UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
			FOR THE QUARTERLY PERIOD ENDED ~~JUNE~~SEPTEMBER 30, 2021

☐

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

FOR THE TRANSITION PERIOD FROM__________ TO__________

COMMISSION FILE NUMBER 001-03551

EQT CORPORATION

(Exact name of registrant as specified in its charter)


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

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

(412) 553-5700

(Registrant's telephone number, including area code)

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

Title of each class

Trading symbol(s)

Name of each exchange on which registered

Common Stock, no par value

EQT

New York Stock Exchange

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

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

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

As of ~~July 23,~~October 22, 2021, ~~378,016,134~~377,948,658 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 June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020

		(Thousands, except per share amounts)									(Thousands, except per share amounts)
Operating revenues:	Operating revenues:									Operating revenues:
Sales of natural gas, natural gas liquids and oil	Sales of natural gas, natural gas liquids and oil	$	1,077,904	$	498,772	$	2,208,855	$	1,213,973	Sales of natural gas, natural gas liquids and oil	$	1,784,050	$	598,992	$	3,992,905	$	1,812,965
(Loss) gain on derivatives not designated as hedges		(1,345,532)		26,426		(1,534,345)		415,862
Loss on derivatives not designated as hedges										Loss on derivatives not designated as hedges	(3,257,237)		(427,182)		(4,791,582)		(11,320)
Net marketing services and other	Net marketing services and other	7,512		1,876		15,297		4,296		Net marketing services and other	8,349		317		23,646		4,613
Total operating revenues	Total operating revenues	(260,116)		527,074		689,807		1,634,131		Total operating revenues	(1,464,838)		172,127		(775,031)		1,806,258
Operating expenses:	Operating expenses:									Operating expenses:
Transportation and processing	Transportation and processing	464,016		405,636		909,800		845,470		Transportation and processing	494,897		427,691		1,404,697		1,273,161
Production	Production	47,546		38,329		94,776		78,709		Production	57,823		39,670		152,599		118,379
Exploration	Exploration	1,779		876		2,728		1,799		Exploration	20,495		3,160		23,223		4,959
Selling, general and administrative	Selling, general and administrative	49,853		43,341		94,859		78,279		Selling, general and administrative	49,113		51,654		143,972		129,933
Depreciation and depletion	Depreciation and depletion	380,288		323,096		757,404		680,622		Depreciation and depletion	442,876		341,027		1,200,280		1,021,649
Amortization of intangible assets	Amortization of intangible assets	0		7,477		0		14,955		Amortization of intangible assets	—		7,478		—		22,433
(Gain) loss on sale/exchange of long-lived assets	(Gain) loss on sale/exchange of long-lived assets	(16,816)		49,207		(18,023)		98,059		(Gain) loss on sale/exchange of long-lived assets	(391)		4,662		(18,414)		102,721
Impairment and expiration of leases	Impairment and expiration of leases	25,634		41,279		42,391		95,047		Impairment and expiration of leases	41,109		50,449		83,500		145,496
Other operating expenses	Other operating expenses	5,225		4,745		14,668		4,745		Other operating expenses	38,766		6,531		53,434		11,276
Total operating expenses	Total operating expenses	957,525		913,986		1,898,603		1,897,685		Total operating expenses	1,144,688		932,322		3,043,291		2,830,007
Operating loss	Operating loss	(1,217,641)		(386,912)		(1,208,796)		(263,554)		Operating loss	(2,609,526)		(760,195)		(3,818,322)		(1,023,749)
Gain on Equitrans Share Exchange (see Note 8)	Gain on Equitrans Share Exchange (see Note 8)	0		0		0		(187,223)		Gain on Equitrans Share Exchange (see Note 8)	—		—		—		(187,223)
(Income) loss from investments	(Income) loss from investments	(11,829)		(82,983)		(23,677)		307,645		(Income) loss from investments	(43,184)		(3,801)		(66,861)		303,844
Dividend and other income	Dividend and other income	(3,765)		(3,590)		(7,069)		(28,304)		Dividend and other income	(4,260)		(2,900)		(11,329)		(31,204)
Loss on debt extinguishment	Loss on debt extinguishment	5,332		353		9,756		16,963		Loss on debt extinguishment	—		3,749		9,756		20,712
Interest expense	Interest expense	76,986		65,386		152,085		127,760		Interest expense	80,349		69,154		232,434		196,914
Loss before income taxes	Loss before income taxes	(1,284,365)		(366,078)		(1,339,891)		(500,395)		Loss before income taxes	(2,642,431)		(826,397)		(3,982,322)		(1,326,792)
Income tax benefit	Income tax benefit	(347,846)		(103,003)		(362,340)		(70,181)		Income tax benefit	(662,915)		(225,757)		(1,025,255)		(295,938)
Net loss	Net loss	(936,519)		(263,075)		(977,551)		(430,214)		Net loss	(1,979,516)		(600,640)		(2,957,067)		(1,030,854)
Less: Net loss attributable to noncontrolling interest		(62)		0		(576)		0
Less: Net income attributable to noncontrolling interest										Less: Net income attributable to noncontrolling interest	601		—		25		—
Net loss attributable to EQT Corporation	Net loss attributable to EQT Corporation	$	(936,457)	$	(263,075)	$	(976,975)	$	(430,214)	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:	Loss per share of common stock attributable to EQT Corporation:									Loss per share of common stock attributable to EQT Corporation:
Basic:	Basic:									Basic:
Weighted average common stock outstanding	Weighted average common stock outstanding	279,156		255,524		278,996		255,477		Weighted average common stock outstanding	356,792		255,589		304,961		255,516
Net loss	Net loss	$	(3.35)	$	(1.03)	$	(3.50)	$	(1.68)	Net loss	$	(5.55)	$	(2.35)	$	(9.70)	$	(4.03)
Diluted:	Diluted:									Diluted:
Weighted average common stock outstanding	Weighted average common stock outstanding	279,156		255,524		278,996		255,477		Weighted average common stock outstanding	356,792		255,589		304,961		255,516
Net loss	Net loss	$	(3.35)	$	(1.03)	$	(3.50)	$	(1.68)	Net loss	$	(5.55)	$	(2.35)	$	(9.70)	$	(4.03)

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 (UNAUDITED)


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

		(Thousands)									(Thousands)
Net loss	Net loss	$	(936,519)	$	(263,075)	$	(977,551)	$	(430,214)	Net loss	$	(1,979,516)	$	(600,640)	$	(2,957,067)	$	(1,030,854)
Other comprehensive income, net of tax:	Other comprehensive income, net of tax:									Other comprehensive income, net of tax:
Other post-retirement benefits liability adjustment, net of tax expense: $27, $24, $54 and $48		81		72		161		84
Other postretirement benefits liability adjustment, net of tax expense: $70, $23, $124 and $71										Other postretirement benefits liability adjustment, net of tax expense: $70, $23, $124 and $71	37		72		198		156
Comprehensive loss	Comprehensive loss	(936,438)		(263,003)		(977,390)		(430,130)		Comprehensive loss	(1,979,479)		(600,568)		(2,956,869)		(1,030,698)
Less: Comprehensive loss attributable to noncontrolling interests		(62)		0		(576)		0
Less: Comprehensive income attributable to noncontrolling interests										Less: Comprehensive income attributable to noncontrolling interests	601		—		25		—
Comprehensive loss attributable to EQT Corporation	Comprehensive loss attributable to EQT Corporation	$	(936,376)	$	(263,003)	$	(976,814)	$	(430,130)	Comprehensive loss attributable to EQT Corporation	$	(1,980,080)	$	(600,568)	$	(2,956,894)	$	(1,030,698)

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


		June 30, 2021		December 31, 2020			September 30, 2021		December 31, 2020

		(Thousands)					(Thousands)
ASSETS	ASSETS					ASSETS
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	$	330,770	$	18,210	Cash and cash equivalents	$	22,792	$	18,210
Accounts receivable (less provision for doubtful accounts: $7,049 and $6,239)		651,568		566,552
Accounts receivable (less provision for doubtful accounts: $783 and $6,239)						Accounts receivable (less provision for doubtful accounts: $783 and $6,239)	1,132,364		566,552
Derivative instruments, at fair value	Derivative instruments, at fair value	648,855		527,073		Derivative instruments, at fair value	1,428,073		527,073
Prepaid expenses and other	Prepaid expenses and other	537,462		103,615		Prepaid expenses and other	757,670		103,615
Total current assets	Total current assets	2,168,655		1,215,450		Total current assets	3,340,899		1,215,450

Property, plant and equipment	Property, plant and equipment	22,497,579		21,995,249		Property, plant and equipment	25,890,930		21,995,249
Less: Accumulated depreciation and depletion	Less: Accumulated depreciation and depletion	6,678,508		5,940,984		Less: Accumulated depreciation and depletion	7,109,820		5,940,984
Net property, plant and equipment	Net property, plant and equipment	15,819,071		16,054,265		Net property, plant and equipment	18,781,110		16,054,265

Contract asset	Contract asset	410,000		410,000		Contract asset	410,000		410,000
Other assets	Other assets	587,531		433,754		Other assets	479,711		433,754
Total assets	Total assets	$	18,985,257	$	18,113,469	Total assets	$	23,011,720	$	18,113,469

LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current liabilities:	Current liabilities:					Current liabilities:
Current portion of debt	Current portion of debt	$	399,699	$	154,161	Current portion of debt	$	12,441	$	154,161
Accounts payable	Accounts payable	820,134		705,461		Accounts payable	1,183,194		705,461
Derivative instruments, at fair value	Derivative instruments, at fair value	2,160,253		600,877		Derivative instruments, at fair value	5,715,608		600,877
Other current liabilities	Other current liabilities	299,115		301,911		Other current liabilities	317,110		301,911
Total current liabilities	Total current liabilities	3,679,201		1,762,410		Total current liabilities	7,228,353		1,762,410

Credit facility borrowings	Credit facility borrowings	0		300,000		Credit facility borrowings	704,000		300,000
Senior notes	Senior notes	4,999,502		4,371,467		Senior notes	5,377,439		4,371,467
Note payable to EQM Midstream Partners, LP	Note payable to EQM Midstream Partners, LP	97,117		99,838		Note payable to EQM Midstream Partners, LP	95,728		99,838
Deferred income taxes	Deferred income taxes	1,009,721		1,371,967		Deferred income taxes	347,392		1,371,967
Other liabilities and credits	Other liabilities and credits	897,294		945,057		Other liabilities and credits	999,083		945,057
Total liabilities	Total liabilities	10,682,835		8,850,739		Total liabilities	14,751,995		8,850,739

Equity:	Equity:					Equity:
Common stock, 0 par value, shares authorized: 640,000, shares issued: 280,003		8,245,752		8,241,684
Treasury stock, shares at cost: 1,145 and 1,658		(20,084)		(29,348)
Common stock, no par value, shares authorized: 640,000, shares issued: 378,793 and 280,003						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						Treasury stock, shares at cost: 1,041 and 1,658	(18,202)		(29,348)
Retained earnings	Retained earnings	71,284		1,048,259		Retained earnings	(1,908,833)		1,048,259
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(5,194)		(5,355)		Accumulated other comprehensive loss	(5,157)		(5,355)
Total common shareholders' equity	Total common shareholders' equity	8,291,758		9,255,240		Total common shareholders' equity	8,248,460		9,255,240
Noncontrolling interests in consolidated subsidiaries	Noncontrolling interests in consolidated subsidiaries	10,664		7,490		Noncontrolling interests in consolidated subsidiaries	11,265		7,490
Total equity	Total equity	8,302,422		9,262,730		Total equity	8,259,725		9,262,730
Total liabilities and equity	Total liabilities and equity	$	18,985,257	$	18,113,469	Total liabilities and equity	$	23,011,720	$	18,113,469

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

Table of Contents

EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED)


		Six Months Ended June 30,					Nine Months Ended September 30,
		2021		2020			2021		2020

		(Thousands)					(Thousands)
Cash flows from operating activities:	Cash flows from operating activities:					Cash flows from operating activities:
Net loss	Net loss	$	(977,551)	$	(430,214)	Net loss	$	(2,957,067)	$	(1,030,854)
Adjustments to reconcile net loss to net cash provided by operating activities:	Adjustments to reconcile net loss to net cash provided by operating activities:					Adjustments to reconcile net loss to net cash provided by operating activities:
Deferred income tax (benefit) expense		(362,299)		24,987
Deferred income tax benefit						Deferred income tax benefit	(1,024,699)		(182,244)
Depreciation and depletion	Depreciation and depletion	757,404		680,622		Depreciation and depletion	1,200,280		1,021,649
Amortization of intangible assets	Amortization of intangible assets	0		14,955		Amortization of intangible assets	—		22,433
Gain/loss on sale/exchange of long-lived assets and impairment and expiration of leases	Gain/loss on sale/exchange of long-lived assets and impairment and expiration of leases	24,368		193,106		Gain/loss on sale/exchange of long-lived assets and impairment and expiration of leases	65,086		248,217
Gain on Equitrans Share Exchange	Gain on Equitrans Share Exchange	0		(187,223)		Gain on Equitrans Share Exchange	—		(187,223)
(Income) loss from investments	(Income) loss from investments	(23,677)		307,645		(Income) loss from investments	(66,861)		303,844
Loss on debt extinguishment	Loss on debt extinguishment	9,756		16,963		Loss on debt extinguishment	9,756		20,712
Share-based compensation expense	Share-based compensation expense	13,515		8,123		Share-based compensation expense	20,822		15,226
Amortization, accretion and other	Amortization, accretion and other	22,097		12,614		Amortization, accretion and other	32,095		25,236
Loss (gain) on derivatives not designated as hedges		1,534,345		(415,862)
Loss on derivatives not designated as hedges						Loss on derivatives not designated as hedges	4,791,582		11,320
Cash settlements (paid) received on derivatives not designated as hedges	Cash settlements (paid) received on derivatives not designated as hedges	(109,581)		561,129		Cash settlements (paid) received on derivatives not designated as hedges	(729,445)		813,218
Net premiums received (paid) on derivative instruments		3,654		(53,473)
Net premiums paid on derivative instruments						Net premiums paid on derivative instruments	(53,429)		(53,473)
Changes in other assets and liabilities:	Changes in other assets and liabilities:					Changes in other assets and liabilities:
Accounts receivable	Accounts receivable	(99,564)		206,322		Accounts receivable	(404,442)		139,713
Accounts payable	Accounts payable	111,191		(85,973)		Accounts payable	276,509		(62,853)
Income tax receivable and payable	Income tax receivable and payable	(23,909)		96,920		Income tax receivable and payable	(27,055)		248,101
Other current assets	Other current assets	(422,618)		(2,597)		Other current assets	(642,554)		(140,466)
Other items, net	Other items, net	(13,737)		(923)		Other items, net	924		(80,979)
Net cash provided by operating activities	Net cash provided by operating activities	443,394		947,121		Net cash provided by operating activities	491,502		1,131,577
Cash flows from investing activities:	Cash flows from investing activities:					Cash flows from investing activities:
Capital expenditures	Capital expenditures	(470,259)		(512,095)		Capital expenditures	(706,938)		(788,384)
Cash paid for acquisitions		(209,764)		0
Cash paid for acquisitions, net of cash acquired						Cash paid for acquisitions, net of cash acquired	(1,021,510)		—
Proceeds from sale of assets	Proceeds from sale of assets	0		110,937		Proceeds from sale of assets	—		113,236
Cash received for Equitrans Share Exchange	Cash received for Equitrans Share Exchange	0		52,323		Cash received for Equitrans Share Exchange	—		52,323
Other investing activities	Other investing activities	5,125		(135)		Other investing activities	13,590		117
Net cash used in investing activities	Net cash used in investing activities	(674,898)		(348,970)		Net cash used in investing activities	(1,714,858)		(622,708)
Cash flows from financing activities:	Cash flows from financing activities:					Cash flows from financing activities:
Proceeds from credit facility borrowings	Proceeds from credit facility borrowings	2,686,000		781,000		Proceeds from credit facility borrowings	6,216,000		1,772,750
Repayment of credit facility borrowings	Repayment of credit facility borrowings	(2,986,000)		(1,037,000)		Repayment of credit facility borrowings	(5,812,000)		(1,822,250)
Proceeds from issuance of debt	Proceeds from issuance of debt	1,000,000		2,250,000		Proceeds from issuance of debt	1,000,000		2,250,000
Debt issuance costs and Capped Call Transactions (See Note 6)	Debt issuance costs and Capped Call Transactions (See Note 6)	(19,713)		(65,102)		Debt issuance costs and Capped Call Transactions (See Note 6)	(19,713)		(65,102)
Repayments and retirements of debt		(127,691)		(2,507,074)
Repayment and retirement of debt						Repayment and retirement of debt	(146,005)		(2,609,785)
Premiums paid on debt extinguishment	Premiums paid on debt extinguishment	(9,599)		(13,635)		Premiums paid on debt extinguishment	(9,599)		(17,150)
Contributions from noncontrolling interests	Contributions from noncontrolling interests	3,750		0		Contributions from noncontrolling interests	3,750		—
Dividends paid	Dividends paid	0		(7,664)		Dividends paid	—		(7,664)
Cash paid for taxes related to net settlement of share-based incentive awards	Cash paid for taxes related to net settlement of share-based incentive awards	(2,683)		(304)		Cash paid for taxes related to net settlement of share-based incentive awards	(3,805)		(596)
Other financing activities						Other financing activities	(690)		—
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	544,064		(599,779)		Net cash provided by (used in) financing activities	1,227,938		(499,797)
Net change in cash and cash equivalents	Net change in cash and cash equivalents	312,560		(1,628)		Net change in cash and cash equivalents	4,582		9,072
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	18,210		4,596		Cash and cash equivalents at beginning of period	18,210		4,596
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	330,770	$	2,968	Cash and cash equivalents at end of period	$	22,792	$	13,668

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 April 1, 2020 255,262 $ 7,821,631 $ (30,852) $ 1,848,286 $ (5,187) $ 0 $ 9,633,878
Comprehensive loss, net of tax:
Net loss (263,075) (263,075)
Other postretirement benefits liability adjustment, net of tax expense: $24 72 72
Share-based compensation plans 28 3,796 511 4,307
Equity component of convertible senior notes (See Note 6) 63,645 63,645
Balance at June 30, 2020 255,290 $ 7,889,072 $ (30,341) $ 1,585,211 $ (5,115) $ 0 $ 9,438,827
Balance at April 1, 2021 278,781 $ 8,238,643 $ (21,469) $ 1,007,741 $ (5,275) $ 10,726 $ 9,230,366
Comprehensive loss, net of tax:
Net loss (936,457) (62) (936,519)
Other postretirement benefits liability adjustment, net of tax expense: $27 81 81
Share-based compensation plans 77 7,109 1,385 8,494
Balance at June 30, 2021 278,858 $ 8,245,752 $ (20,084) $ 71,284 $ (5,194) $ 10,664 $ 8,302,422


	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 shares authorized: ~~320,000 and 640,000 at June 30, 2020 and 2021, respectively.~~

640,000. Preferred shares authorized: 3,000. There were 0no preferred shares issued or outstanding.

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

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

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EQT CORPORATION AND SUBSIDIARIES

STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)


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

		(Thousands, except per share amounts)																				(Thousands, except per share amounts)
Balance at January 1, 2020	Balance at January 1, 2020	255,171	$	7,818,205	$	(32,507)	$	2,023,089			$	(5,199)			$	0				$	9,803,588		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:	Comprehensive loss, net of tax:																			Comprehensive loss, net of tax:
Net loss	Net loss						(430,214)										(430,214)			Net loss													(1,030,854)												(1,030,854)
Other postretirement benefit liability adjustment, net of tax expense: $48									84								84
Other postretirement benefits liability adjustment, net of tax expense: $71																				Other postretirement benefits liability adjustment, net of tax expense: $71																	156								156
Dividends ($0.03 per share)	Dividends ($0.03 per share)						(7,664)										(7,664)			Dividends ($0.03 per share)													(7,664)												(7,664)
Share-based compensation plans	Share-based compensation plans	119	7,222		2,166												9,388			Share-based compensation plans		174			13,778				3,160																16,938
Equity component of convertible senior notes (See Note 6)	Equity component of convertible senior notes (See Note 6)		63,645														63,645			Equity component of convertible senior notes (See Note 6)					63,645																				63,645
Balance at June 30, 2020		255,290	$	7,889,072	$	(30,341)	$	1,585,211	$	(5,115)			$	0			$	9,438,827
Balance at September 30, 2020																				Balance at September 30, 2020		255,345			$	7,895,628			$	(29,347)			$	984,571			$	(5,043)			$	—			$	8,845,809

Balance at January 1, 2021	Balance at January 1, 2021	278,345	$	8,241,684	$	(29,348)	$	1,048,259	$	(5,355)			$	7,490			$	9,262,730		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:	Comprehensive loss, net of tax:																			Comprehensive loss, net of tax:
Net loss							(976,975)						(576)				(977,551)
Other postretirement benefit liability adjustment, net of tax expense: $54									161								161
Net (loss) income																				Net (loss) income													(2,957,092)								25				(2,957,067)
Other postretirement benefits liability adjustment, net of tax expense: $124																				Other postretirement benefits liability adjustment, net of tax expense: $124																	198								198
Share-based compensation plans	Share-based compensation plans	513	4,068		9,264												13,332			Share-based compensation plans		618			13,563				11,146																24,709
Contributions from noncontrolling interests	Contributions from noncontrolling interests												3,750				3,750			Contributions from noncontrolling interests																					3,750				3,750
Balance at June 30, 2021		278,858	$	8,245,752	$	(20,084)	$	71,284	$	(5,194)			$	10,664			$	8,302,422
Alta Acquisition (See Note 10)																				Alta Acquisition (See Note 10)		98,789			1,925,405																				1,925,405
Balance at September 30, 2021																				Balance at September 30, 2021		377,752			$	10,180,652			$	(18,202)			$	(1,908,833)			$	(5,157)			$	11,265			$	8,259,725

Common shares authorized: ~~320,000 and 640,000 at June 30, 2020 and 2021, respectively.~~

640,000. Preferred shares authorized: 3,000. There were 0no 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 ~~June~~September 30, 2021 and December 31, 2020, the results of its operations and equity for the three and ~~six~~nine month periods ended ~~June~~September 30, 2021 and 2020 and its cash flows for the ~~six~~nine month periods ended ~~June~~September 30, 2021 and 2020. 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 the audited financial statements at that date. For further information, refer to the Consolidated Financial Statements and accompanying notes in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.

Recently Issued Accounting Standards

In December 2019, 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 815 or 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 ASU also amends the impact of convertible instruments on the calculation of diluted earnings per share (EPS) and 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 this ASU on January 1, 2022 using the full retrospective method of adoption. The Company is evaluating the impact this standard will have on its financial statements and disclosures.

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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.

Six Months Ended June 30,
2021 2020
(Thousands)
Cash paid (received) during the period for:
Interest, net of amount capitalized $ 127,082 $ 74,596
Income taxes, net 21,768 (191,598)
Non-cash activity during the period for:
Increase in right-of-use lease assets and liabilities $ 1,091 $ 1,697
Increase in asset retirement costs and obligations 1,943 6,596
Capitalization of non-cash equity share-based compensation 2,499 1,611

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~~EQT CORPORATION AND SUBSIDIARIES~~

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


	Nine Months Ended September 30,
	2021		2020

	(Thousands)
Cash paid (received) during the period for:
Interest, net of amount capitalized	$	220,430	$	145,366
Income taxes, net	22,263		(402,044)
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	2,709		9,674
Capitalization of non-cash equity share-based compensation	3,728		2,350
Equity issued as consideration for the Alta Acquisition (See Note 10)	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 ~~$471.5~~$851.2 million and $394.1 million in accounts receivable in the Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2021 and December 31, 2020, respectively.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

The table below provides disaggregated information on the Company's revenues. Certain 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 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 June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020

		(Thousands)									(Thousands)
Revenues from contracts with customers:	Revenues from contracts with customers:									Revenues from contracts with customers:
Natural gas sales	Natural gas sales	$	953,385	$	468,216	$	1,966,465	$	1,141,446	Natural gas sales	$	1,605,581	$	556,950	$	3,572,046	$	1,698,396
NGLs sales	NGLs sales	102,361		28,761		202,618		64,517		NGLs sales	152,046		38,380		354,664		102,897
Oil sales	Oil sales	22,158		1,795		39,772		8,010		Oil sales	26,423		3,662		66,195		11,672
Total revenues from contracts with customers	Total revenues from contracts with customers	$	1,077,904	$	498,772	$	2,208,855	$	1,213,973	Total revenues from contracts with customers	$	1,784,050	$	598,992	$	3,992,905	$	1,812,965

Other sources of revenue:	Other sources of revenue:									Other sources of revenue:
(Loss) gain on derivatives not designated as hedges		(1,345,532)		26,426		(1,534,345)		415,862
Loss on derivatives not designated as hedges										Loss on derivatives not designated as hedges	(3,257,237)		(427,182)		(4,791,582)		(11,320)
Net marketing services and other	Net marketing services and other	7,512		1,876		15,297		4,296		Net marketing services and other	8,349		317		23,646		4,613
Total operating revenues	Total operating revenues	$	(260,116)	$	527,074	$	689,807	$	1,634,131	Total operating revenues	$	(1,464,838)	$	172,127	$	(775,031)	$	1,806,258

The following table summarizes the transaction price allocated to the Company's remaining performance obligations on all contracts with fixed consideration as of ~~June~~September 30, 2021. Amounts shown exclude contracts that qualified for the exception to the relative standalone selling price method as of ~~June~~September 30, 2021.

2021 (a) 2022 2023 Total
(Thousands)
Natural gas sales $ 87,901 $ 8,158 $ 6,794 $ 102,853


	2021 (a)		2022		2023		Total

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

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

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~~EQT CORPORATION AND SUBSIDIARIES~~

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

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 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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EQT CORPORATION AND SUBSIDIARIES

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 ~~2,773~~2,554 Bcf of natural gas and ~~7,687~~5,146 Mbbl of NGLs as of ~~June~~September 30, 2021 and 1,955 Bcf of natural gas and 3,462 Mbbl of NGLs as of December 31, 2020. The open positions at ~~June~~September 30, 2021 and December 31, 2020 had maturities extending through December 2027 and December 2024, respectively.

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) 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 or S&P 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). Anything below these ratings is considered non-investment grade. As of ~~June~~September 30, 2021, the Company's senior notes were rated ~~"Ba2"~~"Ba1" by Moody's and ~~"BB"~~"BB+" by S&P.

When the net fair value of any of the Company's OTC derivative instrument contracts represents a liability to the Company that is in excess of the agreed-upon dollar threshold for the Company's then-applicable credit rating, the counterparty has the right to require the Company to remit funds as a margin deposit in an amount equal to the portion of the derivative liability that is in excess of the dollar threshold amount. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. As of ~~June~~September 30, 2021 and December 31, 2020, the aggregate fair value of all OTC derivative instruments with credit rating risk-related contingent features that were in a net liability position was ~~$1,166.3~~$1,242.7 million and $137.7 million, respectively, for which the Company deposited and recorded current assets of ~~$284.4~~$332.0 million and $21.1 million, respectively.

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~~EQT CORPORATION AND SUBSIDIARIES~~

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

When the net fair value of any of the Company's OTC derivative instrument contracts represents an asset to the Company that is in excess of the agreed-upon dollar threshold for the counterparty's then-applicable credit rating, the Company has the right to require the counterparty to remit funds as a margin deposit in an amount equal to the portion of the derivative asset that is in excess of the dollar threshold amount. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. As of both ~~June~~September 30, 2021 and December 31, 2020, there were 0no 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 ~~June~~September 30, 2021 and December 31, 2020, the Company recorded ~~$205.7~~$381.4 million and $61.5 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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EQT CORPORATION AND SUBSIDIARIES

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)
June 30, 2021
September 30, 2021										September 30, 2021
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	648,855	$	(576,429)	$	0	$	72,426	Asset derivative instruments, at fair value	$	1,428,073	$	(1,313,856)	$	—	$	114,217
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	2,160,253		(576,429)		(490,109)		1,093,715		Liability derivative instruments, at fair value	5,715,608		(1,313,856)		(713,432)		3,688,320

December 31, 2020	December 31, 2020									December 31, 2020
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	527,073	$	(328,809)	$	0	$	198,264	Asset derivative instruments, at fair value	$	527,073	$	(328,809)	$	—	$	198,264
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	600,877		(328,809)		(82,552)		189,516

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 ~~natural gas liquids~~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.

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EQT CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements (Unaudited)

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


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

				(Thousands)												(Thousands)
June 30, 2021
September 30, 2021													September 30, 2021
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	648,855		$	134,691		$	514,164		$	0	Asset derivative instruments, at fair value	$	1,428,073		$	216,702		$	1,211,371		$	—
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	2,160,253			315,372			1,844,881			0		Liability derivative instruments, at fair value	5,715,608			460,180			5,255,428			—

December 31, 2020	December 31, 2020												December 31, 2020
Asset derivative instruments, at fair value	Asset derivative instruments, at fair value	$	527,073		$	70,603		$	456,470		$	0	Asset derivative instruments, at fair value	$	527,073		$	70,603		$	456,470		$	—
Liability derivative instruments, at fair value	Liability derivative instruments, at fair value	600,877			93,361			507,516			0		Liability derivative instruments, at fair value	600,877			93,361			507,516			—

The carrying values of cash equivalents, accounts receivable and accounts payable approximate fair value due to their short-term maturities. The carrying value of the Company's investment in Equitrans Midstream Corporation (Equitrans Midstream) approximates fair value as Equitrans Midstream is a publicly traded company. 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 estimates the fair value of its senior notes using established fair value methodology. Because not all of the Company's senior notes are actively traded, their fair value is a Level 2 fair value measurement. As of ~~June~~September 30, 2021 and December 31, 2020, the Company's senior notes had a fair value of approximately ~~$6.5~~$6.4 billion and $5.2 billion, respectively, and a carrying value of approximately $5.4 billion and $4.5 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 ~~June~~September 30, 2021 and December 31, 2020, the Company's note payable to EQM had a fair value of approximately ~~$123~~$120 million and $130 million, respectively, and a carrying value of approximately ~~$102~~$101 million and $105 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 8 for a discussion of the fair value measurement of the Equitrans Share Exchange ~~and~~(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). 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 for a discussion of the fair value of assets related to the impairment and expiration of leases.

5. Income Taxes

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

1314

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

The Company recorded income tax benefit at an effective tax rate of ~~27.0%~~25.7% and ~~14.0%~~22.3% for the ~~six~~nine months ended ~~June~~September 30, 2021 and 2020, respectively. The Company's effective tax rate for the ~~six~~nine months ended ~~June~~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.The Company's effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2020 was ~~lower~~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 ~~in the first half of~~through September 30, 2020 that, if such investment is sold, would become capital losses. The Company believes ~~that~~ it is more likely than not that such additional unrealized losses will not be realized for tax purposes.

6. Debt

Credit facility. The Company has a $2.5 billion credit facility. On April 23, 2021, the Company entered into an Extension Agreement and First Amendment to Second Amended and Restated Credit Agreement (the Extension Agreement and First Amendment), amending 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 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, (ii) adds customary provisions to provide for the eventual replacement of LIBOR as a benchmark interest rate and (iii) adds an additional pricing level for the Applicable Rate (as defined in the Credit Agreement).

The Company had approximately ~~$670~~$553 million and $791 million of letters of credit outstanding under its credit facility as of ~~June~~September 30, 2021 and December 31, 2020, respectively.

Under the Company's credit facility, for the three months ended ~~June~~September 30, 2021 and 2020, the maximum amounts of outstanding borrowings were ~~$578~~$1,652 million and ~~$173~~$399 million, respectively, the average daily balances were approximately ~~$236~~$813 million and ~~$35~~$149 million, respectively, and interest was incurred at weighted average annual interest rates of ~~2.1%~~1.9% and ~~2.4%~~2.2%, respectively. Under the Company's credit facility, for the ~~six~~nine months ended ~~June~~September 30, 2021 and 2020, the maximum amounts of outstanding borrowings were ~~$890~~$1,652 million and ~~$356~~$399 million, respectively, the average daily balances were approximately ~~$188~~$525 million and ~~$60~~$90 million, respectively, and interest was incurred at weighted average annual interest rates of ~~2.1%~~2.0% and ~~2.9%~~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 ~~three~~period beginning January 1, 2020 and ~~six months ended~~ending June 30, 2020, the average daily ~~balances were~~balance was approximately ~~$431 million and~~ $692 million ~~respectively,~~ and interest was incurred at a weighted average annual interest ~~rates~~rate of ~~2.2% and~~ 2.6%~~, respectively.~~.

3.125% senior notes and 3.625% 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). 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, 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.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Convertible Notes. On 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.

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

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 period after any 5-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 ~~may~~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 ~~June~~September 30, 2021, the net carrying value of the liability portion of the Convertible Notes was included in ~~current portion of debt~~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.

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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.

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, 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 over 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

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

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.

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 ~~were~~was recorded as a reduction to equity and will not be remeasured.

For the second quarter of 2020, 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 of $32.5 million and issuance costs attributable to the equity component of $4.8 million.

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


		June 30, 2021		December 31, 2020			September 30, 2021		December 31, 2020

		(Thousands)					(Thousands)
Principal	Principal	$	500,000	$	500,000	Principal	$	499,991	$	500,000
Less: Unamortized debt discount	Less: Unamortized debt discount	119,105		129,103		Less: Unamortized debt discount	113,960		129,103
Less: Unamortized debt issuance costs	Less: Unamortized debt issuance costs	10,562		11,263		Less: Unamortized debt issuance costs	10,188		11,263
Net carrying value of Convertible Notes	Net carrying value of Convertible Notes	$	370,333	$	359,634	Net carrying value of Convertible Notes	$	375,843	$	359,634

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

The table below summarizes the components of interest expense related to the Convertible Notes.


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020

		(Thousands)									(Thousands)
Contractual interest expense	Contractual interest expense	$	2,187	$	1,507	$	4,375	$	1,507	Contractual interest expense	$	2,188	$	2,188	$	6,563	$	3,695
Amortization of debt discount	Amortization of debt discount	5,046		3,231		9,998		3,231		Amortization of debt discount	5,143		4,767		15,141		7,998
Amortization of issuance costs	Amortization of issuance costs	358		209		701		209		Amortization of issuance costs	374		315		1,075		524
Total Convertible Notes interest expense	Total Convertible Notes interest expense	$	7,591	$	4,947	$	15,074	$	4,947	Total Convertible Notes interest expense	$	7,705	$	7,270	$	22,779	$	12,217

Based on the closing stock price of EQT common stock of ~~$22.26~~$20.46 on ~~June~~September 30, 2021 and excluding the impact of the Capped Call Transactions, the if-converted value of the Convertible Notes exceeded the principal amount by ~~$242~~$182 million.

7. 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 ~~six~~nine months ended ~~June~~September 30, 2021 and 2020, all such securities were excluded from potentially dilutive securities because of their anti-dilutive effect on EPS. Such securities for the three and ~~six~~nine months ended ~~June~~September 30, 2021 were ~~7,679,584~~7,506,075 and ~~7,712,354,~~7,642,451, respectively, and such securities for the three and ~~six~~nine months ended ~~June~~September 30, 2020 were ~~6,769,822~~6,671,532 and ~~6,739,305,~~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 ~~the three and six~~

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

~~months ended June 30, 2021 and for the period of April 28, 2020 through June 30, 2020,~~all periods presented, the conversion premium of ~~6,666,670~~approximately 6.7 million shares was excluded from potentially dilutive securities because of its anti-dilutive effect on EPS.

8. Equitrans Share Exchange

During the first quarter of 2020, the Company sold to Equitrans Midstream a total of 25,299,752 shares of Equitrans Midstream's common stock in exchange for approximately $52 million in 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 (the Consolidated GGA). The Company recorded in the Condensed Consolidated Balance Sheet a contract asset representing the estimated fair value of the rate relief and, beginning on the Mountain Valley Pipeline (MVP) in-service date, expects to recognize amortization of the contract asset over a period of approximately four years in a manner consistent with the expected timing of the Company's realization 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 ~~June~~September 30, 2021 and December 31, 2020, the derivative liability related to the Henry Hub Cash Bonus was approximately ~~$97~~$109 million and $107 million, respectively. In addition, the Consolidated GGA provides a cash payment option that grants the Company the right to receive payments from EQM in the event that the MVP in-service date has not occurred prior to January 1, 2022.

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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Notes to the Condensed Consolidated Financial Statements (Unaudited)

9. Asset Exchange Transactions and Divestiture

2020 Asset Exchange Transactions. During the ~~first and second quarters of~~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 ~~11,700~~14,600 aggregate net revenue interest acres across Greene, Allegheny, Westmoreland and ~~Westmoreland~~Washington Counties, ~~Pennsylvania and~~Pennsylvania; Wetzel and Marshall Counties, West ~~Virginia~~Virginia; and Belmont County, Ohio for approximately ~~11,700~~14,600 aggregate net revenue interest acres across Greene and Washington Counties, ~~Pennsylvania and~~Pennsylvania; Wetzel County, West ~~Virginia.~~Virginia; and Belmont County, Ohio. As a result of the 2020 Asset Exchange Transactions, the Company recognized a loss of ~~$6.7~~$11.6 million and ~~$55.6~~$67.2 million in (gain) loss on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations for the three and ~~six~~nine months ended ~~June~~September 30, 2020, respectively. The fair value of leases acquired ~~were~~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 market-based prices for comparable acreage.

2020 Divestiture. 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 ~~$17.5~~approximately $12.9 million and $1.9 million as of ~~June~~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

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

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 ~~$42.5~~$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 ~~second quarter of~~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, ~~not a business combination 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 ~~hold~~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 ~~the Company's~~EQT common stock, as adjusted pursuant to customary closing purchase price adjustments set forth in the Alta Purchase Agreement. The Alta Purchase Agreement ~~contains customary representations and warranties, covenants, indemnification and termination provisions and~~ has an effective date of January 1, 2021.

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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. ~~In May 2021, upon execution~~

Certain of the ~~Alta Purchase Agreement,~~acquired midstream gathering systems are not wholly-owned but are operated by the Company ~~deposited $146.3 million~~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 complete the purchase price allocation is not yet available, including, but not limited to, final appraisals of assets acquired and liabilities assumed. The Company expects to complete the purchase price allocation once it has received all necessary information, at which time the value of the assets 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

The fair value of the acquired natural gas and oil properties was measured using discounted cash flow valuation techniques based on inputs that are not observable in ~~an escrow account, which~~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 ~~disbursed~~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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Notes to ~~Alta Resources at closing. As of June 30, 2021, this deposit was reflected in other assets in~~ the Condensed Consolidated ~~Balance Sheet.~~Financial Statements (Unaudited)

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.



	(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)

Unaudited Pro Forma Information. The table below summarizes the Company's results as though the Alta Acquisition had been completed on January 1, 2020. 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 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)

1821

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

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

The following discussion and analysis of financial condition and results of operations should be read in conjunction with the Condensed Consolidated Financial Statements and the notes thereto included in this report. Unless the context otherwise indicates, all references in this report to "EQT," 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, and Section 27A of the Securities Act of 1933, as amended. Statements that do not relate strictly to historical or current facts are forward-looking and are usually identified by the use of words such as "anticipate," "estimate," "could," "would," "will," "may," "forecast," "approximate," "expect," "project," "intend," "plan," "believe" and other words of similar meaning, or the negative thereof, in connection with any discussion of future operating or financial matters. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10-Q include the expectations of our plans, strategies, objectives and growth and anticipated financial and operational performance, including guidance regarding our strategy to develop our reserves; drilling plans and programs (including availability of capital to complete these plans and programs); ~~the projected scope and timing of our combo-development projects; estimated reserves, including potential future downward adjustments of reserves and reserve life;~~ total resource potential and drilling inventory duration; projected production and sales volume and growth rates (including liquids production and sales volume and growth rates); natural gas prices; changes in basis and the impact of commodity prices on our business; potential future impairments of our assets; ~~our ability to reduce our~~projected well costs and capital ~~expenditures, and the timing of achieving any such reductions;~~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 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; 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 acquisition transactions 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; 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; projected dividends, if any; projected cash flows and free cash flow; ~~projected capital expenditures;~~ 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;~~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; 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; the ability to obtain environmental and other permits and the timing thereof; government regulation or action; environmental and weather risks, including the possible impacts of climate change; and disruptions to our business due to acquisitions and other significant transactions. 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.

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 attributable to EQT Corporation for the three months ended ~~June~~September 30, 2021 was ~~$936.5~~$1,980.1 million, ~~$3.35~~$5.55 per diluted share, compared to net loss attributable to EQT Corporation for the same period in 2020 of ~~$263.1~~$600.6 million, ~~$1.03~~$2.35 per diluted share. The change was attributable primarily to the loss on derivatives not designated as hedges, ~~lower income from investments,~~increased depreciation and depletion, increased transportation and processing expense and increased ~~depreciation and depletion,~~other operating expenses, partly offset by increased sales of natural gas, NGLs and oil, higher income tax benefit ~~the gain on sale of long-lived assets~~ and ~~decreased impairment and expiration of leases.~~higher income from investments.

Net loss attributable to EQT Corporation for the ~~six~~nine months ended ~~June~~September 30, 2021 was ~~$977.0~~$2,957.1 million, ~~$3.50~~$9.70 per diluted share, compared to net loss attributable to EQT Corporation for the same period in 2020 of ~~$430.2~~$1,030.9 million, ~~$1.68~~$4.03 per diluted share. The change was attributable primarily to the loss on derivatives not designated as hedges, the gain on Equitrans Share Exchange (defined and discussed in Note 8 to the Condensed Consolidated Financial Statements) recognized in the first quarter of 2020, increased depreciation and depletion, ~~and~~ 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, the income from investments, ~~higher income tax benefit,~~ the gain on sale of long-lived assets and decreased impairment and expiration of leases.

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.

2023

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EQT CORPORATION AND SUBSIDIARIES

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020

		(Thousands, unless otherwise noted)									(Thousands, unless otherwise noted)
NATURAL GAS	NATURAL GAS									NATURAL GAS
Sales volume (MMcf)	Sales volume (MMcf)	394,268		325,248		784,566		694,990		Sales volume (MMcf)	464,574		348,136		1,249,140		1,043,126
NYMEX price ($/MMBtu)	NYMEX price ($/MMBtu)	$	2.84	$	1.71	$	2.76	$	1.84	NYMEX price ($/MMBtu)	$	4.02	$	1.97	$	3.23	$	1.88
Btu uplift	Btu uplift	0.16		0.09		0.15		0.09		Btu uplift	0.19		0.11		0.17		0.10
Natural gas price ($/Mcf)	Natural gas price ($/Mcf)	$	3.00	$	1.80	$	2.91	$	1.93	Natural gas price ($/Mcf)	$	4.21	$	2.08	$	3.40	$	1.98

Basis ($/Mcf) (a)	Basis ($/Mcf) (a)	$	(0.57)	$	(0.36)	$	(0.41)	$	(0.29)	Basis ($/Mcf) (a)	$	(0.76)	$	(0.48)	$	(0.54)	$	(0.35)
Cash settled basis swaps (not designated as hedges) ($/Mcf)		(0.02)		(0.02)		(0.05)		0.02
Cash settled basis swaps not designated as hedges ($/Mcf)										Cash settled basis swaps not designated as hedges ($/Mcf)	(0.05)		0.01		(0.05)		0.01
Average differential, including cash settled basis swaps ($/Mcf)	Average differential, including cash settled basis swaps ($/Mcf)	$	(0.59)	$	(0.38)	$	(0.46)	$	(0.27)	Average differential, including cash settled basis swaps ($/Mcf)	$	(0.81)	$	(0.47)	$	(0.59)	$	(0.34)
Average adjusted price ($/Mcf)	Average adjusted price ($/Mcf)	$	2.41	$	1.42	$	2.45	$	1.66	Average adjusted price ($/Mcf)	$	3.40	$	1.61	$	2.81	$	1.64
Cash settled derivatives (not designated as hedges) ($/Mcf)		(0.13)		1.00		(0.07)		0.79
Cash settled derivatives not designated as hedges ($/Mcf)										Cash settled derivatives not designated as hedges ($/Mcf)	(1.20)		0.72		(0.49)		0.77
Average natural gas price, including cash settled derivatives ($/Mcf)	Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.28	$	2.42	$	2.38	$	2.45	Average natural gas price, including cash settled derivatives ($/Mcf)	$	2.20	$	2.33	$	2.32	$	2.41
Natural gas sales, including cash settled derivatives	Natural gas sales, including cash settled derivatives	$	897,429	$	786,595	$	1,869,923	$	1,702,006	Natural gas sales, including cash settled derivatives	$	1,021,529	$	811,122	$	2,891,452	$	2,513,128

LIQUIDS	LIQUIDS									LIQUIDS
Natural gas liquids (NGLs), excluding ethane:
NGLs, excluding ethane:										NGLs, excluding ethane:
Sales volume (MMcfe) (b)	Sales volume (MMcfe) (b)	16,158		10,572		30,758		21,392		Sales volume (MMcfe) (b)	16,504		10,661		47,262		32,053
Sales volume (Mbbl)	Sales volume (Mbbl)	2,693		1,762		5,126		3,565		Sales volume (Mbbl)	2,751		1,777		7,877		5,342
Price ($/Bbl)	Price ($/Bbl)	$	34.83	$	13.52	$	36.00	$	16.08	Price ($/Bbl)	$	49.39	$	19.83	$	40.67	$	17.33
Cash settled derivatives (not designated as hedges) ($/Bbl)		(9.31)		(0.52)		(6.31)		(0.26)
Average NGLs price, including cash settled derivatives ($/Bbl)		$	25.52	$	13.00	$	29.69	$	15.82
Cash settled derivatives not designated as hedges ($/Bbl)										Cash settled derivatives not designated as hedges ($/Bbl)	(16.35)		—		(9.82)		(0.17)
Average price, including cash settled derivatives ($/Bbl)										Average price, including cash settled derivatives ($/Bbl)	$	33.04	$	19.83	$	30.85	$	17.16
NGLs sales	NGLs sales	$	68,737	$	22,910	$	152,180	$	56,421	NGLs sales	$	90,877	$	35,227	$	243,057	$	91,648
Ethane:	Ethane:									Ethane:
Sales volume (MMcfe) (b)	Sales volume (MMcfe) (b)	7,803		8,769		16,390		12,098		Sales volume (MMcfe) (b)	10,546		6,442		26,936		18,540
Sales volume (Mbbl)	Sales volume (Mbbl)	1,301		1,461		2,732		2,016		Sales volume (Mbbl)	1,758		1,074		4,490		3,090
Price ($/Bbl)	Price ($/Bbl)	$	6.58	$	3.38	$	6.62	$	3.56	Price ($/Bbl)	$	9.22	$	2.94	$	7.64	$	3.35
Ethane sales	Ethane sales	$	8,560	$	4,941	$	18,094	$	7,186	Ethane sales	$	16,202	$	3,153	$	34,296	$	10,339
Oil:	Oil:									Oil:
Sales volume (MMcfe) (b)	Sales volume (MMcfe) (b)	2,366		1,058		4,071		2,237		Sales volume (MMcfe) (b)	3,389		899		7,460		3,136
Sales volume (Mbbl)	Sales volume (Mbbl)	394		176		678		373		Sales volume (Mbbl)	565		150		1,243		523
Price ($/Bbl)	Price ($/Bbl)	$	56.18	$	10.17	$	58.61	$	21.48	Price ($/Bbl)	$	46.79	$	24.43	$	53.24	$	22.32
Oil sales	Oil sales	$	22,158	$	1,795	$	39,772	$	8,010	Oil sales	$	26,423	$	3,662	$	66,195	$	11,672

Total liquids sales volume (MMcfe) (b)	Total liquids sales volume (MMcfe) (b)	26,327		20,399		51,219		35,727		Total liquids sales volume (MMcfe) (b)	30,439		18,002		81,658		53,729
Total liquids sales volume (Mbbl)	Total liquids sales volume (Mbbl)	4,388		3,399		8,536		5,954		Total liquids sales volume (Mbbl)	5,074		3,001		13,610		8,955
Total liquids sales	Total liquids sales	$	99,455	$	29,646	$	210,046	$	71,617	Total liquids sales	$	133,502	$	42,042	$	343,548	$	113,659

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)	$	996,884	$	816,241	$	2,079,969	$	1,773,623	Total natural gas and liquids sales, including cash settled derivatives (c)	$	1,155,031	$	853,164	$	3,235,000	$	2,626,787
Total sales volume (MMcfe)	Total sales volume (MMcfe)	420,595		345,647		835,785		730,717		Total sales volume (MMcfe)	495,013		366,138		1,330,798		1,096,855
Average realized price ($/Mcfe)	Average realized price ($/Mcfe)	$	2.37	$	2.36	$	2.49	$	2.43	Average realized price ($/Mcfe)	$	2.33	$	2.33	$	2.43	$	2.39

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

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

(c)Total natural gas and liquids sales, including cash settled derivatives, is also referred to in this report as adjusted operating revenues, a non-GAAP supplemental financial measure.

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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 ~~primarily includes~~consists of the costs of, and recoveries on, pipeline capacity ~~releases.~~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 June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020

		(Thousands, unless otherwise noted)									(Thousands, unless otherwise noted)
Total operating revenues	Total operating revenues	$	(260,116)	$	527,074	$	689,807	$	1,634,131	Total operating revenues	$	(1,464,838)	$	172,127	$	(775,031)	$	1,806,258
Add (deduct):	Add (deduct):									Add (deduct):
Loss (gain) on derivatives not designated as hedges		1,345,532		(26,426)		1,534,345		(415,862)
Loss on derivatives not designated as hedges										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	Net cash settlements (paid) received on derivatives not designated as hedges	(71,441)		315,393		(109,581)		561,129		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	Premiums (paid) received for derivatives that settled during the period	(9,579)		2,076		(19,305)		(1,479)		Premiums (paid) received for derivatives that settled during the period	(9,155)		2,083		(28,460)		604
Net marketing services and other	Net marketing services and other	(7,512)		(1,876)		(15,297)		(4,296)		Net marketing services and other	(8,349)		(317)		(23,646)		(4,613)
Adjusted operating revenues, a non-GAAP financial measure	Adjusted operating revenues, a non-GAAP financial measure	$	996,884	$	816,241	$	2,079,969	$	1,773,623	Adjusted operating revenues, a non-GAAP financial measure	$	1,155,031	$	853,164	$	3,235,000	$	2,626,787

Total sales volume (MMcfe)	Total sales volume (MMcfe)	420,595		345,647		835,785		730,717		Total sales volume (MMcfe)	495,013		366,138		1,330,798		1,096,855
Average realized price ($/Mcfe)	Average realized price ($/Mcfe)	$	2.37	$	2.36	$	2.49	$	2.43	Average realized price ($/Mcfe)	$	2.33	$	2.33	$	2.43	$	2.39

Sales Volume and Revenues


		Three Months Ended June 30,					Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
		2021		2020		%	2021		2020		%		2021		2020		%	2021		2020		%

		(Thousands, unless otherwise noted)											(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):	Sales volume by shale (MMcfe):											Sales volume by shale (MMcfe):
Marcellus (a)	Marcellus (a)	375,116		305,752		22.7	749,057		639,503		17.1	Marcellus (a)	449,650		318,740		41.1	1,198,707		958,243		25.1
Ohio Utica	Ohio Utica	44,034		38,430		14.6	83,963		88,205		(4.8)	Ohio Utica	41,226		46,523		(11.4)	125,189		134,728		(7.1)
Other	Other	1,445		1,465		(1.4)	2,765		3,009		(8.1)	Other	4,137		875		372.8	6,902		3,884		77.7
Total sales volume (b)	Total sales volume (b)	420,595		345,647		21.7	835,785		730,717		14.4	Total sales volume (b)	495,013		366,138		35.2	1,330,798		1,096,855		21.3

Average daily sales volume (MMcfe/d)	Average daily sales volume (MMcfe/d)	4,622		3,798		21.7	4,618		4,015		15.0	Average daily sales volume (MMcfe/d)	5,381		3,980		35.2	4,875		4,003		21.8

Operating revenues:	Operating revenues:											Operating revenues:
Sales of natural gas, NGLs and oil	Sales of natural gas, NGLs and oil	$	1,077,904	$	498,772	116.1	$	2,208,855	$	1,213,973	82.0	Sales of natural gas, NGLs and oil	$	1,784,050	$	598,992	197.8	$	3,992,905	$	1,812,965	120.2
(Loss) gain on derivatives not designated as hedges		(1,345,532)		26,426		(5,191.7)	(1,534,345)		415,862		(469.0)
Loss on derivatives not designated as hedges												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	Net marketing services and other	7,512		1,876		300.4	15,297		4,296		256.1	Net marketing services and other	8,349		317		2,533.8	23,646		4,613		412.6
Total operating revenues	Total operating revenues	$	(260,116)	$	527,074	(149.4)	$	689,807	$	1,634,131	(57.8)	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.

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

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

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil increased for the three months ended ~~June~~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 ~~three~~nine months ended ~~June~~September 30, 2021 and 2020, we paid ~~$71.4~~$729.4 million and received ~~$315.4 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 prior period sales volume decreases of 36 Bcfe from the 2020 Strategic Production Curtailments (defined below) and sales volume increases of 33 Bcfe from the assets acquired from the Chevron Acquisition (defined below). The 2020 Strategic Production Curtailments refers to our strategic decision to temporarily curtail approximately 1.4 Bcfe per day of gross production, equivalent to approximately 1.0 Bcfe per day of net production, beginning in May 2020 and ending in July 2020, at which time we began a moderated approach to bringing back on-line production that had been curtailed. The Chevron Acquisition refers to our acquisition of upstream assets from Chevron U.S.A. Inc. in the fourth quarter of 2020.

~~(Loss) gain on derivatives not designated as hedges.~~ For the three months ended June 30, 2021 and 2020, we recognized a loss of $1,345.5 million and a gain of $26.4 million, respectively, on derivatives not designated as hedges. The 2021 loss was related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices. The 2020 gain was related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices.

~~Net marketing services and other.~~ Net marketing services and other increased for the three months ended June 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.

~~Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020~~

~~Sales of natural gas, NGLs and oil.~~ Sales of natural gas, NGLs and oil increased for the six months ended June 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 six months ended June 30, 2021 and 2020, we paid $109.6 million and received $561.1$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 67101 Bcfe from the assets acquired in the Chevron Acquisition, sales volume increases of 74 Bcfe from the ~~Chevron~~assets acquired in the Alta Acquisition and prior period sales volume decreases of 3651 Bcfe from the 2020 Strategic Production Curtailments.

~~(Loss) gain~~Loss on derivatives not designated as hedges. For the ~~six~~nine months ended ~~June~~September 30, 2021 and 2020, we recognized a loss ~~of $1,534.3 million and a gain of $415.9 million, respectively,~~ on derivatives not designated as ~~hedges.~~hedges of $4,791.6 million and $11.3 million, respectively. The ~~2021 loss was~~losses were related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices. ~~The 2020 gain was related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices.~~

Net marketing services and other. Net marketing services and other increased for the ~~six~~nine months ended ~~June~~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.~~operators and third-party gathering revenues recognized on the midstream assets acquired in the Alta Acquisition.

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Operating Expenses

The following table presents information on our production-related operating expenses.


		Three Months Ended June 30,					Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
		2021		2020		%	2021		2020		%		2021		2020		%	2021		2020		%

		(Thousands, unless otherwise noted)											(Thousands, unless otherwise noted)
Operating expenses:	Operating expenses:											Operating expenses:
Gathering	Gathering	$	286,405	$	252,095	13.6	$	566,766	$	513,816	10.3	Gathering	$	316,612	$	274,196	15.5	$	883,378	$	788,012	12.1
Transmission	Transmission	130,235		119,515		9.0	255,107		266,677		(4.3)	Transmission	129,402		120,681		7.2	384,509		387,358		(0.7)
Processing	Processing	47,376		34,026		39.2	87,927		64,977		35.3	Processing	48,883		32,814		49.0	136,810		97,791		39.9
Lease operating expenses (LOE), excluding production taxes	Lease operating expenses (LOE), excluding production taxes	25,547		25,894		(1.3)	52,566		53,917		(2.5)	Lease operating expenses (LOE), excluding production taxes	32,141		28,758		11.8	84,707		82,675		2.5
Production taxes	Production taxes	21,999		12,435		76.9	42,210		24,792		70.3	Production taxes	25,682		10,912		135.4	67,892		35,704		90.2
Exploration	Exploration	1,779		876		103.1	2,728		1,799		51.6	Exploration	20,495		3,160		548.6	23,223		4,959		368.3
Selling, general and administrative	Selling, general and administrative	49,853		43,341		15.0	94,859		78,279		21.2	Selling, general and administrative	49,113		51,654		(4.9)	143,972		129,933		10.8

Production depletion	Production depletion	$	376,813	$	317,905	18.5	$	749,821	$	670,982	11.7	Production depletion	$	437,367	$	336,672	29.9	$	1,187,188	$	1,007,654	17.8
Other depreciation and depletion	Other depreciation and depletion	3,475		5,191		(33.1)	7,583		9,640		(21.3)	Other depreciation and depletion	5,509		4,355		26.5	13,092		13,995		(6.5)
Total depreciation and depletion	Total depreciation and depletion	$	380,288	$	323,096	17.7	$	757,404	$	680,622	11.3	Total depreciation and depletion	$	442,876	$	341,027	29.9	$	1,200,280	$	1,021,649	17.5

Per Unit ($/Mcfe):	Per Unit ($/Mcfe):											Per Unit ($/Mcfe):
Gathering	Gathering	$	0.68	$	0.73	(6.8)	$	0.68	$	0.70	(2.9)	Gathering	$	0.64	$	0.75	(14.7)	$	0.66	$	0.72	(8.3)
Transmission	Transmission	0.31		0.35		(11.4)	0.31		0.36		(13.9)	Transmission	0.26		0.33		(21.2)	0.29		0.35		(17.1)
Processing	Processing	0.11		0.10		10.0	0.11		0.09		22.2	Processing	0.10		0.09		11.1	0.10		0.09		11.1
LOE, excluding production taxes	LOE, excluding production taxes	0.06		0.07		(14.3)	0.06		0.07		(14.3)	LOE, excluding production taxes	0.06		0.08		(25.0)	0.06		0.08		(25.0)
Production taxes	Production taxes	0.05		0.04		25.0	0.05		0.03		66.7	Production taxes	0.05		0.03		66.7	0.05		0.03		66.7

Exploration												Exploration	0.04		0.01		300.0	0.02		—		—
Selling, general and administrative	Selling, general and administrative	0.12		0.13		(7.7)	0.11		0.11		—	Selling, general and administrative	0.10		0.14		(28.6)	0.11		0.12		(8.3)
Production depletion	Production depletion	0.90		0.92		(2.2)	0.90		0.92		(2.2)	Production depletion	0.88		0.92		(4.3)	0.89		0.92		(3.3)

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

Gathering. Gathering expense increased on an absolute basis for the three months ended June 30, 2021 compared to the same period in 2020 due to increased sales volume, additional gathering capacity acquired from the Chevron Acquisition and a higher gathering rate structure as a result of the Consolidated GGA (defined and discussed in Note 8 to the Condensed Consolidated Financial Statements). We expect to realize fee relief and a lower gathering rate structure from the Consolidated GGA beginning with the Mountain Valley Pipeline (MVP) in-service date.

~~Gathering expense decreased on a per Mcfe basis for the three months ended June~~September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume ~~which resulted~~from the assets acquired in ~~utilization of lower overrun rates as part of~~ the ~~Consolidated GGA,~~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 ~~from~~in the Alta Acquisition and Chevron Acquisition.

Transmission. Transmission expense increased on an absolute basis for the three months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to ~~released~~additional capacity acquired as part of the Alta Acquisition and fewer capacity releases on ~~and credits received from,~~ the ~~Texas Eastern Transmission Pipeline in 2020.~~Tennessee Gas Pipeline. Transmission expense decreased on a per Mcfe basis for the three months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume, some of which, ~~does not have associated~~particularly sales volume from assets acquired in the Alta Acquisition and Chevron Acquisition, has lower transmission expense ~~such~~on a per Mcfe basis as ~~the assets acquired from the Chevron Acquisition.~~compared to our historical transmission portfolio.

Processing. Processing expense increased on an absolute and per Mcfe basis for the three months ended ~~June~~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.

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Production taxes. Production taxes increased on an absolute and per Mcfe basis for the three months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to increased ~~Pennsylvania impact fees and~~ West Virginia severance taxes as a result of increased production from the Chevron Acquisition and higher ~~prices.~~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.

~~Selling, general and administrative.~~Exploration. ~~Selling, general and administrative expense~~Exploration increased on an absolute and per Mcfe basis for thethree months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to ~~higher long-term incentive compensation costs due to changes in~~our purchase of seismic data following the ~~fair value~~completion of ~~awards.~~the Alta Acquisition.

Depreciation and depletion. Production depletion expense increased on an absolute basis for the three months ended ~~June~~September 30, 2021 compared to the same period in 2020 due to increased sales volume, partly offset by a lower annual depletion rate. Production depletion expense decreased on a per Mcfe basis for the three months ended ~~June~~September 30, 2021 compared to the same period in 2020 due to a lower annual depletion rate.

Amortization of intangible assets. Amortization of intangible assets for the three months ended ~~June~~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 ~~June~~September 30, 2021, we recognized a gain on ~~sale~~sale/exchange of long-lived assets of ~~$16.8~~$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 ~~June~~September 30, 2020, we recognized a loss on sale/exchange of long-lived assets of ~~$49.2~~$4.7 million ~~of which $6.7 million~~ related primarily to the 2020 Asset Exchange Transactions (defined and ~~$42.5 million related~~discussed in Note 9 to the Condensed Consolidated Financial Statements), partly offset by changes in the fair value of the Contingent Consideration from the 2020 Divestiture. See Note 9 to the Condensed Consolidated Financial Statements.

Impairment and expiration of leases. Impairment and expiration of leases for the three months ended ~~June~~September 30, 2021 was ~~$25.6~~$41.1 million compared to ~~$41.3~~$50.4 million for the same period in 2020. The decrease was driven by higher lease expirations in 2020 due to changes in market conditions.

Other operating expenses. Other operating expenses for the three months ended ~~June~~September 30, 2021 of ~~$5.2~~$38.8 million were attributable primarily to transaction costs associated with the ~~Chevron Acquisition and~~ Alta ~~Acquisition (defined and discussed in Note 10 to the Condensed Consolidated Financial Statements).~~Acquisition. Other operating expenses for the three months ended ~~June~~September 30, 2020 of ~~$4.7~~$6.5 million were attributable primarily to ~~transaction~~changes in legal reserves, including settlements and reorganization costs.

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

Gathering. Gathering expense increased on an absolute basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due to increased sales volume, additional gathering capacity acquired from the Chevron Acquisition and a higher gathering rate structure as a result of the Consolidated GGA. We expect to realize fee relief and a lower gathering rate structure from the Consolidated GGA beginning with the MVP in-service date.

volume. Gathering expense decreased on a per Mcfe basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume, which resulted in our utilization of lower overrun rates as part of the Consolidated GGA (defined and discussed in Note 8 to the Condensed Consolidated Financial Statements), and a lower gathering rate structure on the assets acquired ~~from~~in the Chevron Acquisition and Alta Acquisition.

Transmission. Transmission expense decreased on an absolute basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to released capacity on, and credits received from, the Texas Eastern Transmission Pipeline in 2020 and released capacity on the Tennessee Gas ~~Pipeline.~~Pipeline, partly offset by additional capacity acquired as part of the Alta Acquisition. Transmission expense decreased on a per Mcfe basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to increased sales volume, some of which, ~~does not have associated transmission expense, such as the assets acquired~~particularly volume from the Chevron ~~Acquisition.~~Acquisition and Alta 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 ~~six~~nine months ended ~~June~~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 ~~six~~nine months ended ~~June~~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 from the Chevron Acquisition and higher prices as well as increased Pennsylvania impact fees as a result of higher ~~prices.~~

prices and additional wells acquired in the Alta Acquisition and Chevron Acquisition.

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Exploration. Exploration increased on an absolute and per Mcfe basis for thenine 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.

Selling, general and administrative. Selling, general and administrative expense increased on an absolute basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due primarily to higher long-term incentive compensation costs due to changes in the fair value of ~~awards.~~awards as well as higher litigation expense.

Depreciation and depletion. Production depletion expense increased on an absolute basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due to increased sales volume, partly offset by a lower annual depletion rate. Production depletion expense decreased on a per Mcfe basis for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same period in 2020 due to a lower annual depletion rate.

Amortization of intangible assets. Amortization of intangible assets for the ~~six~~nine months ended ~~June~~September 30, ~~2021~~2020 was ~~$15.0~~$22.4 million. ~~The~~Our intangible assets were fully amortized in the fourth quarter of 2020.

(Gain) loss on sale/exchange of long-lived assets. During the ~~six~~nine months ended ~~June~~September 30, 2021, we recognized a gain on ~~sale~~sale/exchange of long-lived assets of ~~$18.0~~$18.4 million related primarily to changes in the fair value of the Contingent Consideration from the 2020 Divestiture. During the ~~six~~nine months ended ~~June~~September 30, 2020, we recognized a loss on sale/exchange of long-lived assets of ~~$98.1~~$102.7 million, of which ~~$55.6~~$67.2 million related to the 2020 Asset Exchange Transactions and ~~$42.5~~$35.5 million related to asset sales, including the 2020 Divestiture. See Note 9 to the Condensed Consolidated Financial Statements.

Impairment and expiration of leases. Impairment and expiration of leases for the ~~six~~nine months ended ~~June~~September 30, 2021 was ~~$42.4~~$83.5 million compared to ~~$95.0~~$145.5 million for the same period in 2020. The decrease was driven by higher lease expirations in 2020 due to changes in market conditions.

Other operating expenses. Other operating expenses for the ~~six~~nine months ended ~~June~~September 30, 2021 of ~~$14.7~~$53.4 million were attributable primarily to transaction costs associated with the ~~Chevron~~Alta Acquisition and ~~Alta Acquisition and~~Chevron Acquisition. Other operating expenses for the nine months ended September 30, 2020 of $11.3 million were attributable primarily to changes in legal reserves, including ~~settlements. Other operating expenses for the six months ended June 30, 2020 of $4.7 million were attributable primarily to~~settlements, reorganization and transaction ~~and reorganization~~ costs.

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~~$187.2 million. See Note 8 to the Condensed Consolidated Financial Statements.

(Income) loss from investments. For the three and ~~six~~nine months ended ~~June~~September 30, 2021, we recognized income on our investment 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 ~~$8.51~~$10.14 and $8.04 as of ~~June~~September 30, 2021 and December 31, 2020, respectively.

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

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

Loss on debt extinguishment. During the ~~three and six~~nine months ended ~~June~~September 30, 2021, we recognized a loss on debt extinguishment of ~~$5.3 million and~~ $9.8 million ~~respectively,~~ 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 ~~six~~nine months ended ~~June~~September 30, 2020, we recognized a loss on debt extinguishment of ~~$0.4~~$3.7 million and ~~$17.0~~$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 for the three and ~~six~~nine months ended ~~June~~September 30, 2021 compared to the same periods in 2020 due to increased interest incurred on new debt, 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. See Note 6 to the Condensed Consolidated Financial Statements.

~~Table of Contents~~

~~EQT CORPORATION AND SUBSIDIARIES~~

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

Income tax 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, we expect to spend approximately ~~$1,100~~$1,075 million to ~~$1,175~~$1,125 million in total capital expenditures, excluding amounts attributable to noncontrolling interests, which are expected to be funded by operating cash flow and, if required, borrowings under our credit facility. Sales volume in 2021 is expected to be ~~1,800~~1,840 Bcfe to ~~1,875~~1,870 Bcfe. ~~The planned capital expenditures and expected sales volume include amounts attributable to the assets acquired from the Alta Acquisition, which closed on July 21, 2021.~~

Operating Activities. Net cash provided by operating activities was ~~$443~~$492 million for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to ~~$947~~$1,132 million for the same period in 2020. The decrease was due primarily to ~~decreased~~the cash settlements ~~received~~paid on derivatives not designated as hedges, ~~and~~ unfavorable timing of working capital payments, including increased payments for collateral and margin deposits associated with ~~the Company's~~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.

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.

Investing Activities. Net cash used in investing activities was ~~$675~~$1,715 million for the ~~six~~nine months ended ~~June~~September 30, 2021 compared to ~~$349~~$623 million for the same period in 2020. The increase was due primarily to cash paid for acquisitions in 2021 and ~~cash~~proceeds received ~~in 2020~~ from the sale of assets and the Equitrans Share Exchange in 2020, partly offset by lower capital expenditures.

The following table summarizes our capital expenditures.


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020

		(Millions)									(Millions)
Reserve development	Reserve development	$	178	$	235	$	367	$	458	Reserve development	$	242	$	176	$	609	$	634
Land and lease (a)	Land and lease (a)	31		28		54		50		Land and lease (a)	27		38		81		88
Capitalized overhead	Capitalized overhead	14		13		27		24		Capitalized overhead	15		15		42		39
Capitalized interest	Capitalized interest	4		4		8		8		Capitalized interest	5		5		13		13
Other production infrastructure	Other production infrastructure	19		19		24		20		Other production infrastructure	7		11		31		31
Other corporate items	Other corporate items	—		4		4		5		Other corporate items	1		3		5		8
Total capital expenditures	Total capital expenditures	246		303		484		565		Total capital expenditures	297		248		781		813
Deduct: Non-cash items (b)		(27)		(47)		(14)		(53)
(Deduct) add back: Non-cash items (b)										(Deduct) add back: Non-cash items (b)	(60)		28		(74)		(25)
Total cash capital expenditures	Total cash capital expenditures	$	219	$	256	$	470	$	512	Total cash capital expenditures	$	237	$	276	$	707	$	788

(a)Capital expenditures attributable to noncontrolling interests were ~~$3.8~~$0.7 million and ~~$5.1~~$5.7 million for the three and ~~six~~nine months ended ~~June~~September 30, 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 reversal of the prior period accrual as well as the current period estimate.

~~Financing Activities.~~ Net cash provided by financing activities was $544 million for the six months ended June 30, 2021 compared to net cash used in financing activities of $600 million for the same period in 2020. For the six months ended June 30, 2021, the primary source of financing cash flows was net proceeds from the issuance of debt, and the primary uses of financing

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Financing Activities. Net cash provided by financing activities was $1,228 million for the nine months ended September 30, 2021 compared to net cash used in financing activities of $500 million for the same period in 2020. For the nine months ended September 30, 2021, the primary sources of financing cash flows were net ~~repayments~~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 ~~six~~nine months ended ~~June~~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.

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 or repurchase our outstanding debt or equity securities through cash purchases in the open market or privately negotiated transactions. The amounts involved in any such transactions may be material. Additionally, we plan to dispose of our remaining retained shares of Equitrans Midstream's common stock and use the proceeds to reduce our debt.

Security Ratings and Financing Triggers

The table below reflects the credit ratings and rating outlooks assigned to our debt instruments as of ~~July 27,~~October 22, 2021. 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 of what is deemed investment grade.

Rating agency

Senior notes

Outlook

Moody's Investors Service (Moody's)

Ba1

Stable

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

BB+

Positive

Fitch Ratings Service (Fitch)

BB+

Stable

Changes in credit ratings may affect our access to the capital markets, the cost of short-term debt through interest rates and fees under our lines of credit, the interest rate on ~~the~~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 ~~over the counter (OTC)~~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 ~~July 27,~~October 22, 2021, 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 ~~July 27,~~October 22, 2021, such assurances could be up to approximately ~~$1.2~~$1.1 billion, inclusive of letters of credit, OTC derivative instrument margin deposits and other collateral posted of approximately ~~$1.2~~$0.8 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.

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EQT CORPORATION AND SUBSIDIARIES

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

Our debt agreements and other financial obligations contain various provisions that, if not complied with, could result in default or event of default under 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 ~~June~~September 30, 2021, we were in compliance with all debt provisions and covenants under our debt agreements.

~~Table of Contents~~

~~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 ~~July 23,~~October 22, 2021.


		2021 (a)		2022		2023		2024			2021 (a)		2022		2023		2024
Swaps:	Swaps:									Swaps:
Volume (MMDth)	Volume (MMDth)	741		1,277		166		2		Volume (MMDth)	314		1,102		166		2
Average Price ($/Dth)	Average Price ($/Dth)	$	2.77	$	2.77	$	2.53	$	2.67	Average Price ($/Dth)	$	2.39	$	2.59	$	2.53	$	2.67
Calls – Net Short:	Calls – Net Short:									Calls – Net Short:
Volume (MMDth)	Volume (MMDth)	180		391		77		15		Volume (MMDth)	86		406		77		15
Average Short Strike Price ($/Dth)	Average Short Strike Price ($/Dth)	$	2.92	$	2.96	$	2.89	$	3.11	Average Short Strike Price ($/Dth)	$	2.92	$	2.98	$	2.89	$	3.11
Puts – Net Long:	Puts – Net Long:									Puts – Net Long:
Volume (MMDth)	Volume (MMDth)	105		169		69		15		Volume (MMDth)	53		183		69		15
Average Long Strike Price ($/Dth)	Average Long Strike Price ($/Dth)	$	2.59	$	2.65	$	2.40	$	2.45	Average Long Strike Price ($/Dth)	$	2.58	$	2.68	$	2.40	$	2.45
Fixed Price Sales (b):	Fixed Price Sales (b):									Fixed Price Sales (b):
Volume (MMDth)	Volume (MMDth)	36		4		3		—		Volume (MMDth)	17		4		3		—
Average Price ($/Dth)	Average Price ($/Dth)	$	2.49	$	2.38	$	2.38	$	—	Average Price ($/Dth)	$	2.49	$	2.38	$	2.38	$	—

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

(b)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.

For 2021 ~~(July~~(October 1 through December 31), 2022, 2023 and 2024, we have natural gas sales agreements for approximately 95 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 of 2021 and during the period beginning October 1, 2021 and ending October 22, 2021, we purchased $54 million and $18 million, respectively, 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.

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 matter currently pending against 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 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. 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.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk and Derivative Instruments. Our primary market risk exposure is the volatility of future prices for natural gas and NGLs. Due to the volatility of commodity prices, we are unable to predict future potential movements in the market prices for natural gas and NGLs at our ultimate sales points and, thus, cannot predict the ultimate impact of prices on our operations. Prolonged low, or significant, extended declines in, natural gas and NGLs prices could adversely affect, among other things, our development plans, which would decrease the pace of development and the level of our proved reserves. 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, 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.~~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.

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 natural gas on ~~June~~September 30, 2021 and December 31, 2020 would increase the fair value of our natural gas derivative commodity instruments by approximately ~~$728~~$836 million and $501 million, respectively. A hypothetical increase of 10% in the market price of natural gas on ~~June~~September 30, 2021 and December 31, 2020 would decrease the fair value of our natural gas derivative commodity instruments by approximately ~~$735~~$838 million and $495 million, respectively. For purposes of this analysis, we applied the 10% change in the market price of natural gas on ~~June~~September 30, 2021 and December 31, 2020 to our natural gas derivative commodity instruments as of ~~June~~September 30, 2021 and December 31, 2020 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 ~~fluctuate~~fluctuates based on changes to market interest rates. A 1% increase in interest rates on the borrowings under our credit facility during the ~~six~~nine months ended ~~June~~September 30, 2021 would have increased interest expense by approximately $2$5 million.

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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. 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 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 ~~22%~~19%, or ~~$514~~$1,211 million, of our OTC derivative contracts outstanding at ~~June~~September 30, 2021 had a positive fair value. Approximately 47%, or $456 million, of our OTC derivative contracts outstanding at December 31, 2020 had a positive fair value.

As of ~~June~~September 30, 2021, 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 ~~June~~September 30, 2021, 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 with the participation of management, including our Principal Executive Officer and Principal Financial Officer, an evaluation 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 and 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 internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred during the ~~second~~third quarter of 2021 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 matter currently pending against us will not materially affect our financial condition, results of operations or liquidity.

Environmental Proceedings

~~There have been no material updates~~

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 ~~matters previously disclosed~~West Virginia Department of Environmental Protection (WVDEP) and took corrective actions to ensure that the Stone pads are in ~~Item 3, "Legal Proceedings"~~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 ~~Annual Report on~~ ~~Form 10-K~~ ~~for the year ended December 31, 2020,~~financial position, results of operations or ~~the matters previously disclosed in Part II, Item 1 , "Legal Proceedings" of our subsequently filed Quarterly Report on Form 10-Q.~~liquidity.

~~See also “Commitments and Contingencies” under Part I, Item 2. “Management's Discussion and Analysis of Financial Condition and Results of Operations.”~~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.

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Item 1A. Risk Factors

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

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

~~We did not repurchase any~~Conversion of Certain Convertible Notes

In September 2021, 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 aggregate principal thereof (the Converted Notes). On September 15, 2021, we settled the conversion of the Convertible Notes with a principal amount of $5 thousand by issuing to the converting holders of the Convertible 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. 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.

Repurchases of Equity Securities

The following table sets forth our repurchases of equity securities registered under Section 12 of the ~~Securities~~ Exchange Act ~~of 1934, as amended,~~that have occurred during the three months ended ~~June~~September 30, 2021.


	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	—	—

(a)Reflects the number of shares we have withheld to pay taxes upon vesting of restricted stock.

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Item 6. Exhibits

Exhibit No.

Description

Method of Filing

2.01*

Membership Interest Purchase Agreement, dated May 5, 2021, among Alta Resources Development, LLC, a Delaware limited liability company, Alta Marcellus Development, LLC, a Delaware limited liability company, ARD Operating, LLC, a Delaware limited liability company, EQT Acquisition HoldCo LLC, a Delaware limited liability company, and EQT Corporation.

~~Incorporated herein by reference to Exhibit 2.1 to Form 8-K (#001-3551) filed on May 7, 2021.~~

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.

~~4.01(a)~~*10.01(a)

~~Twelfth Supplemental Indenture,~~Letter Agreement (Ealy North – July), dated ~~May 17, 2021, between EQT Corporation and The Bank of New York Mellon, as trustee, pursuant to which the 3.125% Senior Notes due 2026 were issued.~~

~~Incorporated by reference to Exhibit 4.3 to Form 8-K (#001-3551) filed on May 18, 2021.~~

~~4.01(b)~~

~~Thirteenth Supplemental Indenture, dated May 17, 2021, between EQT Corporation and The Bank of New York Mellon, as trustee, pursuant to which the 3.625% Senior Notes due 2031 were issued.~~

~~Incorporated by reference to Exhibit 4.4 to Form 8-K (#001-3551) filed on May 18, 2021.~~

~~10.01~~

Extension Agreement and First Amendment to Second Amended and Restated Credit Agreement, dated April 23, 2021, among EQT Corporation, PNC Bank, National Association, as administrative agent, and each lender party thereto.

~~Incorporated herein by reference to Exhibit 10.1 to Form 8-K (#001-3551) filed on April 26, 2021.~~

10.02*

~~Purchase Agreement, dated May~~July 10, 2021, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC and ~~BofA Securities, Inc.~~EQM Gathering Opco, LLC, amending that certain Gas Gathering and ~~J.P. Morgan Securities LLC,~~Compression Agreement, dated February 26, 2020, as ~~representatives of the several initial purchasers named in Schedule 1 thereto.~~amended.

~~Incorporated herein by reference to~~Filed herewith as Exhibit ~~10.1 to Form 8-K (#001-3551) filed on May 14, 2021.~~10.01(a).

~~10.03~~*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 in 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 aan unredacted, supplemental copy of(including any omitted schedule or ~~attachment~~attachment) to the Securities and Exchange Commission upon request. Redactions and omissions are designated with brackets containing asterisks.

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SIGNATURE

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


						EQT CORPORATION
						(Registrant)


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

Date: ~~July 29,~~October 28, 2021

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		Page No.
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited):
	Statements of Condensed Consolidated Operations	3
	Statements of Condensed Consolidated Comprehensive (Loss) Income	4
	Condensed Consolidated Balance Sheets	5
	Statements of Condensed Consolidated Cash Flows	6
	Statements of Condensed Consolidated Equity	7
	Notes to the Condensed Consolidated Financial Statements	9
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	1922
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3033
Item 4.	Controls and Procedures	3135

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	3236
Item 1A.	Risk Factors	3237
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3237
Item 6.	Exhibits	3338

Signature		3439