UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q
 
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED JUNE 30, 20222023
or
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, Pennsylvania15222
(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 classTrading symbol(s)Name of each exchange on which registered
Common Stock, no par valueEQTNew 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 filerAccelerated filer
Non-accelerated filerSmaller 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 22, 2022, 369,956,79021, 2023, 361,657,681 shares of common stock, no par value, of the registrant were outstanding.


Table of Contents


TABLE OF CONTENTS
Page No.
 
 
 
 
 
 

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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
June 30,
Six Months Ended
June 30,
2022202120222021 2023202220232022
(Thousands, except per share amounts) (Thousands, except per share amounts)
Operating revenues:Operating revenues:Operating revenues:
Sales of natural gas, natural gas liquids and oilSales of natural gas, natural gas liquids and oil$3,365,211 $1,077,904 $5,851,835 $2,208,855 Sales of natural gas, natural gas liquids and oil$848,325 $3,365,211 $2,678,683 $5,851,835 
Loss on derivatives(845,095)(1,345,532)(3,922,732)(1,534,345)
Gain (loss) on derivativesGain (loss) on derivatives164,386 (845,095)989,238 (3,922,732)
Net marketing services and otherNet marketing services and other7,392 7,512 19,295 15,297 Net marketing services and other6,040 7,392 11,901 19,295 
Total operating revenuesTotal operating revenues2,527,508 (260,116)1,948,398 689,807 Total operating revenues1,018,751 2,527,508 3,679,822 1,948,398 
Operating expenses:Operating expenses:Operating expenses:
Transportation and processingTransportation and processing539,704 464,016 1,055,808 909,800 Transportation and processing523,162 539,704 1,038,146 1,055,808 
ProductionProduction82,556 47,546 153,568 94,776 Production55,038 82,556 102,978 153,568 
ExplorationExploration1,741 1,779 2,513 2,728 Exploration1,203 1,741 2,155 2,513 
Selling, general and administrativeSelling, general and administrative59,276 49,853 128,372 94,859 Selling, general and administrative60,163 59,276 112,057 128,372 
Depreciation and depletionDepreciation and depletion429,143 380,288 851,241 757,404 Depreciation and depletion395,684 429,143 783,369 851,241 
Gain on sale/exchange of long-lived assets(981)(16,816)(2,190)(18,023)
(Gain) loss on sale/exchange of long-lived assets(Gain) loss on sale/exchange of long-lived assets(225)(981)16,303 (2,190)
Impairment of contract assetImpairment of contract asset— — 184,945 — Impairment of contract asset— — — 184,945 
Impairment and expiration of leasesImpairment and expiration of leases47,048 25,634 77,039 42,391 Impairment and expiration of leases5,325 47,048 15,871 77,039 
Other operating expensesOther operating expenses7,120 5,225 23,467 14,668 Other operating expenses13,394 7,120 33,056 23,467 
Total operating expensesTotal operating expenses1,165,607 957,525 2,474,763 1,898,603 Total operating expenses1,053,744 1,165,607 2,103,935 2,474,763 
Operating income (loss)1,361,901 (1,217,641)(526,365)(1,208,796)
Operating (loss) incomeOperating (loss) income(34,993)1,361,901 1,575,887 (526,365)
(Income) loss from investments(Income) loss from investments(3,577)(11,829)17,208 (23,677)(Income) loss from investments(1,092)(3,577)(5,856)17,208 
Dividend and other incomeDividend and other income(7,313)(3,765)(10,909)(7,069)Dividend and other income(562)(7,313)(737)(10,909)
Loss on debt extinguishment104,348 5,332 111,271 9,756 
Interest expense65,985 72,254 133,887 142,727 
Income (loss) before income taxes1,202,458 (1,279,633)(777,822)(1,330,533)
Income tax expense (benefit)308,234 (346,311)(157,463)(359,270)
Net income (loss)894,224 (933,322)(620,359)(971,263)
Less: Net income (loss) attributable to noncontrolling interests2,863 (62)4,328 (576)
Net income (loss) attributable to EQT Corporation$891,361 $(933,260)$(624,687)$(970,687)
Loss (gain) on debt extinguishmentLoss (gain) on debt extinguishment5,462 104,348 (1,144)111,271 
Interest expense, netInterest expense, net39,883 65,985 86,429 133,887 
(Loss) income before income taxes(Loss) income before income taxes(78,684)1,202,458 1,497,195 (777,822)
Income tax (benefit) expenseIncome tax (benefit) expense(11,818)308,234 344,828 (157,463)
Net (loss) incomeNet (loss) income(66,866)894,224 1,152,367 (620,359)
Less: Net (loss) income attributable to noncontrolling interestsLess: Net (loss) income attributable to noncontrolling interests(240)2,863 445 4,328 
Net (loss) income attributable to EQT CorporationNet (loss) income attributable to EQT Corporation$(66,626)$891,361 $1,151,922 $(624,687)
Income (loss) per share of common stock attributable to EQT Corporation:  
(Loss) income per share of common stock attributable to EQT Corporation:(Loss) income per share of common stock attributable to EQT Corporation:  
Basic:Basic:    Basic:    
Weighted average common stock outstandingWeighted average common stock outstanding369,866 279,156 372,023 278,996 Weighted average common stock outstanding361,982 369,866 361,721 372,023 
Net income (loss)$2.41 $(3.34)$(1.68)$(3.48)
Diluted:    
Net (loss) income attributable to EQT CorporationNet (loss) income attributable to EQT Corporation$(0.18)$2.41 $3.18 $(1.68)
Diluted (Note 7):Diluted (Note 7):    
Weighted average common stock outstandingWeighted average common stock outstanding407,303 279,156 372,023 278,996 Weighted average common stock outstanding361,982 407,303 393,435 372,023 
Net income (loss)$2.19 $(3.34)$(1.68)$(3.48)
Net (loss) income attributable to EQT CorporationNet (loss) income attributable to EQT Corporation$(0.18)$2.19 $2.94 $(1.68)

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
STATEMENTS OF CONDENSED CONSOLIDATED COMPREHENSIVE (LOSS) INCOME (LOSS) (UNAUDITED)

Three Months Ended
June 30,
Six Months Ended
June 30,
 2022202120222021
 (Thousands)
Net income (loss)$894,224 $(933,322)$(620,359)$(971,263)
Other comprehensive income, net of tax:    
Other postretirement benefits liability adjustment, net of tax expense: $21, $27, $41 and $5464 81 127 161 
Comprehensive income (loss)894,288 (933,241)(620,232)(971,102)
Less: Comprehensive income (loss) attributable to noncontrolling interests2,863 (62)4,328 (576)
Comprehensive income (loss) attributable to EQT Corporation$891,425 $(933,179)$(624,560)$(970,526)
Three Months Ended
June 30,
Six Months Ended
June 30,
 2023202220232022
 (Thousands)
Net (loss) income$(66,866)$894,224 $1,152,367 $(620,359)
Other comprehensive income, net of tax:    
Other postretirement benefits liability adjustment, net of tax expense: $14, $21, $29 and $4149 64 213 127 
Comprehensive (loss) income(66,817)894,288 1,152,580 (620,232)
Less: Comprehensive (loss) income attributable to noncontrolling interests(240)2,863 445 4,328 
Comprehensive (loss) income attributable to EQT Corporation$(66,577)$891,425 $1,152,135 $(624,560)

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

June 30, 2022December 31, 2021June 30, 2023December 31, 2022
(Thousands) (Thousands)
ASSETSASSETS  ASSETS  
Current assets:Current assets:  Current assets:  
Cash and cash equivalentsCash and cash equivalents$43,745 $113,963 Cash and cash equivalents$1,215,492 $1,458,644 
Accounts receivable (less provision for doubtful accounts: $475 and $321)2,058,953 1,438,031 
Accounts receivable (less provision for doubtful accounts: $166 and $605)Accounts receivable (less provision for doubtful accounts: $166 and $605)475,211 1,608,089 
Derivative instruments, at fair valueDerivative instruments, at fair value1,409,199 543,337 Derivative instruments, at fair value683,612 812,371 
Prepaid expenses and otherPrepaid expenses and other573,732 191,435 Prepaid expenses and other51,254 135,337 
Total current assetsTotal current assets4,085,629 2,286,766 Total current assets2,425,569 4,014,441 
Property, plant and equipmentProperty, plant and equipment26,640,549 26,016,092 Property, plant and equipment28,299,959 27,393,919 
Less: Accumulated depreciation and depletionLess: Accumulated depreciation and depletion8,438,478 7,597,172 Less: Accumulated depreciation and depletion9,976,460 9,226,586 
Net property, plant and equipmentNet property, plant and equipment18,202,071 18,418,920 Net property, plant and equipment18,323,499 18,167,333 
Contract asset29,250 410,000 
Other assetsOther assets304,714 491,702 Other assets524,409 488,152 
Total assetsTotal assets$22,621,664 $21,607,388 Total assets$21,273,477 $22,669,926 
LIABILITIES AND EQUITYLIABILITIES AND EQUITY  LIABILITIES AND EQUITY  
Current liabilities:Current liabilities:  Current liabilities:  
Current portion of debtCurrent portion of debt$440,900 $1,060,970 Current portion of debt$413,917 $422,632 
Accounts payableAccounts payable1,700,406 1,339,251 Accounts payable1,049,895 1,574,610 
Derivative instruments, at fair valueDerivative instruments, at fair value4,568,003 2,413,608 Derivative instruments, at fair value485,224 1,393,487 
Other current liabilitiesOther current liabilities480,438 372,412 Other current liabilities233,790 341,491 
Total current liabilitiesTotal current liabilities7,189,747 5,186,241 Total current liabilities2,182,826 3,732,220 
Credit facility borrowings100,000 — 
Senior notesSenior notes4,409,727 4,435,782 Senior notes4,172,232 5,167,849 
Note payable to EQM Midstream Partners, LPNote payable to EQM Midstream Partners, LP91,442 94,320 Note payable to EQM Midstream Partners, LP85,404 88,484 
Deferred income taxesDeferred income taxes742,670 907,306 Deferred income taxes1,877,584 1,442,406 
Other liabilities and creditsOther liabilities and credits997,988 1,012,740 Other liabilities and credits910,403 1,025,639 
Total liabilitiesTotal liabilities13,531,574 11,636,389 Total liabilities9,228,449 11,456,598 
Equity:Equity:  Equity:  
Common stock, no par value,
shares authorized: 640,000, shares issued: 369,912 and 377,432
9,948,646 10,071,820 
Treasury stock, shares at cost: 192 and 1,033(2,848)(18,046)
Accumulated deficit(880,127)(94,400)
Common stock, no par value,
shares authorized: 640,000, shares issued: 361,654 and 365,363
Common stock, no par value,
shares authorized: 640,000, shares issued: 361,654 and 365,363
9,790,855 9,891,890 
Retained earningsRetained earnings2,217,698 1,283,578 
Accumulated other comprehensive lossAccumulated other comprehensive loss(4,484)(4,611)Accumulated other comprehensive loss(2,781)(2,994)
Total common shareholders' equityTotal common shareholders' equity9,061,187 9,954,763 Total common shareholders' equity12,005,772 11,172,474 
Noncontrolling interest in consolidated subsidiariesNoncontrolling interest in consolidated subsidiaries28,903 16,236 Noncontrolling interest in consolidated subsidiaries39,256 40,854 
Total equityTotal equity9,090,090 9,970,999 Total equity12,045,028 11,213,328 
Total liabilities and equityTotal liabilities and equity$22,621,664 $21,607,388 Total liabilities and equity$21,273,477 $22,669,926 

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
STATEMENTS OF CONDENSED CONSOLIDATED CASH FLOWS (UNAUDITED)

Six Months Ended June 30,Six Months Ended June 30,
20222021 20232022
(Thousands)(Thousands)
Cash flows from operating activities:Cash flows from operating activities:Cash flows from operating activities:
Net loss$(620,359)$(971,263)
Adjustments to reconcile net loss to net cash provided by operating activities:  
Deferred income tax benefit(164,677)(359,229)
Net income (loss)Net income (loss)$1,152,367 $(620,359)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:Adjustments to reconcile net income (loss) to net cash provided by operating activities:  
Deferred income tax expense (benefit)Deferred income tax expense (benefit)353,912 (164,677)
Depreciation and depletionDepreciation and depletion851,241 757,404 Depreciation and depletion783,369 851,241 
Impairments of long-lived assets and gain on sale/exchange of long-lived assets259,794 24,368 
Loss (income) from investments17,208 (23,677)
Loss on debt extinguishment111,271 9,756 
Impairment of long-lived assets and loss/gain on sale/exchange of long-lived assetsImpairment of long-lived assets and loss/gain on sale/exchange of long-lived assets32,174 259,794 
(Income) loss from investments(Income) loss from investments(5,856)17,208 
(Gain) loss on debt extinguishment(Gain) loss on debt extinguishment(1,144)111,271 
Share-based compensation expenseShare-based compensation expense21,558 13,515 Share-based compensation expense23,333 21,558 
Distribution of earnings from equity method investmentsDistribution of earnings from equity method investments16,616 13,640 
Amortization, accretion and otherAmortization, accretion and other31,256 12,739 Amortization, accretion and other7,941 17,616 
Loss on derivatives3,922,732 1,534,345 
Net cash settlements paid on derivatives(2,639,271)(109,581)
Net premiums received on derivative instruments14,073 3,654 
(Gain) loss on derivatives(Gain) loss on derivatives(989,238)3,922,732 
Net cash settlements received (paid) on derivativesNet cash settlements received (paid) on derivatives369,247 (2,639,271)
Net premiums (paid) received on derivative instrumentsNet premiums (paid) received on derivative instruments(164,843)14,073 
Changes in other assets and liabilities:Changes in other assets and liabilities:  Changes in other assets and liabilities:  
Accounts receivableAccounts receivable(626,620)(99,564)Accounts receivable1,128,033 (626,620)
Accounts payableAccounts payable360,208 111,191 Accounts payable(532,223)360,208 
Other current assetsOther current assets(190,358)(422,618)Other current assets84,082 (190,358)
Other items, netOther items, net(96,416)(37,646)Other items, net(157,889)(96,416)
Net cash provided by operating activitiesNet cash provided by operating activities1,251,640 443,394 Net cash provided by operating activities2,099,881 1,251,640 
Cash flows from investing activities:Cash flows from investing activities:  Cash flows from investing activities:  
Capital expendituresCapital expenditures(684,972)(470,259)Capital expenditures(981,795)(684,972)
Cash paid for acquisitions— (209,764)
Proceeds from sale/exchange of assets2,414 — 
Proceeds from sale of investment sharesProceeds from sale of investment shares189,249 — Proceeds from sale of investment shares— 189,249 
Other investing activitiesOther investing activities(14,376)5,125 Other investing activities(2,036)(11,962)
Net cash used in investing activitiesNet cash used in investing activities(507,685)(674,898)Net cash used in investing activities(983,831)(507,685)
Cash flows from financing activities:Cash flows from financing activities:  Cash flows from financing activities:  
Proceeds from credit facility borrowingsProceeds from credit facility borrowings6,237,000 2,686,000 Proceeds from credit facility borrowings— 6,237,000 
Repayment of credit facility borrowingsRepayment of credit facility borrowings(6,137,000)(2,986,000)Repayment of credit facility borrowings— (6,137,000)
Proceeds from issuance of debt— 1,000,000 
Debt issuance costsDebt issuance costs(9,154)(19,713)Debt issuance costs(3,557)(9,154)
Repayment and retirement of debtRepayment and retirement of debt(576,640)(127,691)Repayment and retirement of debt(1,012,877)(576,640)
Premiums paid on debt extinguishment(15,128)(9,599)
Discounts received (premiums paid) on debt extinguishmentDiscounts received (premiums paid) on debt extinguishment6,402 (15,128)
Dividends paidDividends paid(93,272)— Dividends paid(108,318)(93,272)
Cash paid for taxes related to net settlement of share-based incentive awards(13,742)(2,683)
Proceeds from exercises under employee compensation plans13,882 — 
Repurchase and retirement of common stockRepurchase and retirement of common stock(216,491)— Repurchase and retirement of common stock(201,029)(216,491)
(Distribution to) contribution from noncontrolling interest(2,894)3,750 
Distribution to noncontrolling interest, net of contributionsDistribution to noncontrolling interest, net of contributions(2,043)(2,894)
Other financing activitiesOther financing activities(734)— Other financing activities(37,780)(594)
Net cash (used in) provided by financing activities(814,173)544,064 
Net cash used in financing activitiesNet cash used in financing activities(1,359,202)(814,173)
Net change in cash and cash equivalentsNet change in cash and cash equivalents(70,218)312,560 Net change in cash and cash equivalents(243,152)(70,218)
Cash and cash equivalents at beginning of periodCash and cash equivalents at beginning of period113,963 18,210 Cash and cash equivalents at beginning of period1,458,644 113,963 
Cash and cash equivalents at end of periodCash and cash equivalents at end of period$43,745 $330,770 Cash and cash equivalents at end of period$1,215,492 $43,745 

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
See Note 1 for supplemental cash flow information.
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EQT CORPORATION AND SUBSIDIARIES
STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)

Common Stock   Common Stock  
SharesNo Par ValueTreasury StockRetained Earnings
(Accumulated Deficit)
Accumulated Other
Comprehensive Loss (a)
Noncontrolling Interest in
Consolidated Subsidiaries
Total Equity SharesNo Par ValueTreasury Stock(Accumulated Deficit)
Retained Earnings
Accumulated Other
Comprehensive Loss (a)
Noncontrolling Interest in
Consolidated Subsidiaries
Total Equity
(Thousands, except per share amounts)
Balance at April 1, 2021278,781 $8,142,498 $(21,469)$1,019,199 $(5,275)$10,726 $9,145,679 
Comprehensive loss, net of tax:
Net loss  (933,260) (62)(933,322)
Other postretirement benefits liability adjustment, net of tax expense: $2781 81 
Share-based compensation plans77 7,109 1,385   8,494 
Balance at June 30, 2021278,858 $8,149,607 $(20,084)$85,939 $(5,194)$10,664 $8,220,932 
(Thousands, except per share amounts)
Balance at April 1, 2022Balance at April 1, 2022369,074 $9,921,348 $(2,848)$(1,725,279)$(4,548)$17,360 $8,206,033 Balance at April 1, 2022369,074 $9,921,348 $(2,848)$(1,725,279)$(4,548)$17,360 $8,206,033 
Comprehensive income, net of tax:Comprehensive income, net of tax:Comprehensive income, net of tax:
Net incomeNet income  891,361  2,863 894,224 Net income  891,361  2,863 894,224 
Other postretirement benefits liability adjustment, net of tax expense: $21Other postretirement benefits liability adjustment, net of tax expense: $2164 64 Other postretirement benefits liability adjustment, net of tax expense: $2164 64 
Dividends ($0.125 per share)Dividends ($0.125 per share)(46,209)(46,209)Dividends ($0.125 per share)(46,209)(46,209)
Share-based compensation plansShare-based compensation plans645 27,268   27,268 Share-based compensation plans645 27,268   27,268 
Convertible Notes settlements (Note 6)30 30 
Convertible Notes settlementsConvertible Notes settlements30 30 
Distribution to noncontrolling interestDistribution to noncontrolling interest(2,553)(2,553)Distribution to noncontrolling interest(2,553)(2,553)
OtherOther11,233 11,233 Other11,233 11,233 
Balance at June 30, 2022Balance at June 30, 2022369,720 $9,948,646 $(2,848)$(880,127)$(4,484)$28,903 $9,090,090 Balance at June 30, 2022369,720 $9,948,646 $(2,848)$(880,127)$(4,484)$28,903 $9,090,090 
Balance at April 1, 2023Balance at April 1, 2023361,586 $9,776,392 $— $2,338,572 $(2,830)$41,454 $12,153,588 
Comprehensive loss, net of tax:Comprehensive loss, net of tax:
Net lossNet loss  (66,626) (240)(66,866)
Other postretirement benefits liability adjustment, net of tax expense: $14Other postretirement benefits liability adjustment, net of tax expense: $1449 49 
Dividends ($0.15 per share)Dividends ($0.15 per share)(54,248)(54,248)
Share-based compensation plansShare-based compensation plans64 14,451   14,451 
Convertible Notes settlementsConvertible Notes settlements12 12 
Distribution to noncontrolling interestDistribution to noncontrolling interest(1,958)(1,958)
Balance at June 30, 2023Balance at June 30, 2023361,654 $9,790,855 $— $2,217,698 $(2,781)$39,256 $12,045,028 

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

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

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
STATEMENTS OF CONDENSED CONSOLIDATED EQUITY (UNAUDITED)

Common Stock Common Stock
SharesNo Par ValueTreasury StockRetained Earnings
(Accumulated Deficit)
Accumulated Other
Comprehensive Loss (a)
Noncontrolling Interest in
Consolidated Subsidiaries
Total Equity SharesNo Par ValueTreasury Stock(Accumulated Deficit)
Retained Earnings
Accumulated Other
Comprehensive Loss (a)
Noncontrolling Interest in
Consolidated Subsidiaries
Total Equity
(Thousands, except per share amounts)
Balance at January 1, 2021278,345 $8,145,539 $(29,348)$1,056,626 $(5,355)$7,490 $9,174,952 
Comprehensive loss, net of tax:
Net loss(970,687)(576)(971,263)
Other postretirement benefits liability adjustment, net of tax expense: $54161 161 
Share-based compensation plans513 4,068 9,264 13,332 
Contribution from noncontrolling interest3,750 3,750 
Balance at June 30, 2021278,858 $8,149,607 $(20,084)$85,939 $(5,194)$10,664 $8,220,932 
(Thousands, except per share amounts)
Balance at January 1, 2022Balance at January 1, 2022376,399 $10,071,820 $(18,046)$(94,400)$(4,611)$16,236 $9,970,999 Balance at January 1, 2022376,399 $10,071,820 $(18,046)$(94,400)$(4,611)$16,236 $9,970,999 
Comprehensive loss, net of tax:Comprehensive loss, net of tax:Comprehensive loss, net of tax:
Net (loss) incomeNet (loss) income(624,687)4,328 (620,359)Net (loss) income(624,687)4,328 (620,359)
Other postretirement benefits liability adjustment, net of tax expense: $41Other postretirement benefits liability adjustment, net of tax expense: $41127 127 Other postretirement benefits liability adjustment, net of tax expense: $41127 127 
Dividends ($0.25 per share)Dividends ($0.25 per share)(93,272)(93,272)Dividends ($0.25 per share)(93,272)(93,272)
Share-based compensation plansShare-based compensation plans1,852 9,048 15,198 24,246 Share-based compensation plans1,852 9,048 15,198 24,246 
Convertible Notes settlements (Note 6)38 38 
Convertible Notes settlementsConvertible Notes settlements38 38 
Repurchase and retirement of common stockRepurchase and retirement of common stock(8,533)(132,260)(67,768)(200,028)Repurchase and retirement of common stock(8,533)(132,260)(67,768)(200,028)
Distribution to noncontrolling interestDistribution to noncontrolling interest(2,894)(2,894)Distribution to noncontrolling interest(2,894)(2,894)
OtherOther11,233 11,233 Other11,233 11,233 
Balance at June 30, 2022Balance at June 30, 2022369,720 $9,948,646 $(2,848)$(880,127)$(4,484)$28,903 $9,090,090 Balance at June 30, 2022369,720 $9,948,646 $(2,848)$(880,127)$(4,484)$28,903 $9,090,090 
Balance at January 1, 2023Balance at January 1, 2023365,363 $9,891,890 $— $1,283,578 $(2,994)$40,854 $11,213,328 
Comprehensive income, net of tax:Comprehensive income, net of tax:
Net incomeNet income1,151,922 445 1,152,367 
Other postretirement benefits liability adjustment, net of tax expense: $29Other postretirement benefits liability adjustment, net of tax expense: $29213 213 
Dividends ($0.30 per share)Dividends ($0.30 per share)(108,318)(108,318)
Share-based compensation plansShare-based compensation plans2,191 (9,572)(9,572)
Convertible Notes settlementsConvertible Notes settlements82 82 
Repurchase and retirement of common stockRepurchase and retirement of common stock(5,906)(91,545)(109,484)(201,029)
Distribution to noncontrolling interestDistribution to noncontrolling interest(5,793)(5,793)
Contribution from noncontrolling interestContribution from noncontrolling interest3,750 3,750 
Balance at June 30, 2023Balance at June 30, 2023361,654 $9,790,855 $— $2,217,698 $(2,781)$39,256 $12,045,028 

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

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

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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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 30, 20222023 and December 31, 2021,2022, the results of its operations and equity for the three and six month periods ended June 30, 20222023 and 20212022 and its cash flows for the six month periods ended June 30, 20222023 and 2021.2022. Certain previously reported amounts have been reclassified to conform to the current year presentation. In this Quarterly Report on Form 10-Q, references to "EQT," "EQT Corporation""EQT" and "the Company" refer collectively to EQT Corporation and its consolidated subsidiaries.

TheseThe Condensed Consolidated Balance Sheet at December 31, 2022 has been derived from the audited financial statements at that date. For further information, refer to the Consolidated Financial Statements and accompanying notes should be read in conjunction with the audited consolidated financial statements and accompanying notes included in the Company's Annual Report on Form 10-K for the year ended December 31, 2021.2022.

Recently Issued Accounting Standards

In August 2020, the Financial Accounting Standards Board issued Accounting Standards Update (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 Accounting Standards Codification 815 or that do not result in substantial premiums accounted for as paid-in capital, the convertible instrument's embedded conversion features are no longer separated from the host contract. Consequently, and as long as no other feature requires bifurcation and recognition as a derivative, the convertible instrument is accounted for as a single liability measured at its amortized cost. Under ASU 2020-06, entities are required to use the if-converted method to calculate the impact of convertible instruments on diluted earnings per share (EPS). The if-converted method assumes share settlement of the instrument, which increases the number of potentially dilutive securities used to calculate diluted EPS. This ASU also adds several new disclosure requirements.

The Company adopted this ASU effective as of January 1, 2022 using the full retrospective method of adoption. The following tables present the impact of the adoption of ASU 2020-06 on the Company's previously reported historical results. See Note 6 for discussion of the Convertible Notes (defined in Note 6).
Three Months Ended June 30, 2021
As ReportedASU 2020-06 Adoption AdjustmentAs Adjusted
(Thousands, except per share amounts)
Interest expense$76,986 $(4,732)$72,254 
Income tax benefit(347,846)1,535 (346,311)
Net loss(936,519)3,197 (933,322)
Less: Net loss attributable to noncontrolling interest(62)— (62)
Net loss attributable to EQT Corporation$(936,457)$3,197 $(933,260)
Basic and diluted:
Weighted average common stock outstanding (a)279,156 — 279,156 
Loss per share of common stock attributable to EQT Corporation$(3.35)$0.01 $(3.34)

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

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Notes to the Condensed Consolidated Financial Statements (Unaudited)



Six Months Ended June 30, 2021
As ReportedASU 2020-06 Adoption AdjustmentAs Adjusted
(Thousands, except per share amounts)
Interest expense$152,085 $(9,358)$142,727 
Income tax benefit(362,340)3,070 (359,270)
Net loss(977,551)6,288 (971,263)
Less: Net loss attributable to noncontrolling interest(576)— (576)
Net loss attributable to EQT Corporation$(976,975)$6,288 $(970,687)
Basic and diluted:
Weighted average common stock outstanding (a)278,996 — 278,996 
Loss per share of common stock attributable to EQT Corporation$(3.50)$0.02 $(3.48)

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

December 31, 2021
As ReportedASU 2020-06 Adoption AdjustmentAs Adjusted
(Thousands)
Current portion of debt (a)$954,900 $106,070 $1,060,970 
Deferred income taxes938,612 (31,306)907,306 
Common stock, no par value10,167,963 (96,143)10,071,820 
Accumulated deficit(115,779)21,379 (94,400)

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

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

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Notes to the Condensed Consolidated Financial Statements (Unaudited)



Supplemental Cash Flow Information. The following table summarizes net cash paid for interest and income taxes and non-cash activity included in the Statements of Condensed Consolidated Cash Flows.
Six Months Ended June 30,Six Months Ended June 30,
2022202120232022
(Thousands)(Thousands)
Cash paid during the period for:Cash paid during the period for:Cash paid during the period for:
Interest, net of amount capitalizedInterest, net of amount capitalized$133,269 $127,082 Interest, net of amount capitalized$95,316 $133,269 
Income taxes, netIncome taxes, net6,415 21,768 Income taxes, net13,619 6,415 
Non-cash activity during the period for:Non-cash activity during the period for:Non-cash activity during the period for:
Increase in asset retirement costs and obligationsIncrease in asset retirement costs and obligations$10,245 $1,943 Increase in asset retirement costs and obligations$3,631 $10,245 
Capitalization of non-cash equity share-based compensationCapitalization of non-cash equity share-based compensation2,550 2,499 Capitalization of non-cash equity share-based compensation2,997 2,550 
Increase in right-of-use assets and lease liabilities, netIncrease in right-of-use assets and lease liabilities, net819 1,091 Increase in right-of-use assets and lease liabilities, net507 819 
Issuance of common stock for Convertible Notes settlements (see Note 6)38 — 
Issuance of common stock for Convertible Notes settlementIssuance of common stock for Convertible Notes settlement82 38 

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.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)



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 $1,558.1$376.9 million and $1,093.9$1,171.9 million in accounts receivable in the Condensed Consolidated Balance Sheets as of June 30, 20222023 and December 31, 2021,2022, respectively.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)



The table below provides disaggregated information on the Company's revenues. Certain other revenue contracts are outside the scope of ASUAccounting Standards Update (ASU) 2014-09, Revenue from Contracts with Customers. These contracts are reported in net marketing services and other in the Statements of Condensed Consolidated Operations. Derivative contracts are also outside the scope of ASU 2014-09.
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
20222021202220212023202220232022
(Thousands)(Thousands)
Revenues from contracts with customers:Revenues from contracts with customers:Revenues from contracts with customers:
Natural gas salesNatural gas sales$3,175,155 $953,385 $5,464,520 $1,966,465 Natural gas sales$765,856 $3,175,155 $2,478,088 $5,464,520 
NGLs salesNGLs sales167,849 102,361 341,352 202,618 NGLs sales67,899 167,849 166,727 341,352 
Oil salesOil sales22,207 22,158 45,963 39,772 Oil sales14,570 22,207 33,868 45,963 
Total revenues from contracts with customersTotal revenues from contracts with customers$3,365,211 $1,077,904 $5,851,835 $2,208,855 Total revenues from contracts with customers$848,325 $3,365,211 $2,678,683 $5,851,835 
Other sources of revenue:Other sources of revenue:Other sources of revenue:
Loss on derivatives(845,095)(1,345,532)(3,922,732)(1,534,345)
Gain (loss) on derivativesGain (loss) on derivatives164,386 (845,095)989,238 (3,922,732)
Net marketing services and otherNet marketing services and other7,392 7,512 19,295 15,297 Net marketing services and other6,040 7,392 11,901 19,295 
Total operating revenuesTotal operating revenues$2,527,508 $(260,116)$1,948,398 $689,807 Total operating revenues$1,018,751 $2,527,508 $3,679,822 $1,948,398 

The following table summarizes the transaction price allocated to the Company's remaining performance obligations on all contracts with fixed consideration as of June 30, 2022.2023. Amounts shown exclude contracts that qualified for the exception to the relative standalone selling price method as of June 30, 2022.2023.
2022 (a)2023Total
(Thousands)
Natural gas sales$12,148 $10,747 $22,895 
2023 (a)2024Total
(Thousands)
Natural gas sales$6,548 $469 $7,017 

(a)July 1 through December 31.

3.    Derivative Instruments
 
The Company's primary market risk exposure is the volatility of future prices for natural gas and NGLs, which can affect the Company's operating results. The Company uses derivative commodity instruments to hedge its cash flows from sales of produced natural gas and NGLs. The overall objective of the Company's hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices.

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

The Company does not designate any of its derivative instruments as cash flow hedges; therefore, all changes in fair value of the Company's derivative instruments are recognized in operating revenues in lossgain (loss) on derivatives in the Statements of Condensed Consolidated Operations. Because the Company does not designate any of its derivative instruments as cash flow hedges, the Company has changed the references to "derivatives not designated as hedges" to "derivatives" throughout the Condensed Consolidated Financial Statements as of and for the three and six months ended June 30, 2022. 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.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Contracts that result in physical delivery of a commodity expected to be sold by the Company in the normal course of business are generally designated as normal sales and are exempt from derivative accounting. Contracts that result in the physical receipt or delivery of a commodity but are not designated or do not meet all of the criteria to qualify for the normal purchase and normal sale scope exception are subject to derivative accounting.

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

With respect to the derivative commodity instruments held by the Company, the Company hedged portions of its expected sales of production and portions of its basis exposure covering approximately 2,2271,711 billion cubic feet (Bcf) of natural gas and 1,8301,545 thousand barrels (Mbbl) of NGLs as of June 30, 20222023 and 2,1841,424 Bcf of natural gas and 3,0551,483 Mbbl of NGLs as of December 31, 2021.2022. The open positions at both June 30, 20222023 and December 31, 20212022 had maturities extending through December 2027.

Certain of the Company's OTC derivative instrument contracts provide that, if the Company's credit rating assigned by Moody's Investors Service, Inc. (Moody's), S&P Global Ratings (S&P) or Fitch Ratings Service (Fitch) is below the agreed-upon credit rating threshold (typically, below investment grade) and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the counterparty to such contract can require the Company to deposit collateral. Similarly, if such counterparty's credit rating assigned by Moody's, S&P or Fitch is below the agreed-upon credit rating threshold and if the associated derivative liability exceeds the agreed-upon dollar threshold for such credit rating, the Company can require the counterparty to deposit collateral with the Company. Such collateral can be up to 100% of the derivative liability. Investment grade refers to the quality of a company's credit as assessed by one or more credit rating agencies. To be considered investment grade, a company must be rated "Baa3" or higher by Moody's, "BBB–" or higher by S&P and "BBB–" or higher by Fitch. Anything below these ratings is considered non-investment grade. As of June 30, 2022,2023, the Company's senior notes were rated "Ba1" by Moody's, "BBB–" by S&P and "BBB–" by Fitch.

When the net fair value of any of the Company's OTC derivative instrument contracts represents a liability to the Company that is in excess of the agreed-upon dollar threshold for the Company's then-applicable credit rating, the counterparty has the right to require the Company to remit funds as a margin deposit in an amount equal to the portion of the derivative liability that is in excess of the dollar threshold amount. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. As of June 30, 20222023 and December 31, 2021,2022, the aggregate fair value of all OTC derivative instruments with credit rating risk-related contingent features that were in a net liability position was $465.0$30.3 million and $594.9$347.6 million, respectively, for which no deposits were required or recorded in the Company deposited and recorded current assets of $238.0 million and $0.1 million, respectively.Condensed Consolidated Balance Sheets for either period.

When the net fair value of any of the Company's OTC derivative instrument contracts represents an asset to the Company that is in excess of the agreed-upon dollar threshold for the counterparty's then-applicable credit rating, the Company has the right to require the counterparty to remit funds as a margin deposit in an amount equal to the portion of the derivative asset that is in excess of the dollar threshold amount. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. As of both June 30, 20222023 and December 31, 2021,2022, there were no such deposits recorded in the Condensed Consolidated Balance Sheets.

When the Company enters into exchange traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good-faith deposits to guard against the risks associated with changing market conditions. The Company is required to make such deposits based on an established initial margin requirement and the net liability position, if any, of the fair value of the associated contracts. The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets. When the fair value of such contracts is in a net asset position, the broker may remit funds to the Company. The Company records these deposits as a current liability in the Condensed Consolidated Balance Sheets. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the contract. The margin requirements are subject to change at the exchanges' discretion. As of June 30, 20222023 and December 31, 2021,2022, the Company recorded $109.4$27.4 million and $147.7$100.6 million, respectively, of such deposits as current assets in the Condensed Consolidated Balance Sheets.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)
The Company has netting agreements with financial institutions and its brokers that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities. The table below summarizes the impact of netting agreements and margin deposits on gross derivative assets and liabilities.
Gross derivative instruments recorded in the Condensed Consolidated Balance SheetsDerivative instruments subject to
master netting agreements
Margin requirements with counterpartiesNet derivative instrumentsGross derivative instruments recorded in the Condensed Consolidated Balance SheetsDerivative instruments subject to
master netting agreements
Margin requirements with counterpartiesNet derivative instruments
(Thousands) (Thousands)
June 30, 2022
June 30, 2023June 30, 2023
Asset derivative instruments, at fair valueAsset derivative instruments, at fair value$1,409,199 $(1,363,094)$— $46,105 Asset derivative instruments, at fair value$683,612 $(360,541)$— $323,071 
Liability derivative instruments, at fair valueLiability derivative instruments, at fair value4,568,003 (1,363,094)(347,426)2,857,483 Liability derivative instruments, at fair value485,224 (360,541)(27,386)97,297 
December 31, 2021
December 31, 2022December 31, 2022
Asset derivative instruments, at fair valueAsset derivative instruments, at fair value$543,337 $(468,266)$— $75,071 Asset derivative instruments, at fair value$812,371 $(756,495)$— $55,876 
Liability derivative instruments, at fair valueLiability derivative instruments, at fair value2,413,608 (468,266)(147,773)1,797,569 Liability derivative instruments, at fair value1,393,487 (756,495)(100,623)536,369 

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

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

On June 3, 2023, President Biden signed legislation that raises the United States' debt limit, ratifies and approves all permits and authorizations necessary for the construction and initial operation of the Mountain Valley Pipeline and directs the applicable federal officials and agencies to maintain such authorizations. Further, the legislation requires the Secretary of the Army to issue all permits or verifications necessary to complete project construction and allow for the Mountain Valley Pipeline's operation and maintenance. Given the impact of this legislation, the Company reevaluated its probability-weighted assessment of the achievement of an in-service date of the Mountain Valley Pipeline prior to December 31, 2024 and concluded that, as of June 30, 20222023, based on the facts and December 31, 2021,circumstances that existed as of that date, the derivative liability related to the Henry Hub Cash Bonus had a fair value of approximately $53 million and $111 million, respectively. $62.1 million.

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

During the second quarter of 2020, the Company closed a transaction to sell certain non-strategic assets located in Pennsylvania and West Virginia (the 2020 Divestiture), the purchase and sale agreement for which, among other things, provides for additional cash bonus payments (the Contingent Consideration) payable to the Company of up to $20 million, conditioned upon the three-month average of the NYMEX Henry Hub natural gas settlement price relative to stated floor and target price thresholds beginning on August 31, 2020 and ending on November 30, 2022. As of June 30, 2022 and December 31, 2021, the derivative asset related to the Contingent Consideration had a fair value of approximately $3.9 million and $8.2 million, respectively. During the six months ended June 30, 2022 and 2021, the Company received cash from the Contingent Consideration of $4.5 million and $0.6 million, respectively. Changes in fair value are recorded in gain on sale/exchange of long-lived assets in the Statements of Condensed Consolidated Operations. The fair value of the derivative asset related to the Contingent Consideration is based on significant inputs that are interpolated from observable market data and, as such, is a Level 2 fair value measurement. See Note 4 for a description of the fair value hierarchy.

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

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

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

The table below summarizes assets and liabilities measured at fair value on a recurring basis.
Gross derivative instruments recorded in the Condensed Consolidated Balance Sheets Fair value measurements at reporting date using: Fair value measurements at reporting date using:
Quoted prices in active
markets for identical assets
(Level 1)
Significant other observable inputs
(Level 2)
Significant unobservable inputs
(Level 3)
Gross derivative instruments recorded in the Condensed Consolidated Balance SheetsQuoted prices in active
markets for identical assets
(Level 1)
Significant other observable inputs
(Level 2)
Significant unobservable inputs
(Level 3)
(Thousands) (Thousands)
June 30, 2022
June 30, 2023June 30, 2023
Asset derivative instruments, at fair valueAsset derivative instruments, at fair value$1,409,199 $297,009 $1,112,190 $— Asset derivative instruments, at fair value$683,612 $75,675 $607,937 $— 
Liability derivative instruments, at fair valueLiability derivative instruments, at fair value4,568,003 222,871 4,345,132 — Liability derivative instruments, at fair value485,224 79,149 406,075 — 
December 31, 2021
December 31, 2022December 31, 2022
Asset derivative instruments, at fair valueAsset derivative instruments, at fair value$543,337 $66,833 $476,504 $— Asset derivative instruments, at fair value$812,371 $103,028 $709,343 $— 
Liability derivative instruments, at fair valueLiability derivative instruments, at fair value2,413,608 126,053 2,287,555 — Liability derivative instruments, at fair value1,393,487 154,601 1,238,886 — 

The carrying values of cash equivalents, accounts receivable and accounts payable approximate fair value due to their short-term maturities. The December 31, 2021 carrying value of the Company's investment in Equitrans Midstream Corporation (Equitrans Midstream) approximates fair value as Equitrans Midstream is a publicly traded company. In April 2022, the Company sold the remaining balance of its Equitrans Midstream common stock for net proceeds of approximately $189 million. The carrying value ofany borrowings under the Company's credit facility and the Term Loan Facility (defined in Note 6) approximates fair value as thetheir interest rate isrates are based on prevailing market rates. The Company considered all ofconsiders these fair values to be Level 1 fair value measurements.

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

The Company estimates the fair value of its senior notes using established fair value methodology. Because not all of the Company's senior notes are actively traded, their fair value is a Level 2 fair value measurement. As of June 30, 20222023 and December 31, 2021,2022, the Company's senior notes had a fair value of approximately $5.4$5.0 billion and $6.5$6.1 billion, respectively, and a carrying value of approximately $4.8$4.6 billion and $5.5$5.6 billion, respectively, inclusive of any current portion. The fair value of the Company's note payable to EQM Midstream Partners, LP (EQM) is estimated using an income approach model with a market-based discount rate and is a Level 3 fair value measurement. As of June 30, 20222023 and December 31, 2021,2022, the Company's note payable to EQM had a fair value of approximately $102$94 million and $118$96 million, respectively, and a carrying value of approximately $97$91 million and $100$94 million, respectively, inclusive of any current portion. See Note 6 for further discussion of the Company's debt.

The Company recognizes transfers between Levels as of the actual date of the event or change in circumstances that caused the transfer. There were no transfers between Levels 1, 2 and 3 during the periods presented.

See Note 3 for a discussion of the fair value measurement of the derivative liability recorded in connection with the Equitrans Share Exchange and the embedded derivative recorded in connection with the 2020 Divestiture.Henry Hub Cash Bonus. See Note 8 for a discussion of the fair value measurement of the contract asset. See Note 1 to the Consolidated Financial Statements in the Company's Annual Report on Form 10-K for the year ended December 31, 20212022 for a discussion of the fair value measurement of the Company's oil and gas properties and other long-lived assets, including impairment and expiration of leases.

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)

5.    Income Taxes

For the six months ended June 30, 20222023 and 2021,2022, the Company calculated the provision for income taxes for interim periods by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the period. There were no material changes to the Company's methodology for determining unrecognized tax benefits during the six months ended June 30, 2022.2023.

TheFor the six months ended June 30, 2023 and 2022, the Company recorded income tax benefitexpense (benefit) at an effective tax rate of 20.2%23.0% and 27.0%20.2%, respectively. The Company's effective tax rate for the six months ended June 30, 2022 and 2021, respectively.2023 was higher compared to the U.S. federal statutory rate due primarily to state taxes, including valuation allowances limiting certain state tax benefits. The Company's effective tax rate for the six months ended June 30, 2022 was lower compared to the U.S. federal statutory rate due primarily to nondeductible repurchase premiums on the Convertible Notes (defined in Note 6), partly offset by state taxes, including valuation allowances limiting certain state tax benefits. The Company's

On August 16, 2022, President Biden signed into law the Inflation Reduction Act of 2022 (the IRA), which is effective tax rate for the six months ended June 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 after December 31, 2022. The IRA establishes a 15% corporate alternative minimum tax for certain corporations, which is not applicable to the Company for 2023 in accordance with the safe harbor provided in IRS Notice 2023-7. The IRA also includes a 1% excise tax on or after January 1, 2022.stock repurchases made by publicly traded U.S. corporations and includes new and renewed options for energy credits. These changes do not have a significant impact on the Company's financial statements and disclosures.

On July 8, 2022,The Company intends to maintain a valuation allowance on certain of its state net operating loss deferred tax assets (DTAs) until there is sufficient evidence to support a reversal of all or a portion of such allowance. However, given the Pennsylvania General Assembly enacted House Bill 1342,Company's anticipated future earnings, the Company believes that there is a reasonable possibility that, in the near term, sufficient positive evidence may become available that supports the release of a portion of the Company's valuation allowance, which reduceswould result in the corporate netrecognition of certain DTAs and a decrease to income tax rate from 9.99%expense for the period in which the release is recorded. The exact timing and amount of the valuation allowance release would be subject to 8.99% in 2023 and continues to reduce that rate by 0.5% per year beginning in 2024 and ending at 4.99% in 2031 and thereafter. The Company is evaluating the impact this change in law will havebased on the Company's consolidated financial statements.level of profitability that the Company can achieve.

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)
6.    Debt

The table below summarizes the Company's outstanding debt.

June 30, 2022December 31, 2021June 30, 2023December 31, 2022
Principal ValueCarrying Value (a)Principal ValueCarrying Value (a) Principal ValueCarrying Value (a)Principal ValueCarrying Value (a)
(Thousands) (Thousands)
Credit Facility expiring June 28, 2027$100,000 $100,000 $— $— 
Senior notes:Senior notes:Senior notes:
3.00% notes due October 1, 2022— — 568,823 567,909 
7.42% series B notes due 20237.42% series B notes due 202310,000 10,000 10,000 10,000 7.42% series B notes due 2023$— $— $10,000 $10,000 
6.625% notes due February 1, 2025 (b)995,315 990,848 1,000,000 994,643 
6.125% notes due February 1, 2025 (b)6.125% notes due February 1, 2025 (b)601,521 599,865 911,467 908,168 
5.678% notes due October 1, 20255.678% notes due October 1, 2025— — 500,000 496,578 
1.75% convertible notes due May 1, 20261.75% convertible notes due May 1, 2026434,856 425,225 499,991 487,543 1.75% convertible notes due May 1, 2026414,749 407,879 414,832 406,796 
3.125% notes due May 15, 20263.125% notes due May 15, 2026497,694 491,661 500,000 493,157 3.125% notes due May 15, 2026392,915 389,370 440,857 436,198 
7.75% debentures due July 15, 20267.75% debentures due July 15, 2026115,000 112,970 115,000 112,721 7.75% debentures due July 15, 2026115,000 113,467 115,000 113,218 
3.90% notes due October 1, 20273.90% notes due October 1, 20271,250,000 1,243,919 1,250,000 1,243,340 3.90% notes due October 1, 20271,169,503 1,164,866 1,233,008 1,227,582 
5.700% notes due April 1, 20285.700% notes due April 1, 2028500,000 489,363 500,000 493,941 
5.00% notes due January 15, 20295.00% notes due January 15, 2029349,565 344,771 350,000 344,835 5.00% notes due January 15, 2029318,494 314,790 327,101 322,956 
7.500% notes due February 1, 2030 (b)737,650 732,498 750,000 744,417 
7.000% notes due February 1, 2030 (b)7.000% notes due February 1, 2030 (b)674,800 670,709 714,800 710,138 
3.625% notes due May 15, 20313.625% notes due May 15, 2031500,000 493,060 500,000 492,669 3.625% notes due May 15, 2031435,165 429,802 465,165 459,070 
Note payable to EQMNote payable to EQM97,117 97,117 99,838 99,838 Note payable to EQM91,442 91,442 94,320 94,320 
Total debtTotal debt5,087,197 5,042,069 5,643,652 5,591,072 Total debt4,713,589 4,671,553 5,726,550 5,678,965 
Less: Current portion of debt (c)Less: Current portion of debt (c)450,531 440,900 1,074,332 1,060,970 Less: Current portion of debt (c)420,787 413,917 430,668 422,632 
Long-term debtLong-term debt$4,636,666 $4,601,169 $4,569,320 $4,530,102 Long-term debt$4,292,802 $4,257,636 $5,295,882 $5,256,333 
 
(a)For the Company's credit facility and note payable to EQM, the principal value represents the carrying value. For all other debt, the principal value less the unamortized debt issuance costs and debt discounts represents the carrying value.
(b)Interest rates for this tranche of the Company's senior notes fluctuate based on changes to the credit ratings assigned to the Company's senior notes by Moody's, S&P and Fitch. Interest rates on the Company's other outstanding senior notes do not fluctuate based on changes to the credit ratings assigned to its senior notes by Moody's, S&P and Fitch.fluctuate.
(c)As of June 30, 2022,2023, the current portion of debt includesincluded the 7.42% series B notes, the 1.75% convertible notes (described below) and a portion of the note payable to EQM. As of December 31, 2021,2022, the current portion of debt includesincluded the 3.00%7.42% series B notes, the 1.75% convertible notes and a portion of the note payable to EQM.

Debt Repayments. The Company redeemed or repurchased the following debt during the six months ended June 30, 2023.
Debt TranchePrincipalPremiums/(Discounts) (a)Accrued but Unpaid InterestTotal Cost
(Thousands)
6.125% notes due February 1, 2025$309,946 $1,832 $6,801 $318,579 
5.678% notes due October 1, 2025500,000 — 6,940 506,940 
3.125% notes due May 15, 202647,942 (3,042)296 45,196 
3.90% notes due October 1, 202763,505 (3,534)781 60,752 
5.00% notes due January 15, 20298,607 (309)137 8,435 
7.000% notes due February 1, 203040,000 2,736 1,313 44,049 
3.625% notes due May 15, 203130,000 (4,011)167 26,156 
Total$1,000,000 $(6,328)$16,435 $1,010,107 
(a)Includes third-party costs and fees paid to dealer managers and brokers.

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

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)
Debt repayments. The Company redeemed or repurchased the following debt during the six months endedAs of both June 30, 2022.
Debt TranchePrincipal (a)Premiums/(Discounts) (a)Accrued but Unpaid InterestTotal Cost
(Thousands)
3.00% notes due October 1, 2022$568,823 $5,546 $7,150 $581,519 
6.625% notes due February 1, 20254,685 142 130 4,957 
1.75% convertible notes due May 1, 202665,096 101,879 186 167,161 
3.125% notes due May 15, 20262,306 (143)10 2,173 
5.00% notes due January 15, 2029435 (15)10 430 
7.500% notes due February 1, 203012,350 877 387 13,614 

(a)Of the total principal repurchased2023 and premiums recorded during the six months ended June 30, 2022, approximately $80 million and $94 million, respectively, were accrued but not yet paid as of June 30, 2022 due to the timing of settlements.

The Company redeemed or repurchased the following debt during the period beginning July 1, 2022 and ending July 26, 2022.
Debt TranchePrincipalPremiums/(Discounts)Accrued but Unpaid InterestTotal Cost
(Thousands)
6.625% notes due February 1, 2025$79,721 $2,904 $2,491 $85,116 
1.75% convertible notes due May 1, 202620,000 26,027 64 46,091 
3.125% notes due May 15, 202634,340 (1,907)177 32,610 
3.90% notes due October 1, 202715,567 (643)188 15,112 
5.00% notes due January 15, 202913,111 (430)185 12,866 
7.500% notes due February 1, 20307,650 551 253 8,454 
3.625% notes due May 15, 20314,835 (601)28 4,262 

Credit facility. The Company has a $2.5 billion credit facility. On June 28,December 31, 2022, the Company entered into the Third Amended and Restated Credit Agreement (the Third Amendment) with the lenders party thereto and PNC Bank, National Association, as administrative agent, swing line lender and L/C issuer, amending and restating the Second Amended and Restated Credit Agreement, dated as of July 31, 2017 (the Credit Agreement). The Third Amendment, among other things, (i) extends the maturity date of the commitments and loans under the Credit Agreement to June 28, 2027 and provides at the Company's option 2 one-year extensions thereafter, subject to the approval of the lenders, (ii) allows for commitment increases of up to $500 million, subject to the agreement of the Company and new or existing lenders and (iii) allows for Base Rate Loans, Term SOFR Rate Loans and Swing Line Loans (each defined in the Third Amendment).

The Company had approximately $208 million and $440$25 million of letters of credit outstanding under its credit facility as of June 30, 2022 and December 31, 2021, respectively.facility.

UnderDuring the three and six months ended June 30, 2023, there were no borrowings under the Company's credit facility, forfacility. During the three and six months ended June 30, 2022, and 2021,under the Company's credit facility, the maximum amount of outstanding borrowings was $1,300 million and $578 million, respectively,for both periods, the average daily balances werebalance was approximately $844 million and $236$576 million, respectively, and interest was incurred at a weighted average annual interest rate of 2.3% and 2.1%, respectively. Under the Company's credit facility, for the six months ended June 30, 2022 and 2021, the maximum amount of outstanding borrowings was $1,300 million and $890 million, respectively, the average daily balances were approximately $576 million and $188 million, respectively, and interest was incurred at a weighted average annual interest rate of 2.2% and 2.1%, respectively.

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TableTerm Loan Facility. The Company has an unsecured term loan facility (the Term Loan Facility) with aggregate lender commitments thereunder in the principal amount of Contents
EQT CORPORATION AND SUBSIDIARIES
Notes$1.25 billion to partly finance the Condensedpending Tug Hill and XcL Midstream Acquisition (defined and discussed in Note 6 to the Consolidated Financial Statements (Unaudited)
included in the Company's Annual Report on Form 10-K for the year ended December 31, 2022). As of June 30, 2023 and December 31, 2022, all commitments under the Term Loan Facility remained undrawn. On April 25, 2023, the Company extended the commitments under the Term Loan Facility to December 29, 2023. Prior to such extension, any unfunded commitments under the Term Loan Facility were scheduled to expire on June 30, 2023.
3.125% senior notes
5.700% Notes Consent Solicitation and 3.625% senior notes.Indenture Amendment. On May 17, 2021,10, 2023, following the Company issued $500 millionreceipt of the requisite consents of holders of a majority of the aggregate principal amount of 3.125%the Company's 5.700% senior notes, duewhich were obtained through a solicitation of consents that the Company commenced on May 15, 20263, 2023, the Company amended the indenture governing the Company's outstanding 5.700% senior notes to extend the Outside Date (defined below) for the special mandatory redemption provision from June 30, 2023 to December 29, 2023.

In October 2022, the Company issued its 5.700% senior notes to partly finance the pending Tug Hill and $500 million aggregateXcL Midstream Acquisition. Under the indenture governing the Company's 5.700% senior notes, the Company is required to redeem the outstanding 5.700% senior notes at a redemption price equal to 101% of the principal amount of 3.625%the 5.700% senior notes due May 15, 2031. After deducting offering costsplus accrued and unpaid interest, if any, to, but excluding, the date of $15.6 million, net proceeds fromsuch mandatory redemption if (i) the saleTug Hill and XcL Midstream Acquisition is not consummated on or before June 30, 2023 (the Outside Date) or (ii) the Company notifies the trustee of the 5.700% senior notes of $984.4 million were used to partly fundthat it will not pursue the Alta Acquisition (defined in Note 9). The covenantsconsummation of the 3.125%Tug Hill and XcL Midstream Acquisition.

Under the terms set forth in the consent solicitation statement, on May 11, 2023, the Company paid to holders of outstanding 5.700% senior notes and 3.625% senior notes are consistent with the Company's existing senior unsecured notes; however, the 3.125% senior notes and 3.625% senior notes include an offer to repurchase provision applicable upon the occurrencewho delivered valid consents a consent fee of certain change of control events specified$3.6 million in the applicable indentures.aggregate. In addition, pursuant to the terms set forth in the consent solicitation statement, on July 5, 2023, the Company paid to such holders an additional consent fee of $1.8 million in the aggregate.

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

Holders of the Convertible Notes may convert their Convertible Notes at their option at any time prior to the close of business on January 30, 2026 under the following circumstances:
during any quarter as long as the last reported price of EQT Corporation common stock for at least 20 trading days (consecutive or otherwise) during the period of 30 consecutive trading days ending on the last trading day of the immediately preceding quarter is greater than or equal to 130% of the conversion price on each such trading day (the Sale Price Condition);
during the 5-business-dayfive-business-day period after any 5-consecutive-trading-dayfive-consecutive-trading-day period (the measurement period) in which the trading price per $1,000 principal amount of the Convertible Notes for each trading day of the measurement period is less than 98% of the product of the last reported price of EQT Corporation common stock and the conversion rate for the Convertible Notes on each such trading day;
if the Company calls any or all of the Convertible Notes for redemption at any time prior to the close of business on the second scheduled trading day immediately preceding such redemption date; and
upon the occurrence of certain corporate events set forth in the Convertible Notes indenture.

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

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

The initialAs a result of the cash dividends EQT Corporation paid on its common stock during the first half of 2023, the conversion rate for the Convertible Notes was 66.6667 shares ofadjusted as noted in the following table. Future dividend payments by EQT common stock per $1,000 principal amount of the Convertible Notes, which was equivalent to an initial conversion price of $15.00 per share of EQT common stock. The initial conversion price represents a premium of 20%Corporation will result in further adjustments to the $12.50 per share closing price of EQT common stock on April 23, 2020. conversion rate.
Dividend PaidEffective Date of Adjustment to Conversion RateConversion Shares of EQT Corporation Common Stock per $1,000 Principal Amount
Q1 2023February 17, 202368.0740
Q2 2023May 9, 202368.3917

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

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

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)
The Sale Price Condition for conversion of the Convertible Notes was satisfied as of December 31, 2021, March 31, 2022 and June 30, 2022,2023, and, accordingly, the Convertible Notes indenture permits holders of the Convertible Notes are permitted to convert any of their Convertible Notes at their option at any time beginning on January 1,during the third quarter of 2023, subject to the terms and conditions set forth in the Convertible Notes indenture. In addition, the Sales Price Condition for conversion of the Convertible Notes was satisfied as of December 31, 2022, and, continuing until September 30, 2022,accordingly, the Convertible Notes indenture permitted holders of the Convertible Notes to convert any of their Convertible Notes at their option at any time during the first quarter of 2023, subject to the terms and conditions set forth in the Convertible Notes indenture. Therefore, as of June 30, 2023 and December 31, 2021 and June 30, 2022, the net carrying value of the Convertible Notes was included in current portion of debt onin the Condensed Consolidated Balance Sheets.

The following table summarizes settlements of Convertible Notes conversion right exercises from issuance through July 22, 2022.for the six months ended June 30, 2023. The Company elected to settle all such conversions by issuing to the converting holders shares of EQT Corporation common stock.
Settlement MonthPrincipal ConvertedShares IssuedAverage Conversion Price
(Thousands)
September 2021$599 $19.64 
March 2022536 33.65 
April 202226 1,742 34.78 
July 2022335 36.91 
Settlement MonthPrincipal ConvertedShares IssuedAverage Conversion Price
(Thousands)
January 2023$473 $33.70 
February 2023541 30.77 
March 2023408 31.46 
April 202358 3,948 32.01 
June 2023272 39.06 

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

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

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

Based on the closing stock price of EQT Corporation common stock of $34.40$41.13 on June 30, 20222023 and excluding the impact of the Capped Call Transactions, the if-converted value of the Convertible Notes exceeded the principal amount by $572$752 million.

The table below summarizes the net carrying value and fair value of the Convertible Notes.
June 30, 2022December 31, 2021June 30, 2023December 31, 2022
(Thousands)(Thousands)
PrincipalPrincipal$434,856 $499,991 Principal$414,749 $414,832 
Less: Unamortized debt issuance costsLess: Unamortized debt issuance costs9,631 12,448 Less: Unamortized debt issuance costs6,870 8,036 
Net carrying value of Convertible NotesNet carrying value of Convertible Notes$425,225 $487,543 Net carrying value of Convertible Notes$407,879 $406,796 
Fair value of Convertible Notes (a)Fair value of Convertible Notes (a)$1,036,292 $854,985 Fair value of Convertible Notes (a)$939,925 $967,728 

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

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)
The table below summarizes the components of interest expense related to the Convertible Notes. The effective interest rate for the Convertible Notes is 2.4%.
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
20222021202220212023202220232022
(Thousands)(Thousands)
Contractual interest expenseContractual interest expense$2,183 $2,187 $4,370 $4,375 Contractual interest expense$1,815 $2,183 $3,629 $4,370 
Amortization of issuance costsAmortization of issuance costs687 672 1,371 1,341 Amortization of issuance costs583 687 1,164 1,371 
Total Convertible Notes interest expenseTotal Convertible Notes interest expense$2,870 $2,859 $5,741 $5,716 Total Convertible Notes interest expense$2,398 $2,870 $4,793 $5,741 

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)
7.    Earnings(Loss) Income Per Share

The following table shows the computation for basic and diluted (loss) income per share.
Three Months Ended
June 30,
Six Months Ended
June 30,
2023202220232022
(Thousands, except per share amounts)
Net (loss) income attributable to EQT Corporation – Basic (loss) income available to shareholders$(66,626)$891,361 $1,151,922 $(624,687)
Add back: Interest expense on Convertible Notes, net of tax (a)— 2,279 3,691 — 
Diluted (loss) income available to shareholders$(66,626)$893,640 $1,155,613 $(624,687)
Weighted average common stock outstanding – Basic361,982 369,866 361,721 372,023 
Options, restricted stock, performance awards and stock appreciation rights (a)— 4,132 3,455 — 
Convertible Notes (a)— 33,305 28,259 — 
Weighted average common stock outstanding – Diluted361,982 407,303 393,435 372,023 
(Loss) income per share of common stock attributable to EQT Corporation:
Basic$(0.18)$2.41 $3.18 $(1.68)
Diluted$(0.18)$2.19 $2.94 $(1.68)

(a)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 months ended June 30, 2023 and six months ended June 30, 2022, and the three and six months ended June 30, 2021, all such securities of 4.7 million and 6.9 million, respectively, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share. Such securities for the six months ended June 30, 2022 were 6,855,482, and such securities for the three and six months ended June 30, 2021 were 7,679,584 and 7,712,354, respectively. For the three months ended June 30, 2022, such potentially dilutive securities included in the calculation of diluted earnings per share were 4,132,337.

Additionally,In addition, the Company uses the if-converted method to calculate the impact of the Convertible Notes on diluted earnings (loss) income per share. For the three months ended June 30, 2023 and six months ended June 30, 2022, and the three and six months ended June 30, 2021, all such if-converted securities of approximately 28.3 million and 33.4 million, respectively, as well as the respective related add back of interest expense on the Convertible Notes, net of tax, were excluded from potentially dilutive securities because of their anti-dilutive effect on loss per share. Such securities for the six months ended June 30, 2022 were approximately 33.4 million, and such securities for both the three and six months ended June 30, 2021 were approximately 33.3 million. For the three months ended June 30, 2022, such potentially dilutive securities included in the calculation of diluted earnings per share were 33.3 million. See Notes 1 and 6 for further discussion of the Convertible Notes.

8.    Impairment of Contract Asset

During the first quarter of 2020, the Company sold to Equitrans Midstream Corporation (Equitrans Midstream) approximately 50% of the Company's then-owned equity interest in Equitrans Midstream in exchange for a combination of cash and rate relief under certain of the Company's gathering contracts with an affiliate of Equitrans Midstream (the Equitrans Share Exchange). The rate relief was effected through the execution of a consolidated gas gathering and compression agreement entered into between the Company and an affiliate of Equitrans Midstream (the Consolidated GGA). In addition, because the Mountain Valley Pipeline was not in service by January 1, 2022, the Consolidated GGA provides the Company with the option to forgo a portion of the gathering fee relief that would otherwise be applicable following the Mountain Valley Pipeline in-service date in exchange for a cash payment to the Company of approximately $196 million (the Cash Payment Option). On July 8, 2022, the Company delivered notice to Equitrans Midstream that it had elected to exercise the Cash Payment Option.

On the closing date of the Equitrans Share Exchange, the Company recorded in the Condensed Consolidated Balance Sheet a contract asset of $410 million representing the estimated fair value of the rate relief inclusive of the Cash Payment Option.Option (defined below).

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

During 2022, the Company identified indicators that the carrying value of the contract asset may not be fully recoverable, including increased uncertainty of the estimated timing of completion of the Mountain Valley Pipeline due to recent court rulings.rulings and public statements from Equitrans Midstream with respect to its completion. As a result of the Company's impairment evaluation, the Company recognized impairment of the contract asset during the first quarter of 2022 of $184.9 million in the Statement of Condensed Consolidated Operations. TheDuring the fourth quarter of 2022, the Company recognized additional impairment of the contract asset of $29.3 million in the Statement of Condensed Consolidated Operations. As of December 31, 2022, the previously recognized impairments plus the election of the Cash Payment Option reduced the carrying value of the contract asset to its estimated fair value as of March 31, 2022 of $225 million, of which $196 million was attributable to the Cash Payment Option provided by the Consolidated GGA and presented in prepaid expenses and other in the Condensed Consolidated Balance Sheet and $29 million was attributable to the residual rate relief realizable upon the in-service date of the Mountain Valley Pipeline and presented in contract asset in the Condensed Consolidated Balance Sheet. zero.

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

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EQT CORPORATION AND SUBSIDIARIES
Notes to the Condensed Consolidated Financial Statements (Unaudited)
9.    Alta Acquisition

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

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.

The Company completed the purchase price allocation for the Alta Acquisition during the second quarter of 2022, at which time the value of the assets acquired and liabilities assumed were revised. The purchase accounting adjustments recorded in 2022 were not material.

Unaudited Pro Forma Information. The table below summarizes the Company's results as though the Alta Acquisition had been completed on January 1, 2021. Certain of Alta Resources' historical amounts were reclassified to conform to the Company's financial presentation of operations. The following unaudited pro forma information is provided for informational purposes only and does not represent what consolidated results of operations would have been had the Alta Acquisition occurred on January 1, 2021 nor are they necessarily indicative of future consolidated results of operations.
 Three Months Ended
June 30, 2021
Six Months Ended
June 30, 2021
(Thousands, except per share amounts)
Pro forma sales of natural gas, NGLs and oil$1,254,006 $2,598,753 
Pro forma loss on derivatives(1,475,430)(1,650,581)
Pro forma net marketing services and other10,051 20,654 
Pro forma total operating revenues$(211,373)$968,826 
Pro forma net loss$(1,009,899)$(976,368)
Pro forma net loss attributable to noncontrolling interests(62)(576)
Pro forma net loss attributable to EQT Corporation$(1,009,837)$(975,792)
Pro forma loss per share (basic and diluted)$(3.62)$(3.50)

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EQT CORPORATION AND SUBSIDIARIES
Management's Discussion and Analysis of Financial Condition and Results of Operations
Item 2.Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of financial condition and results of operations should be read in conjunction with the Condensed Consolidated Financial Statements and the notes thereto included in this report. Unless the context otherwise indicates, all references in this report to "EQT," the "Company," "we," "us," or "our" are to EQT Corporation and its subsidiaries, collectively.

CAUTIONARY STATEMENTS
 
This Quarterly Report on Form 10-Q contains certain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and Section 27A of the Securities Act of 1933, as amended (the Securities Act). Statements that do not relate strictly to historical or current facts are forward-looking and are usually identified by the use of words such as "anticipate," "estimate," "could," "would," "will," "may," "forecast," "approximate," "expect," "project," "intend," "plan," "believe" and other words of similar meaning, or the negative thereof, in connection with any discussion of future operating or financial matters. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10-Q include the expectations of our plans, strategies, objectives and growth and anticipated financial and operational performance, including guidance regarding our strategy to develop our reserves; drilling plans and programs, including availability of capital to complete these plans and programs; total resource potential and drilling inventory duration; projected production and sales volume and growth rates; natural gas prices; changes in basis and the impact of commodity prices on our business; potential future impairments of our assets; projected well costs and capital expenditures; infrastructure programs; the cost, capacity, and timing of obtaining regulatory approvals; our ability to successfully implement and execute our operational, organizational, technological and environmental, social and governance (ESG) initiatives, and achieve the anticipated results of such initiatives; projected gathering and compression rates; monetizationpotential or pending acquisition transactions, including asset sales, joint ventures or other transactions involvingthe pending Tug Hill and XcL Midstream Acquisition (defined and discussed in Note 6 to the Consolidated Financial Statements included in our assets, and our planned use ofAnnual Report on Form 10-K for the proceeds from such monetization transactions; potential acquisition transactionsyear ended December 31, 2022), or other strategic transactions, the timing thereof and our ability to achieve the intended operational, financial and strategic benefits from any such transactions; the amount and timing of any repayments, redemptions or repurchases of our common stock, outstanding debt securities or other debt instruments; our ability to reduceretire our debt and the timing of such reductions,retirements, if any; the projected amount and timing of dividends; projected cash flows and free cash flow and the timing thereof; liquidity and financing requirements, including funding sources and availability; our ability to maintain or improve our credit ratings, leverage levels and financial profile; our hedging strategy and projected margin posting obligations; the effects of litigation, government regulation and tax position; and the expected impact of changes to tax laws.

The forward-looking statements included in this Quarterly Report on Form 10-Q involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. We have based these forward-looking statements on current expectations and assumptions about future events, taking into account all information currently known by us. While we consider these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks and uncertainties, many of which are difficult to predict and beyond our control. These risks and uncertainties include, but are not limited to, volatility of commodity prices; the costs and results of drilling and operations; uncertainties about estimates of reserves, identification of drilling locations and the ability to add proved reserves in the future; the assumptions underlying production forecasts; the quality of technical data; our ability to appropriately allocate capital and other resources among our strategic opportunities; access to and cost of capital;capital, including as a result of rising interest rates and other economic uncertainties; our hedging and other financial contracts; inherent hazards and risks normally incidental to drilling for, producing, transporting and storing natural gas, natural gas liquids (NGLs) and oil; cyber security risks;risks and acts of sabotage; availability and cost of drilling rigs, completion services, equipment, supplies, personnel, oilfield services and sand and water required to execute our exploration and development plans, including as a result of the COVID-19 pandemic;inflationary pressures; risks associated with operating primarily in the Appalachian Basin and obtaining a substantial amount of our midstream services from Equitrans Midstream Corporation (Equitrans Midstream); the ability to obtain environmental and other permits and the timing thereof; government regulation or action, including regulations pertaining to methane and other greenhouse gas emissions; negative public perception of the fossil fuels industry; increased consumer demand for alternatives to natural gas; environmental and weather risks, including the possible impacts of climate change; and disruptions to our business due to acquisitions and other significant transactions.transactions, including the pending Tug Hill and XcL Midstream Acquisition. These and other risks and uncertainties are described under Item 1A., "Risk Factors" and elsewhere in our Annual Report on Form 10-K for the year ended December 31, 20212022, and set forthmay be updated by Part II, Item 1A., "Risk Factors" in subsequent Quarterly Reports on Form 10-Q and other documents we subsequently file from time to time with the Securities and Exchange Commission.

Any forward-looking statement speaks only as of the date on which such statement is made, and, except as required by law, we do not intend to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by law.otherwise.
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Management's Discussion and Analysis of Financial Condition and Results of Operations
Consolidated Results of Operations
Net incomeloss attributable to EQT Corporation for the three months ended June 30, 2023 was $66.6 million, $0.18 per diluted share, compared to net income attributable to EQT Corporation for the same period in 2022 wasof $891.4 million, $2.19 per diluted share. The change was attributable primarily to decreased sales of natural gas, NGLs and oil, partly offset by a gain on derivatives in 2023 compared to a loss on derivatives in 2022 and income tax benefit in 2023 compared to income tax expense in 2022.
Net income attributable to EQT Corporation for the six months ended June 30, 2023 was $1,151.9 million, $2.94 per diluted share, compared to net loss attributable to EQT Corporation for the same period in 20212022 of $933.3$624.7 million, $3.34$1.68 per diluted share. The change was attributable primarily to increaseda gain on derivatives in 2023 compared to a loss on derivatives in 2022 and impairment of the contract asset in 2022, partly offset by decreased sales of natural gas, NGLs and oil and a smaller loss on derivatives, partly offset by income tax expense increased loss on debt extinguishment and increased transmission and processing, depreciation and depletion and production expenses.

Net loss attributable to EQT Corporation for the six months ended June 30, 2022 was $624.7 million, $1.68 per diluted share,in 2023 compared to net loss attributable to EQT Corporation for the same period in 2021 of $970.7 million, $3.48 per diluted share. The change was attributable primarily to increased sales of natural gas, NGLs and oil, partly offset by a greater loss on derivatives, decreased income tax benefit the impairment of our contract asset (discussed in Note 8 to the Condensed Consolidated Financial Statements), increased transportation and processing expense, increased loss on debt extinguishment and increased depreciation and depletion expense.

Results of operations for 2022 include the results of our operation of assets acquired in the Alta Acquisition (defined and discussed in Note 9 to the Condensed Consolidated Financial Statements), which closed in July 2021.

2022.
See "Sales Volume and Revenues" and "Operating Expenses" for discussions of items affecting operating income and "Other Income Statement Items" for a discussion of other income statement items. See "Investing Activities" under "Capital Resources and Liquidity" for a discussion of capital expenditures.

Trends and Uncertainties
Our sales volume and operating expenses on a per Mcfe basis for 2022 and the first half of 2023 were negatively impacted by fewer wells turned-in-line during 2022 compared to our 2022 planned development schedule due to third-party supply chain constraints. In addition, as a result of third-party supply chain constraints in 2022, we shifted the planned development of approximately 30 wells from 2022 to 2023 (the Rescheduled Wells). All of the Rescheduled Wells have been completed and turned-to-sales as of July 20, 2023; however, future supply chain constraints or declines in natural gas prices may result in adjustments to our 2023 planned development schedule. Our sales volume and operating expenses on a per Mcfe basis for the second quarter of 2023 were also negatively impacted by lower-than-expected liquids volumes from unscheduled downtime at an in-basin ethane cracker plant to conduct equipment repairs and maintenance and a delay in the development schedule of certain wells that are not operated by us but in which we have a working interest in the volumes produced from such wells. We cannot control or otherwise influence the development schedule of non-operated wells in which we have a working interest. Adjustments to our 2023 planned development schedule or delays in the development schedule of non-operated wells in which we have a working interest could impact our future sales volume, operating revenues and expenses, per unit metrics and capital expenditures.
The annual inflation rate in the United States was particularly high during 2022, and, although the inflation rate has decreased through the first half of 2023, it still remains elevated compared to historical levels. Inflationary pressures have multiple impacts on our business, including increasing our operating expenses and our cost of capital. While the prices for certain of the raw materials and services we use in our operations have generally decreased from the peak prices experienced during 2022, we will not fully realize the benefit of such reduced prices until we enter into new contracts for such materials and services, and inflationary pressures may cause prices to fluctuate. Additionally, certain of our commitments for demand charges under our existing long-term contracts and processing capacity are subject to consumer price index adjustments. Although we believe our scale and supply chain contracting strategy of using multi-year sand and frac crew contracts allows us to maximize capital and operating efficiencies, future increases in the inflation rate will negatively impact our long-term contracts with consumer price index adjustments.
Additionally, while the prices for natural gas, NGLs and oil have historically been volatile, price volatility was especially pronounced during 2022, with natural gas prices peaking in August 2022 and steadily declining thereafter. While natural gas prices through the first half of 2023 have declined from the high prices experienced during the majority of 2022, we expect commodity price volatility to continue or increase throughout the remainder of 2023 due to macroeconomic uncertainty and geopolitical tensions, including continued developments pertaining to Russia's invasion of Ukraine, which began in February 2022 and has put upward pressure on natural gas and oil prices. Our revenue, profitability, rate of growth, liquidity and financial position will continue to be impacted in the future by the market prices for natural gas and, to a lesser extent, NGLs and oil.
Average Realized Price Reconciliation
The following table presents detailed natural gas and liquids operational information to assist in the understanding of our consolidated operations, including the calculation of our average realized price ($/Mcfe), which is based on adjusted operating revenues, a non-GAAP supplemental financial measure. Adjusted operating revenues is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Adjusted operating revenues should not be considered as an alternative to total operating revenues. See "Non-GAAP Financial Measures Reconciliation" for a reconciliation of adjusted operating revenues with total operating revenues, the most directly comparable financial measure calculated in accordance with GAAP.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Three Months Ended
June 30,
Six Months Ended
June 30,
2022202120222021
(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)476,723 394,268 942,859 784,566 
NYMEX price ($/MMBtu)$7.16 $2.84 $6.05 $2.76 
Btu uplift0.38 0.16 0.31 0.15 
Natural gas price ($/Mcf)$7.54 $3.00 $6.36 $2.91 
Basis ($/Mcf) (a)$(0.88)$(0.57)$(0.56)$(0.41)
Cash settled basis swaps ($/Mcf)0.01 (0.02)(0.10)(0.05)
Average differential, including cash settled basis swaps ($/Mcf)$(0.87)$(0.59)$(0.66)$(0.46)
Average adjusted price ($/Mcf)$6.67 $2.41 $5.70 $2.45 
Cash settled derivatives ($/Mcf)(3.66)(0.13)(2.71)(0.07)
Average natural gas price, including cash settled derivatives ($/Mcf)$3.01 $2.28 $2.99 $2.38 
Natural gas sales, including cash settled derivatives$1,433,018 $897,429 $2,816,214 $1,869,923 
LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)14,568 16,158 29,202 30,758 
Sales volume (Mbbl)2,428 2,693 4,867 5,126 
NGLs price ($/Bbl)$58.48 $34.83 $61.27 $36.00 
Cash settled derivatives ($/Bbl)(4.67)(9.31)(4.76)(6.31)
Average NGLs price, including cash settled derivatives ($/Bbl)$53.81 $25.52 $56.51 $29.69 
NGLs sales$130,641 $68,737 $275,022 $152,180 
Ethane:
Sales volume (MMcfe) (b)8,768 7,803 18,607 16,390 
Sales volume (Mbbl)1,461 1,301 3,101 2,732 
Ethane price ($/Bbl)$17.70 $6.58 $13.92 $6.62 
Ethane sales$25,865 $8,560 $43,154 $18,094 
Oil:
Sales volume (MMcfe) (b)1,458 2,366 3,124 4,071 
Sales volume (Mbbl)243 394 521 678 
Oil price ($/Bbl)$91.38 $56.18 $88.27 $58.61 
Oil sales$22,206 $22,158 $45,962 $39,772 
Total liquids sales volume (MMcfe) (b)24,794 26,327 50,933 51,219 
Total liquids sales volume (Mbbl)4,132 4,388 8,489 8,536 
Total liquids sales$178,712 $99,455 $364,138 $210,046 
TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)$1,611,730 $996,884 $3,180,352 $2,079,969 
Total sales volume (MMcfe)501,517 420,595 993,792 835,785 
Average realized price ($/Mcfe)$3.21 $2.37 $3.20 $2.49 

Three Months Ended
June 30,
Six Months Ended
June 30,
2023202220232022
(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)449,658 476,723 883,055 942,859 
NYMEX price ($/MMBtu)$2.10 $7.16 $2.76 $6.05 
Btu uplift0.10 0.38 0.14 0.31 
Natural gas price ($/Mcf)$2.20 $7.54 $2.90 $6.36 
Basis ($/Mcf) (a)$(0.50)$(0.88)$(0.10)$(0.56)
Cash settled basis swaps ($/Mcf)(0.20)0.01 (0.18)(0.10)
Average differential, including cash settled basis swaps ($/Mcf)$(0.70)$(0.87)$(0.28)$(0.66)
Average adjusted price ($/Mcf)$1.50 $6.67 $2.62 $5.70 
Cash settled derivatives ($/Mcf)0.53 (3.66)0.42 (2.71)
Average natural gas price, including cash settled derivatives ($/Mcf)$2.03 $3.01 $3.04 $2.99 
Natural gas sales, including cash settled derivatives$912,966 $1,433,018 $2,688,101 $2,816,214 
LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)11,679 14,568 25,176 29,202 
Sales volume (Mbbl)1,946 2,428 4,196 4,867 
NGLs price ($/Bbl)$31.28 $58.48 $35.29 $61.27 
Cash settled derivatives ($/Bbl)(1.21)(4.67)(1.83)(4.76)
Average NGLs price, including cash settled derivatives ($/Bbl)$30.07 $53.81 $33.46 $56.51 
NGLs sales, including cash settled derivatives$58,533 $130,641 $140,389 $275,022 
Ethane:
Sales volume (MMcfe) (b)7,743 8,768 17,670 18,607 
Sales volume (Mbbl)1,291 1,461 2,945 3,101 
Ethane price ($/Bbl)$5.43 $17.70 $6.34 $13.92 
Ethane sales$7,008 $25,865 $18,660 $43,154 
Oil:
Sales volume (MMcfe) (b)1,759 1,458 3,743 3,124 
Sales volume (Mbbl)293 243 624 521 
Oil price ($/Bbl)$49.71 $91.38 $54.30 $88.27 
Oil sales$14,570 $22,206 $33,868 $45,962 
Total liquids sales volume (MMcfe) (b)21,181 24,794 46,589 50,933 
Total liquids sales volume (Mbbl)3,530 4,132 7,765 8,489 
Total liquids sales$80,111 $178,712 $192,917 $364,138 
TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)$993,077 $1,611,730 $2,881,018 $3,180,352 
Total sales volume (MMcfe)470,839 501,517 929,644 993,792 
Average realized price ($/Mcfe)$2.11 $3.21 $3.10 $3.20 

(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 consists of the costs of, and recoveries on, pipeline capacity releases, revenues for gathering services provided to third parties and other revenues. Because we consider net marketing services and other to be unrelated to our natural gas and liquids production activities, adjusted operating revenues excludes net marketing services and other. We believe that adjusted operating revenues provides useful information to investors for evaluating period-to-period comparisons of earnings trends.
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
20222021202220212023202220232022
(Thousands, unless otherwise noted)(Thousands, unless otherwise noted)
Total operating revenuesTotal operating revenues$2,527,508 $(260,116)$1,948,398 $689,807 Total operating revenues$1,018,751 $2,527,508 $3,679,822 $1,948,398 
Add (deduct):
Loss on derivatives845,095 1,345,532 3,922,732 1,534,345 
Net cash settlements paid on derivatives(1,753,732)(71,441)(2,639,271)(109,581)
Premiums received (paid) for derivatives that settled during the period251 (9,579)(32,212)(19,305)
(Deduct) add:(Deduct) add:
(Gain) loss on derivatives(Gain) loss on derivatives(164,386)845,095 (989,238)3,922,732 
Net cash settlements received (paid) on derivativesNet cash settlements received (paid) on derivatives212,247 (1,753,732)369,247 (2,639,271)
Premiums (paid) received for derivatives that settled during the periodPremiums (paid) received for derivatives that settled during the period(67,495)251 (166,912)(32,212)
Net marketing services and otherNet marketing services and other(7,392)(7,512)(19,295)(15,297)Net marketing services and other(6,040)(7,392)(11,901)(19,295)
Adjusted operating revenues, a non-GAAP financial measureAdjusted operating revenues, a non-GAAP financial measure$1,611,730 $996,884 $3,180,352 $2,079,969 Adjusted operating revenues, a non-GAAP financial measure$993,077 $1,611,730 $2,881,018 $3,180,352 
Total sales volume (MMcfe)Total sales volume (MMcfe)501,517 420,595 993,792 835,785 Total sales volume (MMcfe)470,839 501,517 929,644 993,792 
Average realized price ($/Mcfe)Average realized price ($/Mcfe)$3.21 $2.37 $3.20 $2.49 Average realized price ($/Mcfe)$2.11 $3.21 $3.10 $3.20 

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Sales Volume and Revenues

Three Months Ended June 30, 20222023 Compared to Three Months Ended June 30, 20212022
Three Months Ended June 30,Three Months Ended June 30,
20222021Change% Change20232022Change% Change
(Thousands, unless otherwise noted)(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):Sales volume by shale (MMcfe):   Sales volume by shale (MMcfe):   
MarcellusMarcellus465,715 375,116 90,599 24.2 Marcellus449,434 465,715 (16,281)(3.5)
Ohio UticaOhio Utica33,469 44,034 (10,565)(24.0)Ohio Utica19,495 33,469 (13,974)(41.8)
OtherOther2,333 1,445 888 61.5 Other1,910 2,333 (423)(18.1)
Total sales volumeTotal sales volume501,517 420,595 80,922 19.2 Total sales volume470,839 501,517 (30,678)(6.1)
Average daily sales volume (MMcfe/d)Average daily sales volume (MMcfe/d)5,511 4,622 889 19.2 Average daily sales volume (MMcfe/d)5,174 5,511 (337)(6.1)
Operating revenues:Operating revenues:Operating revenues:
Sales of natural gas, NGLs and oilSales of natural gas, NGLs and oil$3,365,211 $1,077,904 $2,287,307 212.2 Sales of natural gas, NGLs and oil$848,325 $3,365,211 $(2,516,886)(74.8)
Loss on derivatives(845,095)(1,345,532)500,437 (37.2)
Gain (loss) on derivativesGain (loss) on derivatives164,386 (845,095)1,009,481 (119.5)
Net marketing services and otherNet marketing services and other7,392 7,512 (120)(1.6)Net marketing services and other6,040 7,392 (1,352)(18.3)
Total operating revenuesTotal operating revenues$2,527,508 $(260,116)$2,787,624 (1,071.7)Total operating revenues$1,018,751 $2,527,508 $(1,508,757)(59.7)

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

Sales volume decreased for the three months ended June 30, 2023 primarily as a result of sales volume decreases from natural decline of producing wells, fewer wells turned-in-line throughout 2022 as a result of third-party supply chain constraints and a delay in the development schedule of certain non-operated wells in which we have a working interest, partly offset by increased volumes from our operated wells as a result efficiencies realized within our drilling and completions operations. The assets that we intend to acquire in the pending Tug Hill and XcL Midstream Acquisition, which is subject to regulatory approvals, are currently producing approximately 800 MMcfe per day of sales volume, 20% of which is liquids sales volume.

Average realized price decreased for the three months ended June 30, 2023 compared to the same period in 2022 due to lower NYMEX and liquids prices, partly offset by favorable cash settled derivatives and favorable differential. For the three months ended June 30, 2023, we received $212.2 million of net cash settlements on derivatives, composed of $304.8 million of net cash settlements received on our NYMEX natural gas hedge positions and $92.6 million of net cash settlements paid on our basis and liquids hedge positions. For the same period in 2022, we paid $1,753.7 million of net cash settlements on derivatives, composed of $1,747.2 million of net cash settlements paid on our NYMEX natural gas hedge positions and $6.5 million of net cash settlements paid on our basis and liquids hedge positions. Net cash settlements received (paid) on derivatives are included in average realized price but may not be included in operating revenues. For the three months ended June 30, 2023 and 2022, we paid $67.5 million and received $0.3 million, respectively, of premiums for derivatives that settled during the period.

Gain (loss) on derivatives. For the three months ended June 30, 2023, we recognized a gain on derivatives of $164.4 million related primarily to increases in the fair market value of our basis swaps, which were in a liability position as of March 31, 2023, partly offset by a loss on the derivative liability related to the Henry Hub Cash Bonus (defined and discussed in Note 4 to the Condensed Consolidated Financial Statements). For the same period in 2022, we recognized a loss on derivatives of $845.1 million related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil increased for the three months ended June 30, 2022 compared to the same period in 2021 due to a higher average realized price and increased sales volume.

Average realized price for the three months ended June 30, 2022 compared to the same period in 2021 increased due to higher NYMEX prices and higher liquids prices, partly offset by unfavorable cash settled derivatives and unfavorable differential. For the three months ended June 30, 2022 and 2021, we paid $1,753.7 million and $71.4 million, respectively, of net cash settlements on derivatives, which are included in average realized price but may not be included in operating revenues.

Sales volume increased primarily as a result of sales volume increases from the assets acquired in the Alta Acquisition.

Loss on derivatives. For the three months ended June 30, 2022 and 2021, we recognized a loss on derivatives of $845.1 million and $1,345.5 million, respectively. The loss on derivatives for 2022 related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX prices. The loss on derivatives for 2021 related primarily to increases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.

Six Months Ended June 30, 20222023 Compared to Six Months Ended June 30, 20212022
Six Months Ended June 30,Six Months Ended June 30,
20222021Change% Change20232022Change% Change
(Thousands, unless otherwise noted)(Thousands, unless otherwise noted)
Sales volume by shale (MMcfe):Sales volume by shale (MMcfe):   Sales volume by shale (MMcfe):   
MarcellusMarcellus921,142 749,057 172,085 23.0 Marcellus883,780 921,142 (37,362)(4.1)
Ohio UticaOhio Utica67,675 83,963 (16,288)(19.4)Ohio Utica42,680 67,675 (24,995)(36.9)
OtherOther4,975 2,765 2,210 79.9 Other3,184 4,975 (1,791)(36.0)
Total sales volumeTotal sales volume993,792 835,785 158,007 18.9 Total sales volume929,644 993,792 (64,148)(6.5)
Average daily sales volume (MMcfe/d)Average daily sales volume (MMcfe/d)5,491 4,618 873 18.9 Average daily sales volume (MMcfe/d)5,136 5,491 (355)(6.5)
Operating revenues:Operating revenues:Operating revenues:
Sales of natural gas, NGLs and oilSales of natural gas, NGLs and oil$5,851,835 $2,208,855 $3,642,980 164.9 Sales of natural gas, NGLs and oil$2,678,683 $5,851,835 $(3,173,152)(54.2)
Loss on derivatives(3,922,732)(1,534,345)(2,388,387)155.7 
Gain (loss) on derivativesGain (loss) on derivatives989,238 (3,922,732)4,911,970 (125.2)
Net marketing services and otherNet marketing services and other19,295 15,297 3,998 26.1 Net marketing services and other11,901 19,295 (7,394)(38.3)
Total operating revenuesTotal operating revenues$1,948,398 $689,807 $1,258,591 182.5 Total operating revenues$3,679,822 $1,948,398 $1,731,424 88.9 

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil increaseddecreased for the six months ended June 30, 20222023 compared to the same period in 20212022 due to a higherdecreased sales volume and lower average realized price and increased sales volume.price.

Average realized priceSales volume decreased for the six months ended June 30, 2023 primarily as a result of sales volume decreases from natural decline of producing wells, fewer wells turned-in-line throughout 2022 as a result of third-party supply chain constraints and a delay in the development schedule of certain non-operated wells in which we have a working interest, partly offset by increased volumes from our operated wells as a result efficiencies realized within our drilling and completions operations. The assets that we intend to acquire in the pending Tug Hill and XcL Midstream Acquisition, which is subject to regulatory approvals, are currently producing approximately 800 MMcfe per day of sales volume, 20% of which is liquids sales volume.

Average realized price decreased for the six months ended June 30, 2023 compared to the same period in 2021 increased2022 due to higherlower NYMEX prices and higher liquids prices, partly offset by unfavorablefavorable cash settled derivatives and unfavorablefavorable differential. For the six months ended June 30, 2023 and 2022, we received $369.2 million, composed of $539.0 million of net cash settlements received on our NYMEX natural gas hedge positions and 2021,$169.8 million of net cash settlements paid on our basis and liquids hedge positions. For the same period in 2022, we paid $2,639.3 million and $109.6 million, respectively, of net cash settlements on derivatives, whichcomposed of $2,522.3 million of net cash settlements paid on our NYMEX natural gas hedge positions and $117.0 million of net cash settlements paid on our basis and liquids hedge positions. Net cash settlements received (paid) on derivatives are included in average realized price but may not be included in operating revenues.

Sales volume increased primarily as a result For the six months ended June 30, 2023 and 2022, we paid premiums for derivatives that settled during the period of sales volume increases from the assets acquired in the Alta Acquisition.$166.9 million and $32.2 million, respectively.

LossGain (loss) on derivatives. For the six months ended June 30, 20222023, we recognized a gain on derivatives of $989.2 million related primarily to increases in the fair market value of our NYMEX swaps and 2021,options due to decreases in NYMEX forward prices, partly offset by a loss on the derivative liability related to the Henry Hub Cash Bonus. For the same period in 2022, we recognized a loss on derivatives of $3,922.7 million and $1,534.3 million, respectively. The loss on derivatives for 2022 related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices. The lossprices, partly offset by a gain on derivatives for 2021the derivative liability related primarily to decreases in the fair market value of our NYMEX swaps and options due to increases in NYMEX forward prices.Henry Hub Cash Bonus.

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EQT CORPORATION AND SUBSIDIARIES
Management's Discussion and Analysis of Financial Condition and Results of Operations
Operating Expenses

Three Months Ended June 30, 20222023 Compared to Three Months Ended June 30, 20212022
Three Months Ended June 30,Three Months Ended June 30,
20222021Change% Change20232022Change% Change
(Thousands, unless otherwise noted)(Thousands, unless otherwise noted)
Operating expenses:Operating expenses:   Operating expenses:   
GatheringGathering$339,100 $286,405 $52,695 18.4 Gathering$318,491 $339,100 $(20,609)(6.1)
TransmissionTransmission149,383 130,235 19,148 14.7 Transmission153,152 149,383 3,769 2.5 
ProcessingProcessing51,221 47,376 3,845 8.1 Processing51,519 51,221 298 0.6 
Lease operating expenses (LOE)Lease operating expenses (LOE)42,814 25,547 17,267 67.6 Lease operating expenses (LOE)35,552 42,814 (7,262)(17.0)
Production taxesProduction taxes39,742 21,999 17,743 80.7 Production taxes19,486 39,742 (20,256)(51.0)
ExplorationExploration1,741 1,779 (38)(2.1)Exploration1,203 1,741 (538)(30.9)
Selling, general and administrativeSelling, general and administrative59,276 49,853 9,423 18.9 Selling, general and administrative60,163 59,276 887 1.5 
Production depletionProduction depletion$423,935 $376,813 $47,122 12.5 Production depletion$390,504 $423,935 $(33,431)(7.9)
Other depreciation and depletionOther depreciation and depletion5,208 3,475 1,733 49.9 Other depreciation and depletion5,180 5,208 (28)(0.5)
Total depreciation and depletionTotal depreciation and depletion$429,143 $380,288 $48,855 12.8 Total depreciation and depletion$395,684 $429,143 $(33,459)(7.8)
Per Unit ($/Mcfe):Per Unit ($/Mcfe):Per Unit ($/Mcfe):
GatheringGathering$0.68 $0.68 $— — Gathering$0.68 $0.68 $— — 
TransmissionTransmission0.30 0.31 (0.01)(3.2)Transmission0.33 0.30 0.03 10.0 
ProcessingProcessing0.10 0.11 (0.01)(9.1)Processing0.11 0.10 0.01 10.0 
LOELOE0.09 0.06 0.03 50.0 LOE0.08 0.09 (0.01)(11.1)
Production taxesProduction taxes0.08 0.05 0.03 60.0 Production taxes0.04 0.08 (0.04)(50.0)
Selling, general and administrativeSelling, general and administrative0.12 0.12 — — Selling, general and administrative0.13 0.12 0.01 8.3 
Production depletionProduction depletion0.85 0.90 (0.05)(5.6)Production depletion0.83 0.85 (0.02)(2.4)

Gathering. Gathering expense increased on an absolute basis for the three months ended June 30, 2022 compared to the same period in 2021 due primarily to increased sales volume from the assets acquired in the Alta Acquisition and higher gathering rates on certain contracts indexed to Appalachian Basin prices. Gathering expense remained flatOperating expenses on a per Mcfe basis for the three months ended June 30, 20222023 compared to the same period in 20212022 were negatively impacted by decreased sales volume.

Gathering. Gathering expense decreased on an absolute basis for the three months ended June 30, 2023 compared to the same period in 2022 due primarily to adecreased sales volume and lower gathering rate structurerates on the assets acquired in the Alta Acquisition, offset primarily by increased gathering rates oncertain contracts indexed to price.

Transmission. Transmission expense increased on an absolute basis for the three months ended June 30, 2022 compared to the same period in 2021 due primarily to additional capacity acquired as part of the Alta Acquisition, higher rates on the Texas Eastern Transmission Pipeline and additional capacity acquired on the Rockies Express Pipeline in the third quarter of 2021. Transmission expense decreased on a per Mcfe basis for the three months ended June 30, 20222023 compared to the same period in 20212022 due primarily to increased sales volumeadditional capacity acquired subsequent to June 2022, partly offset by credits received from the Alta Acquisition, which has a lower average transmission expense per Mcfe when compared to our historical transmission portfolio.Texas Eastern Transmission Pipeline.

Processing.LOE. Processing expense increasedLOE decreased on an absolute basis for the three months ended June 30, 2022 compared to the same period in 2021 due to increased liquid sales volume as a result of increased development of liquids-rich areas. Processing expense decreased on aand per Mcfe basis for the three months ended June 30, 20222023 compared to the same period in 20212022 due primarily to increased sales volume.

LOE. LOE increased on an absolute basis for the three months ended June 30, 2022 compared to the same period in 2021 due primarily to higherlower salt water disposal costs and additional lease operatingincreased recycling. Saltwater disposal costs as a resultand recycle rates were favorably impacted by increased usage of our internally developed produced water gathering and storage system, which was placed in service during the Alta Acquisition. LOE increasedfourth quarter of 2022.

Production taxes. Production taxes decreased on aan absolute and per Mcfe basis for the three months ended June 30, 20222023 compared to the same period in 20212022 due to lower West Virginia severance taxes and Pennsylvania impact fees, which resulted primarily from lower prices.

Depreciation and depletion. Production depletion expense decreased on an absolute and per Mcfe basis for the three months ended June 30, 2023 compared to higher salt water disposal costs.the same period in 2022 due to a lower annual depletion rate and decreased sales volume.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Impairment and expiration of leases. During the three months ended June 30, 2023 and 2022, we recognized impairment and expiration of leases of $5.3 million and $47.0 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

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

Six Months Ended June 30, 2023 Compared to Six Months Ended June 30, 2022
Six Months Ended June 30,
20232022Change% Change
(Thousands, unless otherwise noted)
Operating expenses:   
Gathering$625,755 $659,629 $(33,874)(5.1)
Transmission307,079 296,489 10,590 3.6 
Processing105,312 99,690 5,622 5.6 
LOE64,016 82,643 (18,627)(22.5)
Production taxes38,962 70,925 (31,963)(45.1)
Exploration2,155 2,513 (358)(14.2)
Selling, general and administrative112,057 128,372 (16,315)(12.7)
Production depletion$772,886 $840,860 $(67,974)(8.1)
Other depreciation and depletion10,483 10,381 102 1.0 
Total depreciation and depletion$783,369 $851,241 $(67,872)(8.0)
Per Unit ($/Mcfe):
Gathering$0.67 $0.66 $0.01 1.5 
Transmission0.33 0.30 0.03 10.0 
Processing0.11 0.10 0.01 10.0 
LOE0.07 0.08 (0.01)(12.5)
Production taxes0.04 0.07 (0.03)(42.9)
Selling, general and administrative0.12 0.13 (0.01)(7.7)
Production depletion0.83 0.85 (0.02)(2.4)

Operating expenses on a per Mcfe basis for the six months ended June 30, 2023 compared to the same period in 2022 were negatively impacted by decreased sales volume.

Gathering. Production taxesGathering expense decreased on an absolute basis for the six months ended June 30, 2023 compared to the same period in 2022 due primarily to decreased sales volume and lower gathering rates on certain contracts indexed to price.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the threesix months ended June 30, 20222023 compared to the same period in 20212022 due primarily to additional capacity acquired subsequent to June 2022, partly offset by credits received from the Texas Eastern Transmission Pipeline.

Processing. Processing expense increased on an absolute and per Mcfe basis for the six months ended June 30, 2023 compared to the same period in 2022 due primarily to inflation of contracted processing rates.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
LOE. LOE decreased on an absolute and per Mcfe basis for the six months ended June 30, 2023 compared to the same period in 2022 due primarily to lower salt water disposal costs and increased recycling. Saltwater disposal costs and recycle rates were favorably impacted by increased usage of our internally developed produced water gathering and storage system, which was placed in service during the fourth quarter of 2022.

Production taxes. Production taxes decreased on an absolute and per Mcfe basis for the six months ended June 30, 2023 compared to the same period in 2022 due to increasedlower West Virginia severance taxes which resulted primarily from higher prices, and increased Pennsylvania impact fees, which resulted primarily from the additional wells acquired in the Alta Acquisition, higher prices and inflation.lower prices.

Selling, general and administrative. Selling, general and administrative expense increaseddecreased on an absolute and per Mcfe basis for the threesix months ended June 30, 20222023 compared to the same period in 20212022 due primarily to higherlower long-term incentive compensation costs as a result of changes in the fair value of awards. Long-term incentive compensation may fluctuate with changes in our stock price and performance conditions.

Depreciation and depletion. Production depletion expense increased on an absolute basis for the three months ended June 30, 2022 compared to the same period in 2021 due to increased sales volume, partly offset by a lower annual depletion rate. Production depletion expense decreased on a per Mcfe basis for the three months ended June 30, 2022 compared to the same period in 2021 due to a lower annual depletion rate.

Gain on sale/exchange of long-lived assets. During the three months ended June 30, 2021, we recognized a gain on sale of long-lived assets of $16.8 million related primarily to changes in the fair value of the Contingent Consideration from the 2020 Divestiture (defined and discussed in Note 3 to the Condensed Consolidated Financial Statements).

Impairment and expiration of leases. During the three months ended June 30, 2022 and 2021, we recognized impairment and expiration of leases of $47.0 million and $25.6 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021
Six Months Ended June 30,
20222021Change% Change
(Thousands, unless otherwise noted)
Operating expenses:   
Gathering$659,629 $566,766 $92,863 16.4 
Transmission296,489 255,107 41,382 16.2 
Processing99,690 87,927 11,763 13.4 
LOE82,643 52,566 30,077 57.2 
Production taxes70,925 42,210 28,715 68.0 
Exploration2,513 2,728 (215)(7.9)
Selling, general and administrative128,372 94,859 33,513 35.3 
Production depletion$840,860 $749,821 $91,039 12.1 
Other depreciation and depletion10,381 7,583 2,798 36.9 
Total depreciation and depletion$851,241 $757,404 $93,837 12.4 
Per Unit ($/Mcfe):
Gathering$0.66 $0.68 $(0.02)(2.9)
Transmission0.30 0.31 (0.01)(3.2)
Processing0.10 0.11 (0.01)(9.1)
LOE0.08 0.06 0.02 33.3 
Production taxes0.07 0.05 0.02 40.0 
Selling, general and administrative0.13 0.11 0.02 18.2 
Production depletion0.85 0.90 (0.05)(5.6)

Gathering. Gathering expense increased on an absolute basis for the six months ended June 30, 2022 compared to the same period in 2021 due primarily to increased sales volume from the assets acquired in the Alta Acquisition and higher gathering rates on certain contracts indexed to Appalachian Basin prices. Gathering expense decreased on a per Mcfe basis for the six months ended June 30, 2022 compared to the same period in 2021 due primarily to the lower gathering rate structure on the assets acquired in the Alta Acquisition.

Transmission. Transmission expense increased on an absolute basis for the six months ended June 30, 2022 compared to the same period in 2021 due primarily to additional capacity acquired as part of the Alta Acquisition, higher rates on and lower credits received from the Texas Eastern Transmission Pipeline and additional capacity acquired on the Rockies Express Pipeline in the third quarter of 2021. Transmission expense decreased on a per Mcfe basis for the six months ended June 30, 2022 compared to the same period in 2021 due primarily to increased sales volume from the Alta Acquisition, which has a lower average transmission expense per Mcfe when compared to our historical transmission portfolio.

Processing. Processing expense increased on an absolute basis for the six months ended June 30, 2022 compared to the same period in 2021 due to increased liquid sales volume as a result of increased development of liquids-rich areas. Processing expense decreased on a per Mcfe basis for the six months ended June 30, 2022 compared to the same period in 2021 due primarily to increased sales volume.

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

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Production taxes. Production taxes increased on an absolute and per Mcfe basis for the six months ended June 30, 20222023 compared to the same period in 2021 due to increased West Virginia severance taxes, which resulted primarily from higher prices, and increased Pennsylvania impact fees, which resulted from the additional wells acquired in the Alta Acquisition, higher prices and inflation.

Selling, general and administrative. Selling, general and administrative expense increased on an absolute and per Mcfe basis for thesix months ended June 30, 2022 compared to the same period in 2021 due primarily to higher long-term incentive compensation costs as a result of changes in the fair value of awards and higher litigation expense. Long-term incentive compensation may fluctuate with changes in our stock price and performance conditions.

Depreciation and depletion. Production depletion expense increased on an absolute basis for the six months ended June 30, 2022 compared to the same period in 2021 due to increased sales volume, partly offset by a lower annual depletion rate. Production depletion expense decreased on a per Mcfe basis for the six months ended June 30, 2022 compared to the same period in 2021 due to a lower annual depletion rate.rate and decreased sales volume.

GainLoss (gain) on sale/exchange of long-lived assets. assets. During the six months ended June 30, 2021,2023, we recognized a gainloss on salesale/exchange of long-lived assets of $18.0$16.3 million related primarily to changes inacreage trade agreements where the carrying value of the acres traded exceeded the fair value of the Contingent Consideration from the 2020 Divestiture.acres received.

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

Impairment and expiration of leases. During the six months ended June 30, 20222023 and 2021,2022, we recognized impairment and expiration of leases of $77.0$15.9 million and $42.4$77.0 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses.expenses. Other operating expenses increased for the six months ended June 30, 2023 compared to the same period in 2022 of $23.5 million were attributable primarily to changes in legal and environmental reserves. Other operating expenses for the six months ended June 30, 2021 of $14.7 million were attributabledue primarily to transaction costs associated with our acquisition of upstream assetsthe pending Tug Hill and XcL Midstream Acquisition in 2023, partly offset by decreased legal reserves, including from Chevron U.S.A. Inc. in November 2020 and the Alta Acquisition as well as changes in legal reserves.settlements.

Other Income Statement Items

(Income) loss from investments. For the three months ended June 30, 2023, we recognized income from investments due primarily to equity earnings on our equity method investments. For the three months ended June 30, 2022, we recognized income from investments due primarily to equity earnings on our equity method investments, partly offset by a loss on our sale of our investment in Equitrans Midstream.

For the six months ended June 30, 2023, we recognized income from investments due to a gain on our investment in the Investment Fund (defined in Note 4 to the Condensed Consolidated Financial Statements) and equity earnings on our equity method investments. For the six months ended June 30, 2022, we recognized a loss from investments due primarily to a loss on our sale of our investment in Equitrans Midstream, which resulted from a decrease in Equitrans Midstream's stock price to $8.65 as of April 20, 2022, the date of the final sale of our investment, from $10.34 as of December 31, 2021, partly offset by a gain on our investment in the Investment Fund (defined in Note 4 to the Condensed Consolidated Financial Statements) and equity earnings on our equity method investments. For the three and six months ended June 30, 2021, we recognized income on our investments in Equitrans Midstream and the Investment Fund.

Dividend and other income. Dividend and other income increaseddecreased for the three months ended June 30, 2023 compared to the same period in 2022 due primarily to lower dividends received on our investment in the Investment Fund. Dividend and other income decreased for the six months ended June 30, 20222023 compared to the same periodsperiod in 20212022 due primarily to lower dividends received on our investment in the Investment Fund partly offset by decreasedas well as dividends received on our investment in Equitrans Midstream which was fully disposed of in April 2022.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Loss (gain) on debt extinguishment. During the three months ended June 30, 2023, we recognized a loss on debt extinguishment of $5.5 million due to debt repayment and repurchases at a premium to par value. During the six months ended June 30, 2023, we recognized a gain on debt extinguishment of $1.1 million due to debt repayment and repurchases at a discount to par value during the first quarter of 2023, partly offset by the loss recognized during the three months ended June 30, 2023. During the three and six months ended June 30, 2022, we recognized a loss on debt extinguishment of $104.3 million and $111.3 million, respectively, due primarily to the repayment and repurchases of our Convertible Notes (defined and discussed in Note 6 to the Condensed Consolidated Financial Statements). During the three and six months ended June 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. See Note 6 to the Condensed Consolidated Financial Statements.

Interest expense.expense, net. Interest expense, net decreased for the three and six months ended June 30, 20222023 compared to the same periods in 2021 due primarily to reduced interest expense on letters of credit and our senior notes, partly offset by increased interest expense2022 due primarily to higher borrowings underinterest income earned as well as reduced interest expense due to a reduction of our letters of credit facility. See Note 6 to the Condensed Consolidated Financial Statements.balances.

Income tax expense (benefit). expense. See Note 5 to the Condensed Consolidated Financial Statements.
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Management's Discussion and Analysis of Financial Condition and Results of Operations

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 2022,2023, we expect to spend approximately $1.4$1.7 billion to $1.5$1.9 billion in total capital expenditures, excluding amounts attributable to noncontrolling interest.interest and amounts attributable to the assets expected to be acquired in the pending Tug Hill and XcL Midstream Acquisition. We expect to fund our capital expenditures with cash generated from operations and, if required, borrowings under our credit facility. Because we are the operator of a high percentage of our developed acreage, the amount and timing of thesecertain of our capital expenditures areis largely discretionary. We could choose to defer a portion of theseour planned 20222023 capital expenditures depending on a variety of factors, including prevailing and anticipated prices for natural gas, NGLs and oil; the availability of necessary equipment, infrastructure and capital; the receipt and timing of required regulatory permits and approvals; and drilling, completion and acquisition costs. SalesIn 2023, we expect our sales volume in 2022 isto be 1,900 Bcfe to 2,000 Bcfe, excluding amounts attributable to the assets expected to be 1,950 Bcfe to 2,050 Bcfe.acquired in the pending Tug Hill and XcL Midstream Acquisition.
 
Operating Activities. Net cash provided by operating activities was $1,252$2,100 million for the six months ended June 30, 20222023 compared to $443$1,252 million for the same period in 2021.2022. The increase was due primarily to highernet cash operating revenues, partly offset bysettlements received on derivatives in 2023 compared to net cash settlements paid on derivatives higher cash operating expenses and unfavorablein 2022, favorable changes in working capital due to higher natural gas pricesdriven by declining accounts receivable and lower margin postings as well as unfavorable timing of working capital payments.lower cash operating expenses, partly offset by lower cash operating revenues.

Our cash flows from operating activities are affected by movements in the market price for commodities. We are unable to predict such movements outside of the current market view as reflected in forward strip pricing. 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, 2021.2022.

Investing Activities. Net cash used in investing activities was $508$984 million for the six months ended June 30, 20222023 compared to $675$508 million for the same period in 2021.2022. The decreaseincrease was dueattributable primarily to cash paid for acquisitions in 2021 and proceeds from the sale of our remaining investment in Equitrans Midstream common stock, partly offset by increased capital expenditures.
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EQT CORPORATION AND SUBSIDIARIES
Management's Discussion and Analysis of Financial Condition and Results of Operations

The following table summarizes our capital expenditures.
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
2022202120222021 2023202220232022
(Millions) (Millions)
Reserve developmentReserve development$297 $178 $526 $367 Reserve development$399 $297 $792 $526 
Land and lease (a)Land and lease (a)39 31 88 54 Land and lease (a)24 39 60 88 
Capitalized overheadCapitalized overhead13 14 25 27 Capitalized overhead15 13 29 25 
Capitalized interestCapitalized interest12 Capitalized interest19 12 
Other production infrastructureOther production infrastructure19 19 32 24 Other production infrastructure18 19 32 32 
OtherOther— Other10 
Total capital expendituresTotal capital expenditures376 246 686 484 Total capital expenditures473 376 942 686 
Add (deduct): Non-cash items (b)Add (deduct): Non-cash items (b)17 (27)(1)(14)Add (deduct): Non-cash items (b)14 17 40 (1)
Total cash capital expendituresTotal cash capital expenditures$393 $219 $685 $470 Total cash capital expenditures$487 $393 $982 $685 

(a)Capital expenditures attributable to noncontrolling interest were $2.5$3.1 million and $3.8$2.5 million for the three months ended June 30, 20222023 and 2021,2022, respectively, and $4.4$8.5 million and $5.1$4.4 million for the six months ended June 30, 20222023 and 2021,2022, respectively.
(b)Represents the net impact of non-cash capital expenditures, including the effect of timing of receivables from working interest partners, accrued capital expenditures and capitalized share-based compensation costs. The impact of accrued capital expenditures includes the current period estimate, net of the reversal of the prior period accrual.

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Management's Discussion and Analysis of Financial Condition and Results of Operations
Financing Activities. Net cash used in financing activities was $814$1,359 million for the six months ended June 30, 20222023 compared to net cash provided by financing activities of $544$814 million for the same period in 2021.2022. For the six months ended June 30, 2023, the primary uses of financing cash flows were repayment and retirement of debt, repurchase and retirement of EQT Corporation common stock and payment of dividends. For the six months ended June 30, 2022, the primary uses of financing cash flows were repayment and retirement of debt, repurchase and retirement of EQT Corporation common stock and payment of dividends, and the primary source of financing cash flows was net proceeds from credit facility borrowings. 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 cash flows were net repayments of credit facility borrowings and debt.

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

On July 20, 2022,19, 2023, our Board of Directors declared a quarterly cash dividend of $0.15 per share of EQT Corporation common stock, payable on September 1, 2022,2023, to shareholders of record at the close of business on August 9, 2022.

On July 8, 2022, we delivered notice to Equitrans Midstream that we have elected to exercise the Cash Payment Option (defined and discussed in Note 8 to the Condensed Consolidated Financial Statements).2023.

Depending on our actual and anticipated sources and uses of liquidity, prevailing market conditions and other factors, we may from time to time seek to redeem or repurchase our outstanding debt or equity securities through tender offers or other cash purchases in the open market or privately negotiated transactions. The amounts involved in any such transactions may be material. See Note 6 to the Condensed Consolidated Financial Statements for discussion of redemptions and repurchases of debt.

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EQT CORPORATION AND SUBSIDIARIES
Management's Discussion and Analysis of Financial Condition and Results of Operations
Security Ratings and Financing Triggers
 
The table below reflects the credit ratings and rating outlooks assigned to our debt instruments as of July 22, 2022.21, 2023. Our credit ratings and rating outlooks are subject to revision or withdrawal at any time by the assigning rating agency, and each rating should be evaluated independent from any other rating. We cannot ensure that a rating will remain in effect for any given period of time or that a rating will not be lowered or withdrawn by a rating agency if, in the rating agency's judgment, circumstances so warrant. See Note 3 to the Condensed Consolidated Financial Statements for a description of what is deemed investment grade.
Rating agency Senior notes Outlook
Moody's Investors Service (Moody's)Ba1 Positive
Standard & Poor's Ratings Service (S&P)BBB– Stable
Fitch Ratings Service (Fitch)BBB– Stable
 
Changes in credit ratings may affect our access to the capital markets, the cost of short-term debt through interest rates and fees under our credit facility, the interest rate on our Term Loan Facility (defined in Note 6 to the Condensed Consolidated Financial Statements) and senior notes with adjustable rates, the rates available on new long-term debt, our pool of investors and funding sources, the borrowing costs and margin deposit requirements on our over the counter (OTC) derivative instruments and credit assurance requirements, including collateral, in support of our midstream service contracts, joint venture arrangements or construction contracts. Margin deposits on our OTC derivative instruments are also subject to factors other than credit rating, such as natural gas prices and credit thresholds set forth in the agreements between us and our hedging counterparties.

As of July 22, 2022,21, 2023, 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 22, 2022,21, 2023, such assurances could be up to approximately $0.9$0.6 billion, inclusive of letters of credit, OTC derivative instrument margin deposits and other collateral posted of approximately $0.5$0.2 billion in the aggregate. See Notes 3 and 6 to the Condensed Consolidated Financial Statements for further information.

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 and Term Loan Facility, mandatory partial or full repayment of amounts outstanding, reduced loan capacity or other similar actions. The most significant covenants and events of default under 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 containsand Term Loan Facility contain financial covenants that require us to have a total debt to total capitalization ratio no greater than 65%. As of June 30, 2022,2023, we were in compliance with all debt provisions and covenants under our debt agreements.

See Note 6 to the Condensed Consolidated Financial Statements for a discussion of borrowings under our credit facility. As of June 30, 2023, we had not yet borrowed, and thus, had no borrowings, under the Term Loan Facility.

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

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

Commodity Risk Management

The substantial majority of our commodity risk management program is related to hedging sales of our produced natural gas. The overall objective of our hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices. The derivative commodity instruments that we use are primarily swap, collar and option agreements. The following table summarizes the approximate volume and prices of our NYMEX hedge positions as of July 22, 2022.21, 2023. The difference between the fixed price and NYMEX price is included in average differential presented in our price reconciliation in "Average Realized Price Reconciliation." The fixed price natural gas sales agreements can be physically or financially settled.
Q3 2022 (a)Q4 2022Q1 2023Q2 2023Q3 2023Q4 20232024
Hedged Volume (MMDth)272 284 216 258 261 225 17 
Hedged Volume (MMDth/d)3.0 3.1 2.4 2.8 2.8 2.4 — 
Swaps – Long
Volume (MMDth)125 157 41 41 42 14 — 
Avg. Price ($/Dth)$4.86 $5.59 $6.05 $4.77 $4.77 $4.77 $— 
Swaps – Short
Volume (MMDth)362 332 41 41 42 42 
Avg. Price ($/Dth)$2.93 $2.88 $2.53 $2.53 $2.53 $2.53 $2.67 
Calls – Long
Volume (MMDth)42 36 40 40 40 40 51 
Avg. Strike ($/Dth)$3.79 $2.79 $2.72 $2.72 $2.72 $2.72 $3.20 
Calls – Short
Volume (MMDth)145 195 202 274 277 182 66 
Avg. Strike ($/Dth)$3.33 $5.39 $8.07 $4.48 $4.48 $4.34 $3.11 
Puts – Long
Volume (MMDth)71 119 215 257 260 197 15 
Avg. Strike ($/Dth)$3.11 $4.82 $4.04 $3.06 $3.06 $3.08 $2.45 
Puts – Short
Volume (MMDth)37 11 — — — — — 
Avg. Strike ($/Dth)$3.12 $2.35 $— $— $— $— $— 
Fixed Price Sales
Volume (MMDth)— — 
Avg. Price ($/Dth)$2.38 $3.47 $4.09 $2.38 $2.38 $— $— 
Option Premiums
Cash Settlement of Deferred Premiums (millions)$— $— $(61)$(42)$(42)$(45)$— 

Q3 2023 (a)Q4 2023Q1 2024Q2 2024Q3 2024Q4 2024
Hedged Volume (MMDth)299 313 210 175 177 77 
Hedged Volume (MMDth/d)3.3 3.4 2.3 1.9 1.9 0.8 
Swaps – Long
Volume (MMDth)43 14 — — — — 
Avg. Price ($/Dth)$4.72 $4.77 $— $— $— $— 
Swaps – Short
Volume (MMDth)43 62 98 127 128 44 
Avg. Price ($/Dth)$2.54 $2.79 $3.60 $3.26 $3.26 $3.26 
Calls – Long
Volume (MMDth)40 40 13 13 13 13 
Avg. Strike ($/Dth)$2.72 $2.72 $3.20 $3.20 $3.20 $3.20 
Calls – Short
Volume (MMDth)303 197 125 61 62 46 
Avg. Strike ($/Dth)$4.85 $4.69 $6.21 $4.22 $4.22 $4.27 
Puts – Long
Volume (MMDth)298 265 112 48 49 33 
Avg. Strike ($/Dth)$3.41 $3.53 $4.31 $3.93 $3.93 $4.04 
Fixed Price Sales
Volume (MMDth)— — — — — 
Avg. Price ($/Dth)$2.38 $— $— $— $— $— 
Option Premiums
Cash Settlement of Deferred Premiums (millions)$(70)$(92)$(13)$(4)$(4)$— 
(a)July 1 through September 30.

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EQT CORPORATION AND SUBSIDIARIES
Management's Discussion and Analysis of Financial Condition and Results of Operations
For 2022 (July 1 through December 31), 2023 and 2024, we have natural gas sales agreements for approximately 9 MMDth, 88 MMDth and 11 MMDth, respectively, that include average NYMEX ceiling prices of $3.17, $2.84 and $3.21, respectively.

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.

Commitments and Contingencies

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts claimed may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We evaluate our legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrue legal and other direct costs related to loss contingenciesa liability for such matters 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 a loss is probable and the ultimate outcomeamount of the loss can be reasonably estimated. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event we determine that (i) a loss is probable but the amount of the loss cannot be reasonably estimated, or (ii) a loss is less likely than probable but is reasonably possible, then we are required to disclose the matter in our Annual Report on Form 10-K or this Quarterly Report on Form 10-Q, as applicable, although we are not required to accrue such loss.

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EQT CORPORATION AND SUBSIDIARIES
Management's Discussion and Analysis of Financial Condition and Results of Operations
When able, we determine an estimate of reasonably possible losses or ranges of reasonably possible losses, whether in excess of any pending matter involving us will not materially affectrelated accrued liability or where there is no accrued liability, for legal proceedings. In instances where such estimates can be made, any such estimates are based on our financial condition, resultsanalysis of operations or liquidity.currently available information and are subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained. See Note 1613 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, 20212022 for a discussion of our commitments and contingencies.contingencies, including certain pending legal and regulatory proceedings and other contingent matters. As of June 30, 2023, there have been no material changes to such matters as disclosed therein. See also Part II, "Other Information," Item 1., "Legal Proceedings," for a description of certain other pending environmental matters for which we accrued contingent liabilities.

Recently Issued Accounting Standards

Our recently issued accounting standardsAdditionally, in the normal course of business, we are describedsubject to various other pending and threatened legal proceedings in Note 1 towhich claims for monetary damages or other relief are asserted. We do not anticipate, at the Condensed Consolidated Financial Statements.present time, that the ultimate aggregate liability, if any, arising out of such other legal proceedings will have a material adverse effect on our financial position, results of operations or liquidity.

Critical Accounting Policies and Estimates
 
Our critical accounting policies, including a discussion regarding the estimation uncertainty and the impact that our critical accounting estimates have had, or are reasonably likely to have, on our financial condition or results of operations, are described in 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, 2021.2022. The application of our critical accounting policies may require us to make judgments and estimates about the amounts reflected in the Condensed Consolidated Financial Statements. We use historical experience and all available information to make these estimates and judgments. Different amounts could be reported using different assumptions and estimates.

Item 3.    Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk and Derivative Instruments. Our primary market risk exposure is the volatility of future prices for natural gas and NGLs. Due to the volatility of commodity prices, we are unable to predict future potential movements in the market prices for natural gas and NGLs at our ultimate sales points and, thus, cannot predict the ultimate impact of prices on our operations. Prolonged low, or significant, extended declines in, natural gas and NGLs prices could adversely affect, among other things, our development plans, which would decrease the pace of development and the level of our proved reserves. Increases in natural gas and NGLs prices may be accompanied by, or result in, increased well drilling costs, increased production taxes, increased LOE, increased volatility in seasonal gas price spreads for our storage assets and increased end-user conservation or conversion to alternative fuels. In addition, to the extent we have hedged our production at prices below the current market price, we will not benefit fully from an increase in the price of natural gas, and, depending on our then-current credit ratings and the terms of our hedging contracts, we may be required to post additional margin with our hedging counterparties.

The overall objective of our hedging program is to protect our cash flows from undue exposure to the risk of changing commodity prices. Our use of derivatives is further described in Note 3 to the Condensed Consolidated Financial Statements and "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.

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

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

We monitor price and production levels on a continuous basis and make adjustments to quantities hedged as warranted.
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A hypothetical decrease of 10% in the NYMEX natural gas price on June 30, 20222023 and December 31, 20212022 would increase the fair value of our natural gas derivative commodity instruments by approximately $535$352 million and $577$727 million, respectively. A hypothetical increase of 10% in the NYMEX natural gas price on June 30, 20222023 and December 31, 20212022 would decrease the fair value of our natural gas derivative commodity instruments by approximately $542$273 million and $581$333 million, respectively. For purposes of this analysis, we applied the 10% change in the NYMEX natural gas price on June 30, 20222023 and December 31, 20212022 to our natural gas derivative commodity instruments as of June 30, 20222023 and December 31, 20212022 to calculate the hypothetical change in fair value. The change in fair value was determined using a method similar to our normal process for determining derivative commodity instrument fair value described in Note 4 to the Condensed Consolidated Financial Statements.

The above analysis of our derivative commodity instruments does not include the offsetting impact that the same hypothetical price movement may have on our physical sales of natural gas. The portfolio of derivative commodity instruments held to hedge our forecasted produced natural gas approximates a portion of our expected physical sales of natural gas; therefore, an adverse impact to the fair value of the portfolio of derivative commodity instruments held to hedge our forecasted production associated with the hypothetical changes in commodity prices referenced above should be offset by a favorable impact on our physical sales of natural gas, assuming that the derivative commodity instruments are not closed in advance of their expected term and the derivative commodity instruments continue to function effectively as hedges of the underlying risk.

If the underlying physical transactions or positions are liquidated prior to the maturity of the derivative commodity instruments, a loss on the financial instruments may occur or the derivative commodity instruments might be worthless as determined by the prevailing market value on their termination or maturity date, whichever comes first.

Interest Rate Risk. Changes in market interest rates affect the amount of interest we earn on cash, cash equivalents and short-term investments and the interest rate we pay on borrowings under our credit facility.facility and Term Loan Facility. None of the interest we pay on our senior notes fluctuates based on changes to market interest rates. A 1% increase in interest rates on theThere were no borrowings under our credit facility duringfor the six months ended June 30, 2022 would have increased interest expense by approximately $6 million.2023 under our credit facility or Term Loan Facility.

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, 2021.2022. Changes in interest rates affect the fair value of our fixed rate debt. See Note 6 to the Condensed Consolidated Financial Statements for further discussion of our debt and Note 4 to the Condensed Consolidated Financial Statements for a discussion of fair value measurements, including the fair value measurement of our debt.

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

Approximately 20%60%, or $1,112$608 million, of our OTC derivative contracts outstanding at June 30, 20222023 had a positive fair value. Approximately 17%36%, or $477$710 million, of our OTC derivative contracts outstanding at December 31, 20212022 had a positive fair value.
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As of June 30, 2022,2023, we were not in default under any derivative contracts and had no knowledge of default by any counterparty to our derivative contracts. During the three months ended June 30, 2022,2023, we made no adjustments to the fair value of our derivative contracts due to credit related concerns outside of the normal non-performance risk adjustment included in our established fair value procedure. We monitor market conditions that may impact the fair value of our derivative contracts.

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

No one lender of the large group of financial institutions in the syndicate for our 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

Our management, with the participation of our principal executive officer and our principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act), as of the end of the period covered by this report. Based on that evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred during the second quarter of 20222023 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1.    Legal Proceedings
 
In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts claimed may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We accrue legal and other direct costs related to loss contingencies when actually incurred. We have established reserves in amounts that we believe to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, we believe that the ultimate outcome of any pending matter involving us will not materially affect our financial position, results of operations or liquidity.

There have beenExcept as noted below, there are no material updates to the matters previously disclosed in Part I, Item 3,3., "Legal Proceedings" of our Annual Report on Form 10-K for the year ended December 31, 2021.2022, or in Part II, Item 1., "Legal Proceedings" of our Quarterly Report on Form 10-Q for the period ended March 31, 2023.

Environmental Proceedings

GPU Consent Order Inaccuracies, PADEP. On December 16, 2020, EQT Production Company, a wholly-owned indirect subsidiary of EQT Corporation, entered into a Consent Order and Agreement (the GPU COA) with the Pennsylvania Department of Environmental Protection (the PADEP), pursuant to which EQT Production Company agreed to install secondary containment around Gas Production Units (GPUs) located at wells that were drilled between October 8, 2016 and February 4, 2019. In January 2022, we discovered that the list of GPUs disclosed in the GPU COA was incomplete, and we promptly notified the PADEP of the inaccuracies. On April 26, 2023, we executed a Second Amendment to the GPU COA to update the list of GPUs to correct the inaccuracies, and we agreed to pay $351,000 to the Commonwealth of Pennsylvania related to this matter. We remitted payment in full of the agreed amount to the Commonwealth of Pennsylvania in May 2023, and this matter is now resolved. The payment and the resolution of this matter did not have a material impact on our financial position, results of operations or liquidity.

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Produced Water Release, Washington County, Pennsylvania. In December 2021, we discovered a produced water leak associated with a GPU disposal line at one of our well pad sites located in Washington County, Pennsylvania. We self-reported the release to the PADEP spill hotline on December 4, 2021, and initiated cleanup of the released produced water. The initial release was determined to be in excess of one barrel and we entered the remediation project into the PADEP's Land Recycling and Environmental Remediation Act 2 Program (Act 2) for voluntary cleanup. In January 2022, we determined the release was larger than initially discovered and we disclosed this information to the PADEP on January 14, 2022. We submitted our Site Characterization Report to the PADEP on January 16, 2023, and we intend to initiate remediation of the impacted area according to the PADEP's Act 2 guidelines. We subsequently negotiated a settlement with the PADEP including this matter, as well as the Plugging Consent Order Non-Compliance matter described below. On May 23, 2023, we entered into a Consent Assessment of Civil Penalty with the PADEP, pursuant to which we agreed to pay $4,700,000 to the Commonwealth of Pennsylvania related to this matter. We remitted payment in full of the agreed amount to the Commonwealth of Pennsylvania in May 2023, and this matter is now resolved. The payment and the resolution of this matter did not have a material impact on our financial position, results of operations or liquidity.

Plugging Consent Order Non-Compliance, PADEP. In November 2016, we voluntarily entered into a Consent Order and Agreement with the PADEP to plug a certain number of our abandoned wells on an annual basis, and to remit Well Site Restoration Reports and Well Plugging Certificates to the PADEP in connection with such efforts. In August 2022, the PADEP sent us a notification alleging that, although we had met or exceeded the requirements to plug the requisite abandoned wells within the agreed upon schedule, we had not met all of the administrative requirements for remitting Well Site Restoration Reports and Well Plugging Certificates. We resolved the administrative items in January 2023, and negotiated a settlement with the PADEP including this matter, as well as the Produced Water Release matter described above. On May 23, 2023, we entered into a Consent Order and Agreement with the PADEP, pursuant to which we agreed to pay $4,000,000 related to this matter. We remitted payment of $1,500,000 of the agreed amount to the Commonwealth of Pennsylvania in May 2023. The remaining $2,500,000 of the agreed amount will be paid by us to fund one or more approved community environmental projects at a later date, per the terms of the Consent Order and Agreement. This matter is now resolved. The payments and the resolution of this matter did not have a material impact on our financial position, results of operations or liquidity.

Item 1A. Risk Factors

There have beenare no material changes to the risk factors previously disclosed in Item 1A., "Risk Factors" of our Annual Report on Form 10-K for the year ended December 31, 2021.2022.

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

Conversion of Certain Convertible Notes

In June 2022,. During the second quarter of 2023, we receivedsettled conversion notices fromsubmitted by holders of the Convertible Notes (defined and discussed in Note 6 to the Condensed Consolidated Financial Statements) requesting the conversion of the aggregate principal of certain Convertible Notes (the Converted Notes) by issuing to such converting holders shares of EQT Corporation common stock as stated in the table below (the Converted Notes). We settled the conversion of the Converted Notes by issuing to the converting holders of the Converted Notes shares of EQT common stock.table. Such shares were issued in transactions exempt from registration under the Securities Act by virtue of Section 3(a)(9) thereof, because no commission or other remuneration was paid in connection with conversion of the Converted Notes.
Settlement DatePrincipal ConvertedShares IssuedFair Market Value
(Thousands)(Thousands)
July 1, 2022$201 $
July 5, 2022134 
Settlement DatePrincipal ConvertedShares IssuedFair Market Value
(Thousands)(Thousands)
April 4, 2023$57 3,880 $124 
April 27, 2023168 
June 12, 20232136 
June 15, 2023168 
June 30, 2023168 

Repurchases
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Repurchases of Equity Securities. We did not repurchase any equity securities registered under Section 12 of the Exchange Act during the three months ended June 30, 2022.second quarter of 2023.

On December 13, 2021, we announced that our Board of Directors approved a share repurchase program (the Share Repurchase Program) authorizing us to repurchase shares of our outstanding common stock for an aggregate purchase price of up to $1 billion, excluding fees, commissions and expenses. PursuantOn September 6, 2022, we announced that our Board of Directors approved a $1 billion increase to the shareShare Repurchase Program, pursuant to which approval we are authorized to repurchase authority, weshares of our outstanding common stock for an aggregate purchase price of up to $2 billion, excluding fees, commissions and expenses. Repurchases under the Share Repurchase Program may repurchase sharesbe made from time to time in amounts and at prices we deem appropriate and will be subject to a variety of factors, including the open market or in privately negotiated transactions.price of our common stock, general market and economic conditions, applicable legal requirements and other considerations. The share repurchase authority does not obligate usShare Repurchase Program was originally scheduled to acquire any specific number of shares, was effective immediately and is valid throughexpire on December 31, 2023. We did not repurchase2023; however, on April 26, 2023, we announced that our Board of Directors approved a one-year extension of the Share Repurchase Program. As a result of such extension, the Share Repurchase Program will expire on December 31, 2024, but it may be suspended, modified or discontinued at any shares pursuant to the share repurchase authority during the three months ended June 30, 2022.time without prior notice. As of June 30, 2022,2023, we had purchased shares for an aggregate purchase price of $229.2$622.1 million, excluding fees, commissions and expenses, under this authorizationthe Share Repurchase Program since its inception.inception, and the approximate dollar value of shares that may yet be purchased under the Share Repurchase Program is $1.4 billion.

Item 5. Other Information

During the three months ended June 30, 2023, none of our directors or "officers" (as such term is defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a "Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement" (as each term is defined in Item 408(a) of Regulation S-K).
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Item 6.    Exhibits
Exhibit No.DescriptionMethod of Filing
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.
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.
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.
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.
Sixteenth Supplemental Indenture, dated May 10, 2023, between EQT Corporation and The Bank of New York Mellon, as trustee, relating to EQT Corporation's 5.700% Senior Notes due 2028.Incorporated herein by reference to Exhibit 4.1 to Form 8-K (#001-3551) filed on May 11, 2023.
Second Amendment to the EQT Corporation 2020 Long-Term Incentive Plan.Incorporated by reference to Exhibit 99.2 to Form S-8 (#333-264423) filed on April 21, 2022.
Third Amended and Restated Credit Agreement, dated as of June 28, 2022,April 25, 2023, among EQT Corporation, PNC Bank, National Association, as Administrative Agent, Swing Line Lender and L/C Issuer,administrative agent, and the other lenders party thereto.Incorporated herein by reference to Exhibit 10.1 to Form 8-K (#001-3551) filed on June 28, 2022.April 26, 2023.
Letter Agreement (Tesla(Trust North Well Pad), dated April 29, 2022,June 1, 2023, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC, and EQM Gathering Opco, LLC and Equitrans Water Services (PA), LLC, amending that certain Gas Gathering and Compression Agreement, dated February 26, 2020, as amended and restated.amended.Filed herewith as Exhibit 10.03(a).
10.03(b)*10.02.
Letter Agreement (King Hippo Pad Buyback Gas), dated June 10, 2022, among EQT Corporation, EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC and EQM Gathering Opco, LLC, amending that certain Gas Gathering and Compression Agreement, dated February 26, 2020, as amended and restated.Filed herewith as Exhibit 10.03(b).
Rule 13(a)-14(a) Certification of Principal Executive Officer.Filed herewith as Exhibit 31.01.
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.
101Interactive Data File.Filed herewith as Exhibit 101.
104Cover Page Interactive Data File.Formatted as Inline XBRL and contained in Exhibit 101.

*Certain provisions, schedules andand/or similar attachments to this exhibit have been omitted pursuant to Item 601(a)(5) and/or Item 601(b)(10)(iv), as applicable, of Regulation S-K. EQT Corporation agrees to furnish an unredacted, supplemental copy (including any omitted schedule or attachment) to the SECSecurities 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. KhaniJeremy T. Knop
 David M. KhaniJeremy T. Knop
 Chief Financial Officer
 Date:  July 28, 202226, 2023

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