to the 2020 Asset Exchange Transactions and $35.5 million related to asset sales, including the 2020 Divestiture.~~$184.9 million. See Note 98 to the Condensed Consolidated Financial Statements.

Impairment and expiration of leases. ~~Impairment and expiration of leases for~~During the nine months ended September 30, 2022 and 2021, ~~was~~we recognized impairment and expiration of leases of $97.5 million and $83.5 million, ~~compared~~respectively, related to ~~$145.5 million for the same period in 2020. The decrease was driven by higher lease expirations in 2020 due~~leases that we no longer expect to ~~changes in market conditions.~~extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses for the nine months ended September 30, 2022 of $39.0 million were attributable primarily to changes in legal and environmental reserves as well as transaction costs associated with the Tug Hill and XcL Midstream Acquisition. Other operating expenses for the nine months ended September 30, 2021 of $53.4 million were attributable primarily to transaction costs associated with the Alta Acquisition and our acquisition of upstream assets from Chevron ~~Acquisition. Other operating expenses for the nine months ended September 30, 2020 of $11.3 million were attributable primarily to changes~~U.S.A. Inc. in ~~legal reserves, including settlements, reorganization and transaction costs.~~November 2020.

Other Income Statement Items

~~Gain on Equitrans Share Exchange.~~ ~~During the first quarter of 2020, we recognized a gain on the Equitrans Share Exchange of $187.2 million. See Note 8 to the Condensed Consolidated Financial Statements.~~

(Income) loss from investments. For the three months ended September 30, 2022, we recognized income from investments due to equity earnings on our equity method investments, partly offset by a loss on our investment in the Investment Fund (defined in Note 4 to the Condensed Consolidated Financial Statements). For the three months ended September 30, 2021, we recognized income from investments due primarily to a gain on our investment in Equitrans Midstream.

For the nine months ended September 30, 2022, we recognized a loss from investments due to a loss on the sale of our investment in Equitrans Midstream, which resulted from a decrease in Equitrans Midstream's stock price to $8.65 as of April 20, 2022, the date of the final sale of our investment, from $10.34 as of December 31, 2021, partly offset by equity earnings on our equity method investments and a gain on our investment in the Investment Fund. For the nine months ended September 30, 2021, we recognized income from investments due primarily to a gain on our ~~investment~~investments in Equitrans Midstream and income on our investment in a fund that invests in companies developing technology and operating solutions for exploration and production companies. Our investment in Equitrans Midstream fluctuates with changes in Equitrans Midstream's stock price, which was $10.14 and $8.04 as of September 30, 2021 and December 31, 2020, respectively.

~~For~~ the three months ended September 30, 2020, we recognized income on our investment in Equitrans Midstream due to an increase in Equitrans Midstream's stock price. For the nine months ended September 30, 2020, we recognized a loss on our investment in Equitrans Midstream due to a decrease in Equitrans Midstream's stock price as well as a decrease in the number of shares of Equitrans Midstream's common stock that we owned as a result of the Equitrans Share Exchange.Investment Fund.

Dividend and other ~~income.~~income. Dividend and other income decreased for the ~~nine~~three months ended September 30, ~~2021~~2022 compared to the same period in ~~2020~~2021 due primarily to ~~lower~~decreased dividends received ~~from~~on our investment in Equitrans Midstream, ~~driven by a decrease~~which was fully disposed in ~~the number of shares of Equitrans Midstream's common stock that we owned as well as a decrease in the dividend amount per share.~~April 2022.

Loss 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 debt repayment and repurchases discussed in Note 6 to the Condensed Consolidated Financial Statements. During the nine months ended September 30, 2021, we recognized a loss on debt extinguishment of $9.8 million due to fees incurred for a bridge-loan commitment related to the Alta Acquisition and the repayment of our 4.875% senior notes. During the three and nine months ended September 30, 2020, we recognized a loss on debt extinguishment of $3.7 million and $20.7 million, respectively, related to the repayment of our 4.875% senior notes, 2.50% senior notes, floating rate notes and term loan facility. See 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. Interest expense ~~increased~~decreased for the three months ended September 30, 2022 compared to the same period in 2021 due primarily to reduced interest expense on our senior notes driven by lower balances and lower interest rates as well as reduced interest expense due to a reduction of letters of credit balances, partly offset by increased interest expense due primarily to increased interest rates on borrowings under our credit facility. Interest expense decreased for the nine months ended September 30, ~~2021~~2022 compared to the same ~~periods~~period in ~~2020~~2021 due primarily to reduced interest expense on our senior notes driven by lower interest rates and lower balances as well as reduced interest expense due to a reduction of letters of credit balances, partly offset by increased interest expense due primarily to increased interest ~~incurred on new debt,~~rates and higher borrowings under our credit facility and increased interest due to letters of credit issued throughout 2020. These increases were partly offset by lower interest incurred due to debt repayments throughout 2020 and in the first quarter of 2021.facility. See Note 6 to the Condensed Consolidated Financial Statements.

Income tax ~~benefit.~~expense (benefit). 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 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 ~~2021,~~2022, we expect to spend approximately ~~$1,075 million~~$1.400 billion to ~~$1,125 million~~$1.475 billion in total capital expenditures, excluding amounts attributable to noncontrolling ~~interests, which are~~interest and amounts attributable to the assets expected to be ~~funded by operating~~acquired in the Tug Hill and XcL Midstream Acquisition. We expect to fund our capital expenditures with cash ~~flow~~generated from operations and, if required, borrowings under our credit facility. ~~Sales~~Because we are the operator of a high percentage of our developed acreage, the amount and timing of these capital expenditures are largely discretionary. We could choose to defer a portion of these planned 2022 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 2022, we expect our sales volume ~~in 2021 is~~to be 1,925 Bcfe to 1,975 Bcfe, excluding amounts attributable to the assets expected to be ~~1,840 Bcfe to 1,870 Bcfe.~~acquired in the Tug Hill and XcL Midstream Acquisition.

Operating Activities. Net cash provided by operating activities was ~~$492~~$2,402 million for the nine months ended September 30, ~~2021~~2022 compared to ~~$1,132~~$492 million for the same period in ~~2020.~~2021. The ~~decrease~~increase was due primarily to ~~the~~higher cash operating revenues and favorable changes in working capital, partly offset by higher net cash settlements paid on derivatives ~~not designated as hedges, unfavorable timing of working capital payments, including increased payments for collateral~~ and margin deposits associated with our over the counter (OTC) derivative instrument contracts and exchange traded natural gas contracts, and income tax refunds received in the prior year, partly offset by higher cash operating ~~revenues.~~expenses.

During the third quarter of 2022, we elected to exercise the Cash Payment Option pursuant to the Consolidated GGA (each defined and discussed in Note 8 to the Condensed Consolidated Financial Statements), and, on October 4, 2022, we received the cash proceeds from the Cash Payment Option.

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. Refer to Item 1A., "Risk Factors – Natural gas, NGLs and oil price volatility, or a prolonged period of low natural gas, NGLs and oil prices, may have an adverse effect on our revenue, profitability, future rate of growth, liquidity and financial position" in our Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021.

Investing Activities. Net cash used in investing activities was ~~$1,715~~$1,017 million for the nine months ended September 30, ~~2021~~2022 compared to ~~$623~~$1,715 million for the same period in ~~2020.~~2021. The ~~increase~~decrease was due ~~primarily~~ to cash paid for acquisitions in 2021 and proceeds ~~received~~ from the sale of ~~assets and the~~our remaining investment in Equitrans ~~Share Exchange~~Midstream common stock in ~~2020,~~2022, partly offset by ~~lower~~increased capital ~~expenditures.~~expenditures and a deposit on acquisition in 2022.

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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,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021

		(Millions)									(Millions)
Reserve development	Reserve development	$	242	$	176	$	609	$	634	Reserve development	$	271	$	242	$	797	$	609
Land and lease (a)	Land and lease (a)	27		38		81		88		Land and lease (a)	34		27		122		81
Capitalized overhead	Capitalized overhead	15		15		42		39		Capitalized overhead	14		15		39		42
Capitalized interest	Capitalized interest	5		5		13		13		Capitalized interest	7		5		19		13
Other production infrastructure	Other production infrastructure	7		11		31		31		Other production infrastructure	27		7		59		31
Other corporate items		1		3		5		8
Other										Other	3		1		6		5
Total capital expenditures	Total capital expenditures	297		248		781		813		Total capital expenditures	356		297		1,042		781
(Deduct) add back: Non-cash items (b)		(60)		28		(74)		(25)
Add (deduct): Non-cash items (b)										Add (deduct): Non-cash items (b)	6		(60)		5		(74)
Total cash capital expenditures	Total cash capital expenditures	$	237	$	276	$	707	$	788	Total cash capital expenditures	$	362	$	237	$	1,047	$	707

(a)Capital expenditures attributable to noncontrolling ~~interests~~interest were $6.6 million and $0.7 million for the three months ended September 30, 2022 and 2021, respectively, and $11.0 million and $5.7 million for the ~~three and~~ nine months ended September 30, 2022 and 2021, respectively.

(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 as well as the current period estimate.~~accrual.

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~~EQT CORPORATION AND SUBSIDIARIES~~

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

Financing Activities. Net cash ~~provided by~~used in financing activities was ~~$1,228~~$1,411 million for the nine months ended September 30, ~~2021~~2022 compared to net cash ~~used in~~provided by financing activities of ~~$500~~$1,228 million for the same period in ~~2020.~~2021. For the nine months ended September 30, 2022, the primary uses of financing cash flows were repayment and retirement of debt, repurchase and retirement of EQT common stock and payment of dividends. For the nine months ended September 30, 2021, the primary sources of financing cash flows were net proceeds from the issuance of debt and credit facility borrowings, and the primary use of financing cash flows was net repayments of debt. For the nine months ended September 30, 2020, the primary uses of financing cash flows were net repayments of debt and credit facility borrowings, and the primary source of financing cash flows was net proceeds from the issuance of debt.

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

On October 20, 2022, our Board of Directors declared a quarterly cash dividend of $0.15 per share of EQT common stock, payable on December 1, 2022, to shareholders of record at the close of business on November 9, 2022.

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 ~~retire~~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. ~~Additionally, we plan~~See Note 6 to ~~dispose~~the Condensed Consolidated Financial Statements for discussion of ~~our remaining retained shares~~redemptions and repurchases of ~~Equitrans Midstream's common stock and use the proceeds to reduce our~~ debt.

Material Cash Requirements. On September 6, 2022, we entered into the Tug Hill and XcL Midstream Purchase Agreement (defined in Note 9 to the Condensed Consolidated Financial Statements), pursuant to which we agreed to acquire THQ Appalachia I, LLC's upstream assets and THQ-XcL Holdings I, LLC's gathering and processing assets 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 for consideration of approximately $2.6 billion in cash and 55.0 million shares of EQT common stock, as adjusted pursuant to customary closing purchase price adjustments. Upon execution of the Tug Hill and XcL Midstream Purchase Agreement, we deposited $150 million into an escrow account, which will be credited toward the cash consideration upon closing of the Tug Hill and XcL Midstream Acquisition. On October 4, 2022, we issued $500 million aggregate principal amount of 5.678% senior notes due October 1, 2025 and $500 million aggregate principal amount of 5.700% senior notes due April 1, 2028. We intend to use the net proceeds from the sale of the notes, together with borrowings under the Term Loan Facility (defined in Note 6 to the Condensed Consolidated Financial Statements), cash on hand and/or borrowings under our credit facility, to fund the cash consideration for the Tug Hill and XcL Midstream Acquisition. The Tug Hill and XcL Midstream Acquisition is expected to close in the fourth quarter of 2022, subject to regulatory approvals.

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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 October ~~22, 2021.~~21, 2022. 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 ~~further discussion~~a description of what is deemed investment grade.

Rating agency

Senior notes

Outlook

Moody's Investors Service (Moody's)

Ba1

~~Stable~~Positive

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

~~BB+~~BBB–

~~Positive~~Stable

Fitch Ratings Service (Fitch)

~~BB+~~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 ~~lines of~~ credit facility, the interest rate on our senior notes with adjustable rates, the rates available on new long-term debt, our pool of investors and funding sources, the borrowing costs and margin deposit requirements on our ~~OTC~~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.

As of October ~~22, 2021,~~21, 2022, we had sufficient unused borrowing capacity, net of letters of credit, under our credit facility to satisfy any requests for margin deposit or other collateral that our counterparties are permitted to request of us pursuant to our OTC derivative instruments, midstream services contracts and other contracts. As of October ~~22, 2021,~~21, 2022, such assurances could be up to approximately ~~$1.1~~$0.7 billion, inclusive of letters of credit, OTC derivative instrument margin deposits and other collateral posted of approximately ~~$0.8~~$0.3 billion in the aggregate.

During the third quarter of 2021, we amended agreements with six of our largest OTC hedge counterparties to permanently or temporarily reduce or eliminate our margin posting obligations associated with our OTC derivative instruments with such OTC hedge counterparties. The purpose of such amendments was to mitigate the amount of cash collateral that we would otherwise have been required to post based on current NYMEX strip pricing. As of October 22, 2021, our margin balance on our existing hedge portfolio, including both OTC and broker margin balances, was approximately $0.4 billion, compared to approximately $0.5 billion as of June 30, 2021, despite a significant increase in natural gas prices between June 30, 2021 and October 22, 2021. See Notes 3 and 6 to the Condensed Consolidated Financial Statements for further information.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

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

Our debt agreements and other financial obligations contain various provisions that, if not complied with, could result in default or event of default under our credit 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 the 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 credit facility contains financial covenants that require us to have a total debt to total capitalization ratio no greater than 65%. ~~The calculation of this ratio excludes the effects of accumulated other comprehensive income.~~ As of September 30, ~~2021,~~2022, 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 credit 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 ~~through 2024~~ as of October ~~22, 2021.~~

2021 (a) 2022 2023 2024
Swaps:
Volume (MMDth) 314 1,102 166 2
Average Price ($/Dth) $ 2.39 $ 2.59 $ 2.53 $ 2.67
Calls – Net Short:
Volume (MMDth) 86 406 77 15
Average Short Strike Price ($/Dth) $ 2.92 $ 2.98 $ 2.89 $ 3.11
Puts – Net Long:
Volume (MMDth) 53 183 69 15
Average Long Strike Price ($/Dth) $ 2.58 $ 2.68 $ 2.40 $ 2.45
Fixed Price Sales (b):
Volume (MMDth) 17 4 3 —
Average Price ($/Dth) $ 2.49 $ 2.38 $ 2.38 $ —

~~(a)October 1 through December 31.~~

~~(b)~~21, 2022. 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 2022 (a)		Q1 2023		Q2 2023		Q3 2023		Q4 2023		2024
Hedged Volume (MMDth)	290		300		353		356		283		17
Hedged Volume (MMDth/d)	3.2		3.3		3.9		3.9		3.1		—

Swaps – Long
Volume (MMDth)	203		44		41		42		14		—
Avg. Price ($/Dth)	$	6.07	$	6.19	$	4.77	$	4.75	$	4.77	$	—

Swaps – Short
Volume (MMDth)	354		44		41		42		42		2
Avg. Price ($/Dth)	$	3.14	$	2.88	$	2.53	$	2.53	$	2.53	$	2.67

Calls – Long
Volume (MMDth)	54		40		40		40		40		51
Avg. Strike ($/Dth)	$	4.88	$	2.79	$	2.72	$	2.72	$	2.72	$	3.20

Calls – Short
Volume (MMDth)	239		233		300		303		197		66
Avg. Strike ($/Dth)	$	6.32	$	9.46	$	4.85	$	4.85	$	4.69	$	3.11

Puts – Long
Volume (MMDth)	155		299		352		355		255		15
Avg. Strike ($/Dth)	$	5.33	$	4.50	$	3.30	$	3.30	$	3.35	$	2.45

Puts – Short
Volume (MMDth)	17		—		—		—		—		—
Avg. Strike ($/Dth)	$	4.40	$	—	$	—	$	—	$	—	$	—

Fixed Price Sales
Volume (MMDth)	1		1		1		1		—		—
Avg. Price ($/Dth)	$	3.37	$	4.00	$	2.24	$	2.24	$	—	$	—

Option Premiums
Cash Settlement of Deferred Premiums (millions)	$	—	$	(107)	$	(81)	$	(82)	$	(75)	$	—

(a)October 1 through December 31.

For ~~2021~~2022 (October 1 through December 31), ~~2022,~~ 2023 and 2024, we have natural gas sales agreements for approximately 5 ~~MMDth, 18~~ MMDth, 88 MMDth and 11 MMDth, respectively, that include average NYMEX ceiling prices of $3.17, ~~$3.17,~~ $2.84 and $3.21, respectively.

~~During the third quarter~~

Table of ~~2021~~Contents

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and ~~during the period beginning October 1, 2021~~Analysis of Financial Condition and ~~ending October 22, 2021, we purchased $54 million and $18 million, respectively,~~Results of winter calls to reposition our 2021 and 2022 hedge portfolio to enable incremental upside participation in rising natural gas prices and to further mitigate potential incremental margin posting requirements. These positions cover approximately 149 MMDth in 2021 and 2022 and have been excluded from the table above. In addition, during the third quarter of 2021, we purchased $3 million of 2022 swaptions. If exercised, these positions will be converted into approximately 37 MMDth of swaps and have been excluded from the table above.Operations

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

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~~EQT CORPORATION AND SUBSIDIARIES~~

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

Commitments and Contingencies

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts claimed may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We accrue legal and other direct costs related to loss contingencies when actually incurred. We have established reserves 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 ~~currently pending against~~involving us will not materially affect our financial condition, results of operations or liquidity. See Note 16 to the Consolidated Financial Statements and Part I, Item 3., "Legal Proceedings" in our Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 for a discussion of our commitments and contingencies. ~~See also Part II, Item 1., "Legal Proceedings."~~

Recently Issued Accounting Standards

Our recently issued accounting standards are described in Note 1 to the Condensed Consolidated Financial Statements.

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 Item 7., "Management's Discussion and Analysis of Financial Condition and Results of Operations" in our Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021. 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 ~~lease operating expenses,~~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 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 "Commodity Risk Management" under "Capital Resources and Liquidity" in Item 2., "Management's Discussion and Analysis of Financial Condition and Results of Operations." 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.

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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.

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We monitor price and production levels on a continuous basis and make adjustments to quantities hedged as warranted.

A hypothetical decrease of 10% in the ~~market price of~~NYMEX natural gas price on September 30, ~~2021~~2022 and December 31, ~~2020~~2021 would increase the fair value of our natural gas derivative commodity instruments by approximately ~~$836~~$500 million and ~~$501~~$577 million, respectively. A hypothetical increase of 10% in the ~~market price of~~NYMEX natural gas price on September 30, ~~2021~~2022 and December 31, ~~2020~~2021 would decrease the fair value of our natural gas derivative commodity instruments by approximately ~~$838~~$604 million and ~~$495~~$581 million, respectively. For purposes of this analysis, we applied the 10% change in the ~~market price of~~NYMEX natural gas price on September 30, ~~2021~~2022 and December 31, ~~2020~~2021 to our natural gas derivative commodity instruments as of September 30, ~~2021~~2022 and December 31, ~~2020~~2021 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 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 credit facility. None of the interest we pay on our senior notes fluctuates based on changes to market interest rates. A 1% increase in interest rates on the borrowings under our credit facility during the nine months ended September 30, ~~2021~~2022 would have increased interest expense by approximately $5$6 million.

Interest rates on our 6.125% senior notes due 2025 and 7.00% 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 Item 1A., "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, ~~2020.~~2021. 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 ~~19%~~22%, or ~~$1,211~~$1,151 million, of our OTC derivative contracts outstanding at September 30, ~~2021~~2022 had a positive fair value. Approximately ~~47%~~17%, or ~~$456~~$477 million, of our OTC derivative contracts outstanding at December 31, ~~2020~~2021 had a positive fair value.

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As of September 30, ~~2021,~~2022, 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, ~~2021,~~2022, 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 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 NGLs on our behalf.

No one lender of the large group of financial institutions in the syndicate for our credit facility holds more than 10% 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

~~Under the supervision and~~Our management, with the participation of ~~management, including~~ our ~~Principal Executive Officer~~principal executive officer and ~~Principal Financial Officer, an evaluation~~our principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the ~~Securities~~ Exchange ~~Act of 1934, as amended (Exchange~~ Act)), ~~was conducted~~ as of the end of the period covered by this report. Based on that evaluation, ~~the Principal Executive Officer~~our principal executive officer and ~~Principal Financial Officer~~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

During the third quarter of 2021, we completed the Alta Acquisition and started integrating the acquired assets into our internal controls over financial reporting. We will continue to evaluate and monitor the internal controls over financial reporting and will continue to evaluate the operating effectiveness of related key controls.

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 ~~2021~~2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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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 ~~currently pending against~~involving us will not materially affect ~~our financial condition, results of operations or liquidity.~~

~~Environmental Proceedings~~

~~West Virginia Air Quality Permit Violations, Wetzel County, West Virginia~~. In mid-March 2021, we discovered that a small subset of eight of our well pads located in Wetzel County, West Virginia (collectively known as the Stone pads) were out of compliance with the air quality permits and/or permit determinations originally obtained for the well pads. It was originally believed that nine of the well pads were out of compliance, but upon further investigation, it was determined that only eight of the well pads were out of compliance. The Stone pads were permitted to utilize a pipeline to transport condensate generated from the associated wells on the pads. Beginning in late 2019, we began storing condensate generated from the associated wells in production tanks located on the Stone pads and trucking the condensate off site, as opposed to utilizing a pipeline for transportation. This change in procedure resulted in higher emissions being generated on site. In April 2021, we self-disclosed this information to the West Virginia Department of Environmental Protection (WVDEP) and took corrective actions to ensure that the Stone pads are in compliance with their requisite permits. On April 21, 2021, the WVDEP requested additional information from us related to this matter, and we responded to their requests on April 30, 2021. On September 22, 2021, we entered into a Consent Order with the WVDEP, pursuant to which we paid a monetary penalty of $549,575 in September 2021 to resolve this matter. The payment of the monetary penalty and the resolution of this matter did not have a material impact on our financial position, results of operations or liquidity.

~~Other Legal Proceedings~~

~~Hammerhead Gathering Agreement Dispute~~. EQT Corporation and Equitrans Midstream, through certain of our and their subsidiaries, are parties to a gas gathering agreement (the Hammerhead Gathering Agreement) related to Equitrans Midstream's Hammerhead Gas Gathering System. Pursuant to the terms of the Hammerhead Gathering Agreement, if the "In-Service Date" under the Hammerhead Gathering Agreement did not occur on or before October 1, 2020, EQT may terminate the Hammerhead Gathering Agreement and purchase the Hammerhead Gas Gathering System from Equitrans Midstream for an amount equal to 88% of expenses actually incurred and other obligations made or to be incurred by Equitrans Midstream. The "In-Service Date" is defined in the Hammerhead Gathering Agreement as "the later of (i) the first Day of the Month immediately following the date on which Gatherer is first able to provide the Gathering Services to Shipper in accordance with the Hammerhead Gathering Agreement and (ii) the first Day of the Month immediately following the date on which the Interconnect Facilities connecting the Gathering System to the Mountain Valley Pipeline are first able to receive deliveries of the Contract MDQ." Equitrans Midstream claimed the "In-Service Date" commenced on July 22, 2020, despite the Mountain Valley Pipeline not being in service at such time. On September 24, 2020, we initiated an arbitration proceeding against Equitrans Midstream, seeking a declaration that we are entitled to terminate the Hammerhead Gathering Agreement and purchase the Hammerhead Gas Gathering System because the "In-Service Date" would not be achieved by October 1, 2020. The deadline for us to provide notice of our election to terminate the Hammerhead Gathering Agreement and purchase the Hammerhead Gas Gathering System was tolled during the arbitration proceeding.

On October 25, 2021, the arbitration panel issued its ruling. The panel found that, while the "In-Service Date" under the Hammerhead Gathering Agreement did not occur on or before October 1, 2020 and has yet to occur, the failure was excused by force majeure. As a result, the arbitration panel found that (i) EQT is not entitled to exercise the early termination right and (ii) EQT does not have any obligation to pay the $6 million monthly reservation fee under the Hammerhead Gathering Agreement until such time as the "In-Service Date" commences. The resolution of this matter did not have a material impact on our financial position, results of operations or liquidity.

There have been no material updates to the matters previously disclosed in Item 3, "Legal Proceedings" of our Annual Report on Form 10-K for the year ended December 31, 2021.

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Item 1A. Risk Factors

There have been no material changes ~~from~~to the risk factors previously disclosed in Item 1A., "Risk Factors" of our Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021 other than those listed in this section.

Completion of the Tug Hill and XcL Midstream Acquisition is subject to conditions, including certain conditions that may not be satisfied or completed on a timely basis or at all. Failure to complete the Tug Hill and XcL Midstream Acquisition could have material and adverse effects on us.

Completion of the Tug Hill and XcL Midstream Acquisition is subject to a number of conditions, including, among other things, the termination or expiration of the applicable waiting periods under the Hart-Scott-Rodino Antitrust Improvements Act of 1976. Such conditions, some of which are beyond our control, may not be satisfied or waived in a timely manner or at all and therefore make the completion and timing of the completion of the Tug Hill and XcL Midstream Acquisition uncertain. In addition, the Tug Hill and XcL Midstream Purchase Agreement contains certain termination rights for both us and THQ Appalachia I, LLC (Tug Hill) and THQ-XcL Holdings I, LLC (XcL Midstream and, together with Tug Hill, the Tug Hill and XcL Midstream Sellers), which if exercised, will also result in the Tug Hill and XcL Midstream Acquisition not being consummated. Furthermore, the governmental authorities from which the regulatory approvals are required may impose conditions on the completion of the Tug Hill and XcL Midstream Acquisition or require changes to the terms thereof. Such conditions or changes and the process of obtaining regulatory approvals could have the effect of delaying or impeding consummation of the transactions or of imposing additional costs or limitations on us following completion of the Tug Hill and XcL Midstream Acquisition, any of which might have an adverse effect on us following completion of the Tug Hill and XcL Midstream Acquisition.

If the Tug Hill and XcL Midstream Acquisition is not completed, our ongoing business may be adversely affected and, without realizing any of the benefits of having completed the Tug Hill and XcL Midstream Acquisition, we will be subject to a number of risks, including the following:

•we will be required to pay our costs relating to the Tug Hill and XcL Midstream Acquisition, such as legal, accounting and financial advisory expenses, whether or not the transactions are completed;

•time and resources committed by our management to matters relating to the Tug Hill and XcL Midstream Acquisition could otherwise have been devoted to pursuing other beneficial opportunities; and

•the market price of EQT’s common stock could decline to the extent that the current market price reflects a market assumption that the Tug Hill and XcL Midstream Acquisition will be completed.

In addition to the above risks, if the Tug Hill and XcL Midstream Purchase Agreement is terminated and our Board of Directors seeks another acquisition, EQT’s shareholders cannot be certain that we will be able to find a party willing to enter into a transaction as attractive to us as the Tug Hill and XcL Midstream Acquisition. Also, if the Tug Hill and XcL Midstream Purchase Agreement is terminated under certain specified circumstances by the Tug Hill and XcL Midstream Sellers, the $150.0 million deposit placed by us into escrow, to be credited toward the cash consideration payable at the closing of the Tug Hill and XcL Midstream Acquisition, will be disbursed to the Tug Hill and XcL Midstream Sellers.

If the Tug Hill and XcL Midstream Acquisition is consummated, we may be unable to successfully integrate the Tug Hill assets or the XcL Midstream assets into our business or achieve the anticipated benefits of the Tug Hill and XcL Midstream Acquisition.

Our ability to achieve the anticipated benefits of the Tug Hill and XcL Midstream Acquisition will depend in part upon whether we can integrate the Tug Hill and XcL Midstream assets and their operations into our existing business in an efficient and effective manner. We may not be able to accomplish this integration process successfully. The successful acquisition of producing properties, including the Tug Hill and XcL Midstream assets, requires an assessment of several factors, including:

•recoverable reserves;

•future natural gas and oil prices and their appropriate differentials;

•availability and cost of transportation of production to markets;

•availability and cost of drilling equipment and of skilled personnel;

•development and operating costs including access to water and potential environmental and other liabilities; and

•regulatory, permitting and similar matters.

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The accuracy of these assessments is inherently uncertain. In connection with our assessment of Tug Hill’s assets, we have performed a review of the subject properties that we believe to be generally consistent with industry practices. The review was based on our analysis of historical production data, assumptions regarding capital expenditures and anticipated production declines without review by an independent petroleum engineering firm. Data used in such review was furnished by the Tug Hill and XcL Midstream Sellers or obtained from publicly available sources. Our review may not reveal all existing or potential problems or permit us to fully assess the deficiencies and potential recoverable reserves for all of Tug Hill’s assets, and the reserves and production related to the Tug Hill assets may differ materially after such data is reviewed by an independent petroleum engineering firm or further by us. Inspections were not performed on every well, and environmental problems are not necessarily observable even when an inspection is undertaken.

The integration process may be subject to delays or changed circumstances, and we can give no assurance that the Tug Hill assets or the XcL Midstream assets will perform in accordance with our expectations or that our expectations with respect to integration or cost savings as a result of the Tug Hill and XcL Midstream Acquisition will materialize.

We and the subsidiaries of the Tug Hill and XcL Midstream Sellers that we intend to acquire in the Tug Hill and XcL Midstream Acquisition (the Tug Hill and XcL Midstream Companies) will be subject to business uncertainties while the Tug Hill and XcL Midstream Acquisition is pending, which could adversely affect our business.

In connection with the pendency of the Tug Hill and XcL Midstream Acquisition, it is possible that certain persons with whom we or the Tug Hill and XcL Midstream Companies have a business relationship may delay or defer certain business decisions or might decide to seek to terminate, change or renegotiate their relationships with us or the Tug Hill and XcL Midstream Companies, as the case may be, as a result of the Tug Hill and XcL Midstream Acquisition, which could negatively affect our or the Tug Hill and XcL Midstream Companies’ revenues, earnings and cash flows as well as the market price of EQT’s common stock, regardless of whether the Tug Hill and XcL Midstream Acquisition is completed. Also, our and the Tug Hill and XcL Midstream Companies’ ability to attract, retain and motivate employees may be impaired until the Tug Hill and XcL Midstream Acquisition is completed, and our ability to do so may be impaired for a period of time thereafter, as current and prospective employees may experience uncertainty about their roles within the company following the Tug Hill and XcL Midstream Acquisition.

Under the terms of the Tug Hill and XcL Midstream Purchase Agreement, both we and the Tug Hill and XcL Midstream Companies are subject to certain restrictions on the conduct of business prior to the effective time of the Tug Hill and XcL Midstream Acquisition, which may adversely affect our and the Tug Hill and XcL Midstream Companies’ ability to execute certain of our and their business strategies, including the ability in certain cases to modify or enter into certain contracts, acquire or dispose of certain assets, incur or prepay certain indebtedness, incur encumbrances, make capital expenditures or settle claims. Such limitations could negatively affect our and the Tug Hill and XcL Midstream Companies’ businesses and operations prior to the completion of the Tug Hill and XcL Midstream Acquisition.

We will incur significant transaction costs in connection with the Tug Hill and XcL Midstream Acquisition.

We have incurred, and are expected to continue to incur, a number of non-recurring costs associated with the Tug Hill and XcL Midstream Acquisition, combining the operations of the Tug Hill and XcL Midstream assets with ours and achieving desired synergies. These costs have been, and will continue to be, substantial and, in many cases, will be borne by us whether or not the Tug Hill and XcL Midstream Acquisition is completed. A substantial majority of non-recurring expenses will consist of transaction costs and include, among others, fees paid to financial, legal, accounting and other advisors and employee retention, severance and benefit costs. We will also incur costs related to formulating and implementing integration plans. Although we expect that the elimination of duplicative costs, as well as the realization of synergies and efficiencies related to the integration of the Tug Hill and XcL Midstream assets, should allow us to offset these transaction costs over time, this net benefit may not be achieved in the near term or at all.

Securities class action and derivative lawsuits may be brought against us in connection with the Tug Hill and XcL Midstream Acquisition, which could result in substantial costs and may delay or prevent the Tug Hill and XcL Midstream Acquisition from being completed.

Securities class action lawsuits and derivative lawsuits are often brought against public companies that have entered into acquisition, merger or other business combination agreements. Even if such a lawsuit is without merit, defending against these claims can result in substantial costs and divert management time and resources. An adverse judgment could result in monetary damages, which could have a negative impact on our liquidity and financial condition.

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Lawsuits that may be brought against us or our or their directors could also seek, among other things, injunctive relief or other equitable relief, including a request to enjoin us from consummating the Tug Hill and XcL Midstream Acquisition. One of the conditions to the closing of the Tug Hill and XcL Midstream Acquisition is that no court, tribunal or other governmental authority of competent jurisdiction has issued a final and non-appealable order, decree, judgment or law prohibiting the consummation of the Tug Hill and XcL Midstream Acquisition. Consequently, if a plaintiff is successful in obtaining an injunction prohibiting completion of the Tug Hill and XcL Midstream Acquisition, that injunction may delay or prevent the Tug Hill and XcL Midstream Acquisition from being completed within the expected timeframe or at all, which may adversely affect our business, financial position and results of operation.

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

Conversion of Certain Convertible Notes

In September ~~2021,~~2022, we received notices from holders of the Convertible Notes ~~(defined and described in Note 6 to the Condensed Consolidated Financial Statements)~~ requesting the conversion of ~~$9 thousand~~the aggregate principal ~~thereof~~of Convertible Notes stated in the table below (the Converted Notes). ~~On September 15, 2021, we~~We settled the conversion of the ~~Convertible~~Converted Notes ~~with a principal amount of $5 thousand~~ by issuing to the converting holders of the ~~Convertible~~Converted Notes ~~333~~ shares of EQT common stock with a fair market value of approximately $7 thousand. On September 21, 2021, we settled the conversion of the Convertible Notes with a principal amount of $4 thousand by issuing to the converting holders of the Convertible Notes 266 shares of EQT common stock with a fair market value of $5 thousand.stock. Such shares were issued in transactions exempt from registration under the Securities Act ~~of 1933, as amended,~~ 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)
October 3, 2022	$	1	67	$	3
October 4, 2022	9		607	24

Repurchases of Equity Securities

The following table sets forth our repurchases of equity securities registered under Section 12 of the Exchange Act that have occurred during the three months ended September 30, ~~2021.~~2022.

Total number of shares purchased (a) Average price paid
per share Total number of shares purchased as part of
publicly announced plans or programs Approximate dollar value of shares that may
yet be purchased under plans or programs
July 1, 2021 – July 31, 2021 — $ — — —
August 1, 2021 – August 31, 2021 26,246 19.14 — —
September 1, 2021 – September 30, 2021 — — — —
Total 26,246 $ 19.14 — —


	Total number of shares purchased	Average price paid per share (b)		Total number of shares purchased as part of publicly announced plans or programs (c)	Approximate dollar value of shares that may yet be purchased under the plans or programs (c)
July 1, 2022 – July 31, 2022	—	$	—	—	$	770,784,573
August 1, 2022 – August 31, 2022 (a)	66,718	41.34		—	770,784,573
September 1, 2022 – September 30, 2022	1,768,356	42.41		1,768,356	1,695,784,616
Total	1,835,074			1,768,356

(a)~~Reflects the number~~In August 2022, we withheld 66,718 shares to pay taxes upon vesting of restricted stock. There were no shares ~~we have~~ withheld to pay taxes upon vesting of restricted ~~stock.~~stock in July and September 2022.

(b)Excludes any fees, commissions or other expenses associated with the share repurchases.

(c)On December 13, 2021, we announced that our Board of Directors approved a 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 announced on December 13, 2021, 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 expires December 31, 2023 but may be suspended, modified or discontinued at any time without prior notice. As of September 30, 2022, we had purchased shares under this authorization for an aggregate purchase price of $304.2 million, excluding fees, commissions and expenses. The total number of shares purchased and the approximate dollar value of shares that may yet be purchased under our repurchase authority reported in this table reflect shares purchased in each month based on the trade date; however, certain purchases may not have settled until the following month.

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Item 6. Exhibits

Exhibit No.

Description

Method of Filing

2.01*

Purchase Agreement, dated September 6, 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 September 7, 2022.

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(a)4.01

Fourteenth Supplemental Indenture, dated October 4, 2022, between EQT Corporation and The Bank of New York Mellon, as trustee, pursuant to which the 5.678% Senior Notes due 2025 were issued.

Incorporated by reference to Exhibit 4.3 to Form 8-K (#001-3551) filed on October 4, 2022.

4.02

Fifteenth Supplemental Indenture, dated October 4, 2022, between EQT Corporation and The Bank of New York Mellon, as trustee, pursuant to which the 5.700% Senior Notes due 2028 were issued.

Incorporated by reference to Exhibit 4.5 to Form 8-K (#001-3551) filed on October 4, 2022.

10.01*

Letter Agreement ~~(Ealy North – July)~~(Whipkey Interim Flow), dated ~~July 10, 2021,~~September 19, 2022, 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 ~~10.01(a).~~10.01.

*10.01(b)

Letter Agreement (Ealy North – August), dated August 25, 2021, 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 10.01(b).~~

*10.01(c)

Letter Agreement (Throckmorton), dated September 13, 2021, 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 10.01(c).~~

~~10.02~~

~~Registration Rights Agreement, dated July 21, 2021, among EQT Corporation and certain security holders thereof parties thereto, and Form of Lock-Up Agreement.~~

~~Incorporated herein by reference to Exhibit 10.1 to Form 8-K (#001-3551) filed on July 22, 2021.~~

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 ~~terms and~~ schedules and similar attachments into this exhibit have been ~~redacted or~~ omitted pursuant to Item 601(a)(5) and/or Item 601(b)(10)(iv), as applicable, of Regulation S-K. EQT Corporation agrees to furnish an unredacted, supplemental copy (including any omitted schedule or attachment) to the ~~Securities and Exchange Commission~~SEC upon request. ~~Redactions and omissions are designated with brackets containing asterisks.~~

3843

Table of Contents

SIGNATURE

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


						EQT CORPORATION
						(Registrant)


			By:			/s/ David M. Khani
						David M. Khani
						Chief Financial Officer

Date: October ~~28, 2021~~27, 2022

3944


		Page No.
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited):
	Statements of Condensed Consolidated Operations	3
	Statements of Condensed Consolidated Comprehensive Income (Loss) ~~Income~~	4
	Condensed Consolidated Balance Sheets	5
	Statements of Condensed Consolidated Cash Flows	6
	Statements of Condensed Consolidated Equity	7
	Notes to the Condensed Consolidated Financial Statements	9
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	2224
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3337
Item 4.	Controls and Procedures	3539

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	3639
Item 1A.	Risk Factors	3740
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3742
Item 6.	Exhibits	3843

Signature		3944


	Three Months Ended September 30,				Nine Months Ended September 30,
��	2021		2020		2021		2020

	(Thousands)
Net loss	$	(1,979,516)	$	(600,640)	$	(2,957,067)	$	(1,030,854)
Other comprehensive income, net of tax:
Other postretirement benefits liability adjustment, net of tax expense: $70, $23, $124 and $71	37		72		198		156
Comprehensive loss	(1,979,479)		(600,568)		(2,956,869)		(1,030,698)
Less: Comprehensive income attributable to noncontrolling interests	601		—		25		—
Comprehensive loss attributable to EQT Corporation	$	(1,980,080)	$	(600,568)	$	(2,956,894)	$	(1,030,698)


	2021 (a)		2022		2023		Total

	(Thousands)
Natural gas sales	$	41,746	$	8,158	$	6,794	$	56,698


	Total number of shares purchased (a)	Average price paid per share		Total number of shares purchased as part of publicly announced plans or programs	Approximate dollar value of shares that may yet be purchased under plans or programs
July 1, 2021 – July 31, 2021	—	$	—	—	—
August 1, 2021 – August 31, 2021	26,246	19.14		—	—
September 1, 2021 – September 30, 2021	—	—		—	—
Total	26,246	$	19.14	—	—