Antero Resources (AR) 10-Q26 Oct 222022 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2022	Oct. 21, 2022
Document and Entity Information
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	001-36120
Entity Registrant Name	ANTERO RESOURCES CORPORATION
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	80-0162034
Entity Address, Address Line One	1615 Wynkoop Street
Entity Address, City or Town	Denver
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80202
City Area Code	303
Local Phone Number	357-7310
Title of 12(b) Security	Common Stock, par value $0.01
Trading Symbol	AR
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		300,136,446
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Entity Central Index Key	0001433270
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Accounts receivable	$ 23,770	$ 78,998
Accrued revenue	924,343	591,442
Derivative instruments	954	757
Other current assets	28,587	14,922
Total current assets	977,654	686,119
Oil and gas properties, at cost (successful efforts method):
Unproved properties	999,273	1,042,118
Proved properties	13,103,294	12,646,303
Gathering systems and facilities	5,802	5,802
Other property and equipment	129,853	116,522
Property and equipment, gross	14,238,222	13,810,745
Less accumulated depletion, depreciation, and amortization	(4,587,529)	(4,283,700)
Property and equipment, net	9,650,693	9,527,045
Operating leases right-of-use assets	3,541,576	3,419,912
Derivative instruments	7,327	14,369
Investment in unconsolidated affiliate	222,882	232,399
Other assets	13,246	16,684
Total assets	14,413,378	13,896,528
Current liabilities:
Accounts payable	103,640	24,819
Accounts payable, related parties	74,584	76,240
Accrued liabilities	497,547	457,244
Revenue distributions payable	682,327	444,873
Derivative instruments	612,237	559,851
Short-term lease liabilities	535,347	456,347
Deferred revenue, VPP	32,330	37,603
Other current liabilities	6,010	11,140
Total current liabilities	2,544,022	2,068,117
Long-term liabilities:
Long-term debt	1,172,828	2,125,444
Deferred income tax liability, net	619,342	318,126
Derivative instruments	445,481	181,806
Long-term lease liabilities	3,007,636	2,964,115
Deferred revenue, VPP	95,514	118,366
Other liabilities	58,293	54,462
Total liabilities	7,943,116	7,830,436
Commitments and contingencies
Equity:
Preferred stock, $0.01 par value; authorized - 50,000 shares; none issued
Common stock, $0.01 par value; authorized - 1,000,000 shares; 313,930 shares and 303,131 shares issued and outstanding as of December 31, 2021 and September 30, 2022, respectively	3,031	3,139
Additional paid-in capital	5,941,977	6,371,398
Retained earnings (accumulated deficit)	266,468	(617,377)
Total stockholders' equity	6,211,476	5,757,160
Noncontrolling interests	258,786	308,932
Total equity	6,470,262	6,066,092
Total liabilities and equity	$ 14,413,378	$ 13,896,528

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2022	Dec. 31, 2021
Condensed Consolidated Balance Sheets
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, authorized shares	50,000,000	50,000,000
Preferred stock, shares issued	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, authorized shares	1,000,000,000	1,000,000,000
Common stock, shares issued	303,131,000	313,930,000
Common stock, shares outstanding	303,131,000	313,930,000

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations and Comprehensive Loss - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenue and other:
Revenue	$ 2,583,865	$ 1,772,415	$ 6,829,011	$ 4,450,839
Commodity derivative fair value losses	(530,523)	(1,250,466)	(1,807,565)	(2,260,062)
Amortization of deferred revenue, VPP	9,478	11,404	28,125	33,833
Other income	1,804	530	3,578	551
Total revenue	2,064,624	533,883	5,053,149	2,225,161
Operating expenses:
Lease operating	27,453	25,363	70,486	71,555
Production and ad valorem taxes	92,998	52,219	227,648	130,610
General and administrative	42,903	32,442	123,033	108,693
Depletion, depreciation, and amortization	169,607	182,810	511,390	564,166
Impairment of oil and gas properties	33,924	26,253	79,749	69,618
Accretion of asset retirement obligations	630	828	3,878	2,947
Contract termination	17,995	3,370	20,099	4,305
(Gain) loss on sale of assets	214	(539)	2,071	(2,827)
Total operating expenses	1,290,464	1,217,957	3,422,070	3,457,645
Operating income (loss)	774,160	(684,074)	1,631,079	(1,232,484)
Other income (expense):
Interest expense, net	(28,326)	(45,414)	(100,252)	(138,120)
Equity in earnings of unconsolidated affiliates	14,972	21,450	54,863	57,621
Loss on early extinguishment of debt	(30,307)	(16,567)	(45,375)	(82,836)
Loss on convertible note inducement and equitizations	(169)		(169)	(50,777)
Transaction expense		(626)		(3,102)
Total other expense	(43,830)	(41,157)	(90,933)	(217,214)
Income (loss) before income taxes	730,330	(725,231)	1,540,146	(1,449,698)
Income tax benefit (expense)	(135,823)	158,656	(308,302)	337,568
Net income (loss) and comprehensive income (loss) including noncontrolling interests	594,507	(566,575)	1,231,844	(1,112,130)
Less: net income (loss) and comprehensive income (loss) attributable to noncontrolling interests	34,748	(17,257)	63,369	(23,846)
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	$ 559,759	$ (549,318)	$ 1,168,475	$ (1,088,284)
Income (loss) per share-basic (in dollars per share)	$ 1.83	$ (1.75)	$ 3.77	$ (3.55)
Income (loss) per share-diluted (in dollars per share)	$ 1.72	$ (1.75)	$ 3.51	$ (3.55)
Weighted average number of shares outstanding:
Basic (in shares)	305,343	313,790	309,954	306,201
Diluted (in shares)	325,997	313,790	333,738	306,201
Natural gas sales
Revenue and other:
Revenue	$ 1,736,039	$ 884,669	$ 4,290,825	$ 2,231,558
Natural gas liquids sales
Revenue and other:
Revenue	620,816	598,327	1,983,509	1,503,027
Oil sales
Revenue and other:
Revenue	67,025	56,734	219,504	153,326
Gathering, compression, water handling and treatment, processing, and transportation
Operating expenses:
Cost of goods and services sold	716,388	628,225	1,962,878	1,874,664
Marketing.
Revenue and other:
Revenue	159,985	232,685	335,173	562,928
Operating expenses:
Cost of goods and services sold	185,377	266,751	415,571	627,822
Exploration and mine expenses
Operating expenses:
Cost of goods and services sold	$ 2,975	$ 235	$ 5,267	$ 6,092

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Operations and Comprehensive Loss (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Condensed Consolidated Statements of Operations and Comprehensive Loss
Equity-based compensation expense	$ 10,402	$ 5,298	$ 23,222	$ 15,189

Condensed Consolidated Statem_3

Condensed Consolidated Statement of Equity - USD ($) shares in Thousands, $ in Thousands	Common Stock	Additional paid-in capital	Accumulated earnings (deficit)	Noncontrolling Interests	Total
Balances at Dec. 31, 2020	$ 2,686	$ 6,195,497	$ (430,478)	$ 322,566	$ 6,090,271
Balances (in shares) at Dec. 31, 2020	268,672
Increase (Decrease) in Stockholders' Equity
Issuance of common shares	$ 314	238,551			238,865
Issuance of common shares (in shares)	31,388
Issuance of common units in Martica Holdings, LLC				51,000	51,000
Equity component of 2026 Convertible Notes, net		(116,381)			(116,381)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes	$ 11	(5,656)			(5,645)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	1,130
Equity-based compensation		5,642			5,642
Distributions to non-controlling interest				(24,699)	(24,699)
Net income (loss) and comprehensive income (loss)			(15,499)	4,395	(11,104)
Balance at Mar. 31, 2021	$ 3,011	6,317,653	(445,977)	353,262	6,227,949
Balance (in shares) at Mar. 31, 2021	301,190
Balances at Dec. 31, 2020	$ 2,686	6,195,497	(430,478)	322,566	6,090,271
Balances (in shares) at Dec. 31, 2020	268,672
Increase (Decrease) in Stockholders' Equity
Net income (loss) and comprehensive income (loss)					(1,112,130)
Balance at Sep. 30, 2021	$ 3,138	6,365,929	(1,518,762)	284,937	5,135,242
Balance (in shares) at Sep. 30, 2021	313,866
Balances at Mar. 31, 2021	$ 3,011	6,317,653	(445,977)	353,262	6,227,949
Balances (in shares) at Mar. 31, 2021	301,190
Increase (Decrease) in Stockholders' Equity
Issuance of common shares	$ 116	125,262			125,378
Issuance of common shares (in shares)	11,588
Equity component of 2026 Convertible Notes, net		(79,497)			(79,497)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes	$ 8	(3,893)			(3,885)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	749
Equity-based compensation		4,249			4,249
Distributions to non-controlling interest				(21,329)	(21,329)
Net income (loss) and comprehensive income (loss)			(523,467)	(10,984)	(534,451)
Balance at Jun. 30, 2021	$ 3,135	6,363,774	(969,444)	320,949	5,718,414
Balance (in shares) at Jun. 30, 2021	313,527
Increase (Decrease) in Stockholders' Equity
Equity component of 2026 Convertible Notes, net		36			36
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes	$ 3	(3,179)			(3,176)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	339
Equity-based compensation		5,298			5,298
Distributions to non-controlling interest				(18,755)	(18,755)
Net income (loss) and comprehensive income (loss)			(549,318)	(17,257)	(566,575)
Balance at Sep. 30, 2021	$ 3,138	6,365,929	(1,518,762)	284,937	5,135,242
Balance (in shares) at Sep. 30, 2021	313,866
Balances at Dec. 31, 2021	$ 3,139	6,371,398	(617,377)	308,932	6,066,092
Balances (in shares) at Dec. 31, 2021	313,930
Increase (Decrease) in Stockholders' Equity
Equity component of 2026 Convertible Notes, net		(24,411)	3,229		(21,182)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes	$ 8	(10,385)			(10,377)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	780
Repurchases and retirements of common stock	$ (37)	(74,745)	(25,263)		(100,045)
Repurchases and retirements of common stock (in shares)	(3,690)
Equity-based compensation		4,649			4,649
Distributions to non-controlling interest				(35,757)	(35,757)
Net income (loss) and comprehensive income (loss)			(156,419)	(18,277)	(174,696)
Balance at Mar. 31, 2022	$ 3,110	6,266,506	(795,830)	254,898	5,728,684
Balance (in shares) at Mar. 31, 2022	311,020
Balances at Dec. 31, 2021	$ 3,139	6,371,398	(617,377)	308,932	6,066,092
Balances (in shares) at Dec. 31, 2021	313,930
Increase (Decrease) in Stockholders' Equity
Net income (loss) and comprehensive income (loss)					1,231,844
Balance at Sep. 30, 2022	$ 3,031	5,941,977	266,468	258,786	6,470,262
Balance (in shares) at Sep. 30, 2022	303,131
Balances at Mar. 31, 2022	$ 3,110	6,266,506	(795,830)	254,898	5,728,684
Balances (in shares) at Mar. 31, 2022	311,020
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes	$ 21	(54,463)			(54,442)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	2,112
Conversion of 2026 Convertible Notes	$ 9	3,955			3,964
Conversion of 2026 Convertible Notes (in shares)	921
Repurchases and retirements of common stock	$ (52)	(104,524)	(88,430)		(193,006)
Repurchases and retirements of common stock (in shares)	(5,241)
Equity-based compensation		8,171			8,171
Distributions to non-controlling interest				(31,541)	(31,541)
Net income (loss) and comprehensive income (loss)			765,135	46,898	812,033
Balance at Jun. 30, 2022	$ 3,088	6,119,645	(119,125)	270,255	6,273,863
Balance (in shares) at Jun. 30, 2022	308,812
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes		(210)			(210)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	25
Conversion of 2026 Convertible Notes	$ 48	20,230			20,278
Conversion of 2026 Convertible Notes (in shares)	4,751
Repurchases and retirements of common stock	$ (105)	(208,090)	(174,166)		(382,361)
Repurchases and retirements of common stock (in shares)	(10,457)
Equity-based compensation		10,402			10,402
Distributions to non-controlling interest				(46,217)	(46,217)
Net income (loss) and comprehensive income (loss)			559,759	34,748	594,507
Balance at Sep. 30, 2022	$ 3,031	$ 5,941,977	$ 266,468	$ 258,786	$ 6,470,262
Balance (in shares) at Sep. 30, 2022	303,131

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests	$ 1,231,844	$ (1,112,130)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion, depreciation, amortization and accretion	515,268	567,113
Impairments	79,749	69,618
Commodity derivative fair value losses	(1,807,565)	(2,260,062)
Losses on settled commodity derivatives	(1,484,660)	(481,083)
Payments for derivative monetizations		(4,569)
Deferred income tax expense (benefit)	307,326	(337,568)
Equity-based compensation expense	23,222	15,189
Equity in earnings of unconsolidated affiliate	(54,863)	(57,621)
Dividends of earnings from unconsolidated affiliate	93,854	105,325
Amortization of deferred revenue	(28,125)	(33,833)
Amortization of debt issuance costs, debt discount and debt premium	3,458	10,122
Settlement of asset retirement obligations	(946)
(Gain) loss on sale of assets	2,071	(2,827)
Loss on early extinguishment of debt	45,375	82,836
Loss on convertible note equitizations	169	50,777
Changes in current assets and liabilities:
Accounts receivable	55,229	(11,336)
Accrued revenue	(332,900)	(227,207)
Other current assets	(13,664)	(5,695)
Accounts payable including related parties	59,222	39,108
Accrued liabilities	36,632	124,382
Revenue distributions payable	237,453	117,819
Other current liabilities	(7,222)	16,470
Net cash provided by operating activities	2,576,057	1,184,952
Cash flows provided by (used in) investing activities:
Additions to unproved properties	(120,139)	(48,960)
Drilling and completion costs	(589,093)	(447,899)
Additions to other property and equipment	(12,188)	(14,082)
Proceeds from asset sales	1,147	3,192
Change in other assets	1,910	2,371
Change in other liabilities		(77)
Net cash used in investing activities	(718,363)	(505,455)
Cash flows provided by (used in) financing activities:
Repurchases of common stock	(675,412)
Issuance of senior notes		1,800,000
Repayment of senior notes	(1,011,313)	(1,424,354)
Borrowings (repayments) on bank credit facilities, net	9,000	(919,500)
Payment of debt issuance costs	(814)	(22,814)
Sale of noncontrolling interest		51,000
Distributions to noncontrolling interests in Martica Holdings LLC	(113,515)	(64,783)
Employee tax withholding for settlement of equity compensation awards	(65,029)	(12,706)
Convertible note inducement and equitizations	(169)	(85,648)
Other	(442)	(692)
Net cash used in financing activities	(1,857,694)	(679,497)
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents, beginning of period	0	0
Cash and cash equivalents, end of period	0	0
Supplemental disclosure of cash flow information:
Cash paid during the period for interest	148,668	130,947
Increase in accounts payable and accrued liabilities for additions to property and equipment	$ 23,633	$ 33,547

Organization

Organization	9 Months Ended
Organization	Sep. 30, 2022
Organization
Organization	(1) Organization Antero Resources Corporation (individually referred to as “Antero” and together with its consolidated subsidiaries “Antero Resources,” or the “Company”) is engaged in the development, production, exploration and acquisition of natural gas, NGLs and oil properties in the Appalachian Basin in West Virginia and Ohio. The Company targets large, repeatable resource plays where horizontal drilling and advanced fracture stimulation technologies provide the means to economically develop and produce natural gas, NGLs and oil from unconventional formations. The Company’s corporate headquarters is located in Denver, Colorado.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
Summary of Significant Accounting Policies	Sep. 30, 2022
Summary of Significant Accounting Policies
Summary of Significant Accounting Policies	(2) Summary of Significant Accounting Policies (a) Basis of Presentation These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information and should be read in the context of the Company’s December 31, 2021 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position and accounting policies. The Company’s December 31, 2021 consolidated financial statements were included in Antero Resources’ 2021 Annual Report on Form 10-K, which was filed with the SEC. These unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, and, accordingly, do not include all of the information and footnotes required by GAAP for complete consolidated financial statements. In the opinion of management, these unaudited condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Company’s financial position as of December 31, 2021 and September 30, 2022, results of operations for the three and nine months ended September 30, 2021 and 2022 and cash flows for the nine months ended September 30, 2021 and 2022. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss. Operating results for the period ended September 30, 2022 are not necessarily indicative of the results that may be expected for the full year because of the impact of fluctuations in prices received for natural gas, NGLs and oil, natural production declines, the uncertainty of exploration and development drilling results, fluctuations in the fair value of derivative instruments, the impacts of COVID-19 and other factors. (b) Principles of Consolidation The accompanying unaudited condensed consolidated financial statements include the accounts of Antero Resources Corporation, its wholly owned subsidiaries and its variable interest entity (“VIE”), Martica Holdings LLC, (“Martica”), for which the Company is the primary beneficiary. All significant intercompany accounts and transactions have been eliminated in the Company’s unaudited condensed consolidated financial statements. (c) Cash and Cash Equivalents The Company considers all liquid investments purchased with an initial maturity of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments. From time to time, the Company may be in the position of a “book overdraft” in which outstanding checks exceed cash and cash equivalents. The Company classifies book overdrafts in accounts payable and revenue distributions payable within its condensed consolidated balance sheets, and classifies the change in accounts payable associated with book overdrafts as an operating activity within its unaudited condensed consolidated statements of cash flows. As of December 31, 2021, the book overdrafts included within accounts payable and revenue distributions payable were million, respectively. As of September 30, 2022, the book overdrafts included within accounts payable and revenue distributions payable were (d) Earnings (Loss) Per Common Share Earnings (loss) per common share—basic for each period is computed by dividing net income (loss) attributable to Antero by the basic weighted average number of shares outstanding during the period. Earnings (loss) per common share—diluted for each period is computed after giving consideration to the potential dilution from (i) outstanding equity awards using the treasury stock method and (ii) shares of common stock issuable upon conversion of the 2026 Convertible Notes (as defined below in Note 7—Long-Term Debt) using the if-converted method. The Company includes restricted stock unit (“RSU”) awards, performance share unit (“PSU”) awards and stock options in the calculation of diluted weighted average shares outstanding based on the number of common shares that would be issuable if the end of the period was also the end of the performance period required for the vesting of the awards. During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effects of all equity awards and the 2026 Convertible Notes are anti-dilutive. The following is a reconciliation of the Company’s earnings (loss) attributable to common stockholders for basic and diluted earnings (loss) per share (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Net income (loss) attributable to Antero Resources Corporation—common shareholders $ (549,318) 559,759 (1,088,284) 1,168,475 Add: Interest expense for 2026 Convertible Notes — 830 — 2,764 Less: Tax-effect of interest expense for 2026 Convertible Notes — (193) — (642) Net income (loss) attributable to Antero Resources Corporation—common shareholders and assumed conversions $ (549,318) 560,396 (1,088,284) 1,170,597 Income (loss) per share—basic $ (1.75) 1.83 (3.55) 3.77 Income (loss) per share—diluted $ (1.75) 1.72 (3.55) 3.51 Weighted average common shares outstanding—basic 313,790 305,343 306,201 309,954 Weighted average common shares outstanding—diluted 313,790 325,997 306,201 333,738 The following is a reconciliation of the Company’s basic weighted average shares outstanding to diluted weighted average shares outstanding during the periods presented (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Basic weighted average number of shares outstanding 313,790 305,343 306,201 309,954 Add: Dilutive effect of RSUs — 3,041 — 3,444 Add: Dilutive effect of PSUs — 1,486 — 2,462 Add: Dilutive effect of stock options — — — — Add: Dilutive effect of 2026 Convertible Notes — 16,127 — 17,878 Diluted weighted average number of shares outstanding 313,790 325,997 306,201 333,738 Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share (1) RSUs 6,158 — 6,562 — PSUs 2,748 — 2,706 — Stock options 357 349 388 350 2026 Convertible Notes 18,778 — 18,778 — (1) The potential dilutive effects of these awards were excluded from the computation of diluted earnings (loss) per common share because the inclusion of these awards would have been anti-dilutive. (e) Income Taxes The Company recognizes deferred tax assets and liabilities for temporary differences resulting from net operating loss carryforwards for income tax purposes and the differences between the financial statement and tax basis of assets and liabilities. The effect of changes in tax laws or tax rates is recognized in income during the period such changes are enacted. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion, or all, of the deferred tax assets will not be realized. On July 8, 2022, Pennsylvania enacted new tax laws that are effective January 1, 2023 on a prospective basis that reduce the state’s corporate income tax rate. As a result of this tax law change, the Company’s net deferred income tax liability was reduced by (f) Recently Issued Accounting Standards Convertible Debt Instruments In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity Debt with Conversion and Other Options , that required separate accounting for conversion features, and instead, allows the debt instrument and conversion features to be accounted for as a single debt instrument. It is effective for interim and annual reporting periods beginning after December 31, 2021. The Company adopted the standard effective January 1, 2022 Upon adoption of this new standard, the Company reclassified $24 million, net of deferred income taxes and equity issuance costs, from additional paid-in capital and increased long-term debt by $27 million, reduced deferred income tax liability by $6 million and reduced accumulated deficit by $3 million as of January 1, 2022. Additionally, annual interest expense for the 2026 Convertible Notes beginning January 1, 2022 is based on an effective interest rate of Income Taxes In December 2019, the FASB issued ASU No. 2019-12, Simplifying the Accounting for Income Taxes . Income Taxes

Transactions

Transactions	9 Months Ended
Transactions	Sep. 30, 2022
Conveyance Of Overriding Royalty Interest And Drilling Partnership Formation [Abstract]
Transactions	(3) Transactions (a) Conveyance of Overriding Royalty Interest On June 15, 2020, the Company announced the consummation of a transaction with an affiliate of Sixth Street Partners, LLC (“Sixth Street”) relating to certain overriding royalty interests across the Company’s existing asset base (the “ORRIs”). In connection with the transaction, the Company contributed the ORRIs to Martica and Sixth Street contributed $300 million in cash (subject to customary adjustments) and agreed to contribute up to an additional $102 million in cash if certain production thresholds attributable to the ORRIs are achieved in the third quarter of 2020 and first quarter of 2021. All cash contributed by Sixth Street at the initial closing was distributed to the Company. The Company met the applicable production thresholds related to the third quarter of 2020 and the first quarter of 2021 as of September 30, 2020 and March 31, 2021, respectively. The Company received a $51 million cash distribution during each of the fourth quarter of 2020 and the second quarter of 2021. (b) Drilling Partnership On February 17, 2021, Antero Resources announced the formation of a drilling partnership with QL Capital Partners (“QL”), an affiliate of Quantum Energy Partners, for the Company’s 2021 through 2024 drilling program. Under the terms of the arrangement, each year in which QL participates represents an annual tranche, and QL will be conveyed a working interest in any wells spud by Antero Resources during such tranche year. For 2021 and 2022, Antero Resources and QL agreed to the estimated internal rate of return (“IRR”) of the Company’s capital budget for each annual tranche, and QL agreed to participate in the 2021 and 2022 tranches. For each subsequent year through 2024, Antero Resources will propose a capital budget and estimated IRR for all wells to be spud during such year and, subject to the mutual agreement of the parties that the estimated IRR for the year exceeds a specified return, QL will be obligated to participate in such tranche. Antero Resources develops and manages the drilling program associated with each tranche, including the selection of wells. Additionally, for each annual tranche in which QL participates, Antero Resources and QL will enter into assignments, bills of sale and conveyances pursuant to which QL will be conveyed a proportionate working interest percentage in each well spud in that year, which conveyances will not be subject to any reversion. Under the terms of the arrangement, QL funded 20% of development capital for wells spud in 2021, and will fund 15% in 2022 and between 15% and 20% of development capital spending for wells spud on an annual basis in 2023 and 2024, which funding amounts represent QL’s proportionate working interest in such wells. Additionally, Antero Resources may receive a carry in the form of a one-time payment from QL for each annual tranche if the IRR for such tranche exceeds certain specified returns, which will be determined no earlier than October 31 and no later than December 1 following the end of each tranche year. All of the wells spud during each calendar year period will be a separate annual tranche. Capital costs in excess of, and cost savings below, a specified percentage of budgeted amounts for each annual tranche will be for Antero Resources’ account. Subject to the preceding sentence, for any wells included in a tranche, QL is obligated and responsible for its working interest share of costs and liabilities, and is entitled to its working interest share of revenues, associated with such wells for the life of such wells. If Antero Resources presents a capital budget for an annual tranche with an estimated IRR equal to or exceeding a specified return that QL in good faith believes is less than such specified return and QL elects not to participate, Antero Resources will not be obligated to offer QL the opportunity to participate in subsequent annual tranches. The Company has accounted for the drilling partnership as a conveyance under ASC 932, Extractive Activities—Oil and Gas

Revenue

Revenue	9 Months Ended
Revenue	Sep. 30, 2022
Revenue
Revenue	(4) Revenue (a) Disaggregation of Revenue The table set forth below presents revenue disaggregated by type and reportable segment to which it relates (in thousands). See Note 16—Reportable Segments to the unaudited condensed financial statements for more information on reportable segments. Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Reportable Segment Revenues from contracts with customers: Natural gas sales $ 884,669 1,736,039 2,231,558 4,290,825 Exploration and production Natural gas liquids sales (ethane) 57,919 117,253 137,446 274,546 Exploration and production Natural gas liquids sales (C3+ NGLs) 540,408 503,563 1,365,581 1,708,963 Exploration and production Oil sales 56,734 67,025 153,326 219,504 Exploration and production Marketing 232,685 159,985 562,928 335,173 Marketing Total revenue from contracts with customers 1,772,415 2,583,865 4,450,839 6,829,011 Loss from derivatives, deferred revenue and other sources, net (1,238,532) (519,241) (2,225,678) (1,775,862) Total revenue $ 533,883 2,064,624 2,225,161 5,053,149 (b) Transaction Price Allocated to Remaining Performance Obligations For the Company’s product sales that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606, Revenue from Contracts with Customers (“ASC 606”), which does not require the disclosure of the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under the Company’s product sales contracts, each unit of product delivered to the customer represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. For the Company’s product sales that have a contract term of one year or less, the Company utilized the practical expedient in ASC 606, which does not require the disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of (c) Contract Balances Under the Company’s sales contracts, the Company invoices customers after its performance obligations have been satisfied, at which point payment is unconditional. Accordingly, the Company’s contracts do not give rise to contract assets or liabilities. As of December 31, 2021 and September 30, 2022, the Company’s receivables from contracts with customers were $

Equity Method Investments

Equity Method Investments	9 Months Ended
Equity Method Investments	Sep. 30, 2022
Equity Method Investments.
Equity Method Investments	(5) Equity Method Investment (a) Summary of Equity Method Investment As of September 30, 2022, Antero owned approximately 29.1% of Antero Midstream Corporation’s (“Antero Midstream”) common stock, which is reflected in Antero’s unaudited condensed consolidated financial statements using the equity method of accounting. The following table sets forth a reconciliation of Antero’s investment in unconsolidated affiliate (in thousands): Balance as of December 31, 2021 (1) $ 232,399 Equity in earnings of unconsolidated affiliate 54,863 Dividends from unconsolidated affiliate (93,854) Elimination of intercompany profit 29,474 Balance as of September 30, 2022 (1) $ 222,882 (1) The fair value of the Company’s investment in Antero Midstream as of December 31, 2021 and September 30, 2022 was $1.3 billion based on the quoted market share price of Antero Midstream. (b) Summarized Financial Information of Antero Midstream The tables set forth below present summarized financial information of Antero Midstream (in thousands): Balance Sheet (Unaudited) December 31, September 30, 2021 2022 Current assets $ 83,804 80,785 Noncurrent assets 5,460,197 5,483,036 Total assets $ 5,544,001 5,563,821 Current liabilities $ 114,009 106,382 Noncurrent liabilities 3,143,294 3,245,584 Stockholders' equity 2,286,698 2,211,855 Total liabilities and stockholders' equity $ 5,544,001 5,563,821 Statement of Operations Nine Months Ended September 30, 2021 2022 Revenues $ 681,712 678,432 Operating expenses 254,905 283,112 Income from operations 426,807 395,320 Net income $ 252,991 243,449

Accrued Liabilities

Accrued Liabilities	9 Months Ended
Accrued Liabilities	Sep. 30, 2022
Accrued Liabilities
Accrued Liabilities	(6) Accrued Liabilities Accrued liabilities consisted of the following items (in thousands): (Unaudited) December 31, September 30, 2021 2022 Capital expenditures $ 46,983 50,785 Gathering, compression, processing and transportation expenses 164,900 185,383 Marketing expenses 50,589 79,119 Interest expense, net 65,093 13,819 Production and ad valorem taxes 44,298 40,152 General and administrative expense 27,740 25,693 Derivative settlements payable 35,202 84,062 Other 22,439 18,534 Total accrued liabilities $ 457,244 497,547

Long-Term Debt

Long-Term Debt	9 Months Ended
Long-Term Debt	Sep. 30, 2022
Long-Term Debt
Long-Term Debt	(7) Long-Term Debt Long-term debt consisted of the following items (in thousands): (Unaudited) December 31, September 30, 2021 2022 Credit Facility (a) $ — 9,000 5.00% senior notes due 2025 (d) 584,635 — 8.375% senior notes due 2026 (e) 325,000 103,892 7.625% senior notes due 2029 (f) 584,000 415,837 5.375% senior notes due 2030 (g) 600,000 600,000 4.25% convertible senior notes due 2026 (h) 81,570 56,932 Total principal 2,175,205 1,185,661 Unamortized discount, net (27,772) — Unamortized debt issuance costs (21,989) (12,833) Long-term debt $ 2,125,444 1,172,828 (a) Senior Secured Revolving Credit Facility Antero Resources has a senior secured revolving credit facility with a consortium of bank lenders. On October 26, 2021, Antero Resources entered into an amended and restated senior secured revolving credit facility (the “Credit Facility”). As of December 31, 2021 and September 30, 2022, the Credit Facility had a borrowing base of billion. The borrowing base was re-affirmed in the semi-annual redetermination in October 2022. The maturity date of the Credit Facility is the earlier of (i) October 26, 2026 and (ii) the date that is prior to the earliest stated redemption date of any series of the Company’s then outstanding senior notes. As of September 30, 2022, the Credit Facility had an available borrowing capacity of The Credit Facility contains requirements with respect to leverage and current ratios, and certain covenants, including restrictions on our ability to incur debt and limitations on our ability to pay dividends unless certain customary conditions are met, in each case, subject to customary carve-outs and exceptions. Antero Resources was in compliance with all of the financial covenants under the Credit Facility as of December 31, 2021 and September 30, 2022. The senior secured revolving credit facility agreement in effect prior to October 26, 2021 provided for borrowing under either an Alternate Base Rate or as a Eurodollar Loan (as each term is defined in the agreement), and the Credit Facility provides for borrowing at either an Adjusted Term Secured Overnight Financing Rate (“SOFR”), an Adjusted Daily Simple SOFR or an Alternate Base Rate (each as defined in the Credit Facility). The Credit Facility provides for interest only payments until maturity at which time all outstanding borrowings are due. Interest was payable at a variable rate based on LIBOR or the Alternative Base Rate (as defined in the agreement), determined by election at the time of borrowing, plus an applicable margin rate under the senior secured revolving credit facility agreement in effect prior to October 26, 2021. Interest is payable at a variable rate based on SOFR or the Alternate Base Rate, determined by election at the time of borrowing, plus an applicable margin rate under the Credit Facility. Interest at the time of borrowing is determined with reference to the Antero Resources’ then-current leverage ratio subject to certain exceptions. Commitment fees on the unused portion of the Credit Facility are due quarterly at rates ranging from with respect to the Credit Facility, determined with reference to borrowing base utilization, subject to certain exceptions based on the leverage ratio then in effect. The Credit Facility includes fall away covenants, lower interest rates and reduced collateral requirements that Antero Resources may elect if Antero Resources is assigned an Investment Grade Rating (as defined in the Credit Facility). As of December 31, 2021, Antero Resources had no borrowings under the Credit Facility and outstanding letters of credit of $531 million. As of September 30, 2022, Antero Resources had an outstanding balance under the Credit Facility of $ (b) 5.125% Senior Notes Due 2022 On May 6, 2014, Antero Resources issued $600 million of 5.125% senior notes due December 1, 2022 (the “2022 Notes”) at par . On September 18, 2014, Antero Resources issued an additional of par. The Company repurchased or otherwise fully redeemed all of the 2022 Notes between 2019 and the first quarter of 2021. Interest on the 2022 Notes was payable on June 1 and December 1 of each year. See “—Debt Repurchase Program” below for more information. (c) 5.625% Senior Notes Due 2023 On March 17, 2015, Antero Resources issued $750 million of 5.625% senior notes due June 1, 2023 (the “2023 Notes”) at par . 1 of each year. See “—Debt Repurchase Program” below for more information. (d) 5.00% Senior Notes Due 2025 On December 21, 2016, Antero Resources issued $600 million of 5.00% senior notes due March 1, 2025 (the “2025 Notes”) at par . The Company repurchased or otherwise fully redeemed all of the 2025 Notes between 2020 and the first quarter of 2022. Interest on the 2025 Notes was payable on March 1 and September 1 of each year. See “—Debt Repurchase Program” below for more information. (e) 8.375% Senior Notes Due 2026 On January 4, 2021, Antero Resources issued $500 million of 8.375% senior notes due July 15, 2026 (the “2026 Notes”) at par . The Company redeemed million principal amount of the 2026 Notes remained outstanding. See “—Debt Repurchase Program” below for more information. The 2026 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2026 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2026 Notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero Resources’ existing subsidiaries that guarantee the Credit Facility and certain of its future restricted subsidiaries. Interest on the 2026 Notes is payable on January 15 and July 15 of each year. Antero Resources may redeem all or part of the 2026 Notes at any time on or after January 15, 2024 at redemption prices ranging from on or after January 15, 2026. At any time prior to January 15, 2024, Antero Resources may also redeem the 2026 Notes, in whole or in part, at a price equal to of the principal amount of the 2026 Notes plus a “make-whole” premium and accrued and unpaid interest. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2026 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to (f) 7.625% Senior Notes Due 2029 On January 26, 2021, Antero Resources issued $700 million of 7.625% senior notes due February 1, 2029 (the “2029 Notes”) at par . The Company redeemed million principal amount of the 2029 Notes remained outstanding. See “—Debt Repurchase Program” below for more information. The 2029 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2029 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2029 Notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero Resources’ existing subsidiaries that guarantee the Credit Facility and certain of its future restricted subsidiaries. Interest on the 2029 Notes is payable on February 1 and August 1 of each year. Antero Resources may redeem all or part of the 2029 Notes at any time on or after February 1, 2024 at redemption prices ranging from on or after February 1, 2027. In addition, on or before February 1, 2024, Antero Resources may redeem up to million aggregate principal amount of outstanding 2029 Notes. At any time prior to February 1, 2024, Antero Resources may also redeem the 2029 Notes, in whole or in part, at a price equal to of the principal amount of the 2029 Notes plus a “make-whole” premium and accrued and unpaid interest. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2029 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to (g) 5.375% Senior Notes Due 2030 On June 1, 2021, Antero Resources issued $600 million of 5.375% senior notes due March 1, 2030 (the “2030 Notes”) at par . The 2030 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2030 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2030 Notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero Resources’ existing subsidiaries that guarantee the Credit Facility and certain of its future restricted subsidiaries. Interest on the 2030 Notes is payable on March 1 and September 1 of each year. Antero Resources may redeem all or part of the 2030 Notes at any time on or after March 1, 2025 at redemption prices ranging from on or after March 1, 2028. In addition, on or before March 1, 2025, Antero Resources may redeem up to of the principal amount of the 2030 Notes, plus accrued and unpaid interest. At any time prior to March 1, 2025, Antero Resources may also redeem the 2030 Notes, in whole or in part, at a price equal to of the principal amount of the 2030 Notes plus a “make-whole” premium and accrued and unpaid interest. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2030 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to (h) 4.25% Convertible Senior Notes Due 2026 On August 21, 2020, Antero Resources issued $250 million in aggregate principal amount of 4.25% convertible senior notes due September 1, 2026 (the “2026 Convertible Notes”). On September 2, 2020, Antero Resources issued an additional million of the 2026 Convertible Notes. During 2021, the Company completed the equitization transactions described below under “—Partial Equitizations of 2026 Convertible Notes,” that extinguished million principal amount of the 2026 Convertible Notes. During the nine months ended September 30, 2022, million aggregate principal amount of the 2026 Convertible Notes were induced into conversion by the Company. The Company elected to settle these conversions by issuing approximately million. As of September 30, 2022, million principal amount of the 2026 Convertible Notes remained outstanding. The 2026 Convertible Notes were issued pursuant to an indenture and are senior, unsecured obligations of Antero Resources. The 2026 Convertible Notes bear interest at a fixed rate of per annum, payable semi-annually in arrears on March 1 and September 1 of each year, commencing on March 1, 2021. Proceeds from the issuance of the 2026 Convertible Notes totaled The initial conversion rate is 230.2026 shares of Antero Resources’ common stock per $1,000 principal amount of 2026 Convertible Notes, subject to adjustment upon the occurrence of specified events. As of September 30, 2022, the if-converted value of the 2026 Convertible Notes was million. The 2026 Convertible Notes will mature on September 1, 2026, unless earlier repurchased, redeemed or converted. Before May 1, 2026, noteholders will have the right to convert their 2026 Convertible Notes only upon the occurrence of the following events: ● during any calendar quarter (and only during such calendar quarter) commencing after the calendar quarter ending on September 30, 2020, if the Last Reported Sale Price per share of Antero Resources’ common stock exceeds 130% of the Conversion Price for each of at least 20 Trading Days (whether or not consecutive) during the 30 consecutive Trading Days ending on, and including, the last Trading Day of the immediately preceding calendar quarter (the “Stock Price Condition”); ● during the five consecutive Business Days immediately after any 10 consecutive trading day period (such 10 consecutive Trading Day period, the “Measurement Period”) if the trading Price per $1,000 principal amount of 2026 Convertible Notes, as determined following a request by a noteholder in accordance with the procedures set forth below, for each trading day of the Measurement Period was less than 98% of the product of the last reported sale price per share of common stock on such trading day and the conversion rate on such trading day; ● if Antero Resources calls any or all of the 2026 Convertible Notes for redemption, at any time prior to the close of business on the scheduled trading day immediately preceding the redemption date; or ● upon the occurrence of certain specified corporate events as set forth in the indenture governing the 2026 Convertible Notes. From and after May 1, 2026, noteholders may convert their 2026 Convertible Notes at any time at their election until the close of business on the second scheduled trading day immediately before the maturity date. Upon conversion, Antero Resources may satisfy its conversion obligation by paying and/or delivering, as the case may be, cash, shares of Antero Resources’ common stock or a combination of cash and shares of Antero Resources’ common stock, at Antero Resources’ election, in the manner and subject to the terms and conditions provided in the indenture governing the 2026 Convertible Notes. The 2026 Convertible Notes have met the Stock Price Condition allowing holders of the 2026 Convertible Notes to exercise their conversion right as of September 30, 2022. The conversion rate is subject to adjustment under certain circumstances in accordance with the terms of the indenture governing the 2026 Convertible Notes. In addition, following certain corporate events, as described in the indenture governing the 2026 Convertible Notes, that occur prior to the maturity date, Antero Resources will increase the conversion rate for a holder who elects to convert its 2026 Convertible Notes in connection with such a corporate event. If certain corporate events that constitute a Fundamental Change occur, then noteholders may require Antero Resources to repurchase their 2026 Convertible Notes at a cash repurchase price equal to the principal amount of the 2026 Convertible Notes to be repurchased, plus accrued and unpaid interest, if any, to, but excluding, the fundamental change repurchase date. The definition of Fundamental Change includes certain business combination transactions involving Antero Resources and certain de-listing events with respect to Antero Resources’ common stock. Upon issuance, the Company separately accounted for the liability and equity components of the 2026 Convertible Notes. The liability component was recorded at the estimated fair value of a similar debt instrument without the conversion feature. The difference between the principal amount of the 2026 Convertible Notes and the estimated fair value of the liability component was recorded as a debt discount and was amortized to interest expense, together with debt issuance costs, over the term of the 2026 Convertible Notes using the effective interest method, with an effective interest rate of 15.1% per annum. As of the issuance date, the fair value of the 2026 Convertible Notes was estimated at $172 million, resulting in a debt discount at inception of $116 million. The equity component, representing the value of the conversion option, was computed by deducting the fair value of the liability component from the initial proceeds of the 2026 Convertible Notes issuance. This equity component was recorded, net of deferred taxes and issuance costs, in additional paid-in capital within the condensed consolidated balance sheet and statement of stockholders’ equity. Transaction costs related to the 2026 Convertible Notes issuance were allocated to the liability and equity components based on their relative fair values. Issuance costs attributable to the liability component were recorded within debt issuance costs on the condensed consolidated balance sheet and were amortized over the term of the 2026 Convertible Notes using the effective interest method. Issuance costs attributable to the equity component were recorded as a charge to additional paid-in capital within the condensed consolidated balance sheet and statement of stockholders’ equity. Effective January 1, 2022, the Company adopted ASU 2020-06 whereby the Company reclassified the equity component of the 2026 Convertible Notes outstanding on such date, net of deferred income taxes and equity issuance costs, from additional paid-in capital to long-term debt. See Note 2—Summary of Significant Accounting Policies to the unaudited condensed consolidated financial statements. Partial Equitizations of 2026 Convertible Notes On January 12, 2021, the Company completed a registered direct offering (the “January Share Offering”) of an aggregate of 31.4 million shares of its common stock at a price of $6.35 per share to certain holders of the 2026 Convertible Notes. The Company used the proceeds from the January Share Offering and approximately shares of common stock per $1,000 principal amount. The Company accounted for this transaction as an inducement of the 2026 Convertible Notes, and as a result, the Company recorded a million loss on convertible note equitization in the unaudited condensed consolidated statements of operations and comprehensive loss for the three months ended March 31, 2021 for the consideration paid in excess of the original terms of the 2026 Convertible Notes. Additionally, the January Equitization Transactions resulted in a loss on early extinguishment of debt of On May 13, 2021, the Company completed a registered direct offering (the “May Share Offering”) of an aggregate of 11.6 million shares of its common stock at a price of $11.01 per share to certain holders of the 2026 Convertible Notes. The Company used the proceeds from the May Share Offering and approximately shares of common stock per $1,000 principal amount. The Company accounted for this transaction as an inducement of the 2026 Convertible Notes, and as a result, the Company recorded a million loss on convertible note equitization in the unaudited condensed consolidated statements of operations and comprehensive loss for the second quarter of 2021 for the consideration paid in excess of the original terms of the 2026 Convertible Notes. Additionally, the May Equitization Transactions resulted in a loss on early extinguishment of debt of The 2026 Convertible Notes consist of the following (in thousands): (Unaudited) December 31, September 30, 2021 2022 Liability component: Principal $ 81,570 56,932 Less: unamortized note discount (1) (27,772) — Less: unamortized debt issuance costs (1,592) (1,231) Net carrying value $ 52,206 55,701 Equity component (1) $ 32,799 — (1) As of December 31, 2021, the equity component attributable to the outstanding 2026 Convertible Notes was recorded in additional paid-in capital net of $1 million of issuance costs and $8 million of deferred taxes. Upon adoption of ASU 2020-06 on January 1, 2022, the equity component was reclassified from additional paid-in capital to long-term debt and fully offset the remaining discount on the 2026 Convertible Notes. See Note 2—Summary of Significant Accounting Policies to the unaudited condensed consolidated financial statements. Interest expense recognized on the 2026 Convertible Notes related to the stated interest rate, amortization of the debt discount and debt issuance costs totaled $2 million and $1 million for the three months ended September 30, 2021 and 2022, respectively, and $9 million and $3 million for the nine months ended September 30, 2021 and 2022, respectively. (i) Debt Repurchase Program During the first quarter of 2021, the Company redeemed the remaining $661 million aggregate principal amount of its 2022 Notes at par, plus accrued and unpaid interest, and as a result, the 2022 Notes were fully retired as of February 10, 2021. The Company redeemed the remaining $574 million of the 2023 Notes at par, plus accrued and unpaid interest, during the second quarter of 2021. The 2023 Notes were fully retired as of June 1, 2021. During the third quarter of 2021, the Company redeemed $175 million of its 2026 Notes at a redemption price of 108.375% of the principal amount thereof, plus accrued and unpaid interest, and recognized a loss on early debt extinguishment of $17 million during the three months ended September 30, 2021. During the first quarter of 2022, the Company redeemed the remaining $585 million aggregate principal amount of its 2025 Notes at a redemption price of 101.25% of the principal amount thereof, plus accrued and unpaid interest and recognized a loss on early debt extinguishment of $11 million. During the second quarter of 2022, the Company repurchased million. During the third quarter of 2022, the Company repurchased through its previously disclosed tender offer and open market transactions (i) plus accrued and unpaid interest, plus accrued and unpaid interest . For the three and nine months ended September 30, 2022, the Company recognized a loss on early debt extinguishment from these repurchases of

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
Asset Retirement Obligations	Sep. 30, 2022
Asset Retirement Obligations
Asset Retirement Obligations	(8) Asset Retirement Obligations The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations—December 31, 2021 $ 53,952 Obligations incurred 2,445 Accretion expense 4,069 Settlement of obligations (946) Obligations on sold properties (42) Revisions to prior estimates (1,467) Asset retirement obligations—September 30, 2022 $ 58,011 Asset retirement obligations are included in Other liabilities on the Company’s condensed consolidated balance sheets.

Equity-Based Compensation and C

Equity-Based Compensation and Cash Awards	9 Months Ended
Equity-Based Compensation and Cash Awards	Sep. 30, 2022
Equity-Based Compensation and Cash Awards
Equity-Based Compensation and Cash Awards	(9) Equity-Based Compensation and Cash Awards On June 17, 2020, Antero Resources’ stockholders approved the Antero Resources Corporation 2020 Long-Term Incentive Plan (the “2020 Plan”), which replaced the Antero Resources Corporation Long-Term Incentive Plan (the “2013 Plan”), and the 2020 Plan became effective as of such date. The 2020 Plan provides for grants of stock options (including incentive stock options), stock appreciation rights, restricted stock awards, RSU awards, vested stock awards, dividend equivalent awards and other stock-based and cash awards. The terms and conditions of the awards granted are established by the Compensation Committee of Antero Resources’ Board of Directors. Employees, officers, non-employee directors and other service providers of the Company and its affiliates are eligible to receive awards under the 2020 Plan. No further awards will be granted under the 2013 Plan on or after June 17, 2020. The 2020 Plan provides for the reservation of 10,050,000 shares of the Company’s common stock, plus the number of certain shares that become available again for delivery from the 2013 Plan in accordance with the share recycling provisions described below. The share recycling provisions allow for all or any portion of an award (including an award granted under the 2013 Plan that was outstanding as of June 17, 2020) that expires or is cancelled, forfeited, exchanged, settled for cash or otherwise terminated without actual delivery of the shares to be considered not delivered and thus, available for new awards under the 2020 Plan. Further, any shares withheld or surrendered in payment of any taxes relating to awards that were outstanding under either the 2013 Plan as of June 17, 2020 or are granted under the 2020 Plan (other than stock options and stock appreciation rights), will again be available for new awards under the 2020 Plan. A total of 8,406,240 shares were available for future grant under the 2020 Plan as of September 30, 2022. Antero Midstream Partners LP’s (“Antero Midstream Partners”) general partner was authorized to grant up to 10,000,000 common units representing limited partner interests in Antero Midstream Partners under the Antero Midstream Partners LP Long-Term Incentive Plan (the “AMP Plan”) to non-employee directors of its general partner and certain officers, employees and consultants of Antero Midstream Partners and its affiliates (which includes Antero Resources). Antero Resources deconsolidated Antero Midstream Partners on March 12, 2019, and on such date, each outstanding phantom unit award under the AMP Plan was assumed by Antero Midstream and converted into RSUs (all such RSUs, the “Converted AM RSU Awards”) under the Antero Midstream Long Term Incentive Plan (the “AM Plan”). Each RSU award under the AM Plan represents a right to receive The Company’s equity-based compensation expense, by type of award, is as follows (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 RSU awards $ 3,327 4,974 9,957 12,468 PSU awards 1,452 5,070 3,211 9,501 Converted AM RSU Awards (1) 186 8 988 203 Equity awards issued to directors 333 350 1,033 1,050 Total expense $ 5,298 10,402 15,189 23,222 (1) Antero Resources recognized compensation expense for equity awards granted under both the 2013 Plan and the AMP Plan because the awards under the AMP Plan are accounted for as if they are distributed by Antero Midstream Partners to Antero Resources. Antero Resources allocates a portion of equity-based compensation expense related to grants prior to March 12, 2019 (date of deconsolidation) to Antero Midstream Partners based on its proportionate share of Antero Resources’ labor costs. (a) Restricted Stock Unit Awards A summary of RSU award activity is as follows: Weighted Average Number of Grant Date Shares Fair Value Total awarded and unvested—December 31, 2021 5,930,607 $ 5.15 Granted 992,843 35.02 Vested (2,564,930) 4.80 Forfeited (158,102) 10.63 Total awarded and unvested—September 30, 2022 4,200,418 $ 12.22 As of September 30, 2022, there was approximately $41 million of unamortized equity-based compensation expense related to unvested RSUs. That expense is expected to be recognized over a weighted average period of approximately (b) Performance Share Unit Awards Performance Share Unit Awards Based on Total Shareholder Return In 2019, the Company granted PSUs to certain of its employees and executive officers that vest based on Antero Resources’ absolute total shareholder return at the end of a three-year performance period (“2019 Absolute TSR PSUs”). The number of shares of common stock that could ultimately be earned ranged from of the target number of PSUs granted. During the second quarter of 2022, the market-based performance condition for the 2019 Absolute TSR PSUs was met at In April 2022, the Company granted PSU awards to certain of its senior management and executive officers that vest based on Antero Resources’ absolute total shareholder return determined as of the last day of each of three one-year performance periods ending on April 15, 2023, April 15, 2024 and April 15, 2025, and one cumulative three-year performance period ending on April 15, 2025, in each case, subject to certain continued employment criteria (“2022 Absolute TSR PSUs”). The number of shares of common stock that may ultimately be earned following the end of the cumulative three-year performance period with respect to the 2022 Absolute TSR PSUs ranges from zero to 200% of the target number of 2022 Absolute TSR PSUs originally granted. Expense related to these PSUs is recognized on a graded-vested basis over the term of each performance period. Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. The following table presents the assumptions used in the Monte Carlo valuation model and the grant date fair value information for the 2022 Absolute TSR PSUs: Dividend yield — % Volatility 88 % Risk-free interest rate 2.65 % Weighted average fair value of awards granted—Absolute TSR $ 47.53 Performance Share Unit Awards Based on Leverage Ratio In April 2022, the Company granted PSUs to certain of its senior management and executive officers that vest based on the Company’s total debt less cash and cash equivalents divided by the Company’s Adjusted EBITDAX ( ) determined as of the last day of each of three one-year performance periods ending on December 31, 2022, December 31, 2023 and December 31, 2024, in each case, subject to certain continued employment criteria (“Leverage Ratio PSUs”). The number of shares of common stock that may ultimately be earned following the end of the third performance period with respect to the Leverage Ratio PSUs ranges from zero to 200% of the target number of Leverage Ratio PSUs originally granted. Expense related to the Leverage Ratio PSUs is recognized on a graded-vested basis over the term of each performance period that reflects the number of shares of common stock that are expected to be issued at the end of each measurement period, and such expense is reversed if the likelihood of achieving the performance condition becomes improbable. As of September 30, 2022, the likelihood of achieving the performance conditions related to the Leverage Ratio PSUs was probable. Summary Information for Performance Share Unit Awards A summary of PSU award activity is as follows: Weighted Number of Average Grant Units Date Fair Value Total awarded and unvested—December 31, 2021 1,847,279 $ 8.31 Granted 436,537 29.98 Vested (1,210,712) 9.26 Forfeited — — Cancelled (unearned) — — Total awarded and unvested—September 30, 2022 1,073,104 $ 16.05 As of September 30, 2022, there was approximately $15 million of unamortized equity-based compensation expense related to unvested PSUs. That expense is expected to be recognized over a weighted average period of approximately (c) Converted AM RSU Awards A summary of the Converted AM RSU Awards is as follows: Weighted Average Number of Grant Date Units Fair Value Total awarded and unvested—December 31, 2021 81,707 $ 13.46 Granted — — Vested (78,880) 13.50 Forfeited — — Total awarded and unvested—September 30, 2022 2,827 $ 12.38 million of unamortized equity-based compensation expense related to unvested Converted AM RSU Awards. That expense is expected to be recognized over a weighted average period of (d) Stock Options A summary of stock option activity is as follows: Weighted Weighted Average Average Remaining Intrinsic Stock Exercise Contractual Value Options Price Life (in thousands) (1) Outstanding—December 31, 2021 351,794 $ 50.79 3.0 $ — Granted — — Exercised — — Forfeited — — Expired (3,417) 50.00 Outstanding—September 30, 2022 348,377 $ 50.80 2.1 $ — Vested—September 30, 2022 348,377 $ 50.80 2.1 $ — Exercisable—September 30, 2022 348,377 $ 50.80 2.1 $ — (1) Intrinsic values are based on the exercise price of the options and the closing price of Antero Resources’ common stock on the referenced dates. As of September 30, 2022, all stock options were fully vested resulting in no unamortized equity-based compensation expense. (e) Cash Awards In January 2020, the Company granted cash awards of approximately $3 million to certain executives under the 2013 Plan, and compensation expense for these awards is recognized ratably over the vesting period for each of three tranches through January 20, 2023. In July 2020, the Company granted additional cash awards in the aggregate of . As of December 31, 2021 and September 30, 2022, the Company has recorded approximately

Fair Value

Fair Value	9 Months Ended
Fair Value	Sep. 30, 2022
Fair Value
Fair Value	(10) Fair Value The carrying values of accounts receivable and accounts payable as of December 31, 2021 and September 30, 2022 approximated market values because of their short-term nature. The carrying values of the amounts outstanding under the Credit Facility as of December 31, 2021 and September 30, 2022 approximated fair value because the variable interest rates are reflective of current market conditions. The following table sets forth the fair value and carrying value of the senior notes and 2026 Convertible Notes (in thousands): (Unaudited) December 31, 2021 September 30, 2022 Fair Carrying Fair Carrying Value (1) Value (2) Value (1) Value (2) 2025 Notes $ 594,866 581,117 — — 2026 Notes 370,013 321,738 108,692 103,028 2029 Notes 654,080 577,149 415,837 411,363 2030 Notes 641,400 593,234 537,780 593,736 2026 Convertible Notes 331,655 52,206 400,454 55,701 Total $ 2,592,014 2,125,444 1,462,763 1,163,828 (1) Fair values are based on Level 2 market data inputs. (2) Carrying values are presented net of unamortized debt issuance costs and debt discounts or premiums. See Note 9—Equity-Based Compensation and Cash Awards to the unaudited condensed consolidated financial statements for information regarding the fair value of equity-based awards. See Note 11—Derivative Instruments to the unaudited condensed consolidated financial statements for information regarding the fair value of derivative financial instruments.

Derivative Instruments

Derivative Instruments	9 Months Ended
Derivative Instruments	Sep. 30, 2022
Derivative Instruments.
Derivative Instruments	(11) Derivative Instruments The Company is exposed to certain risks relating to its ongoing business operations, and it uses derivative instruments to manage its commodity price risk. In addition, the Company periodically enters into contracts that contain embedded features that are required to be bifurcated and accounted for separately as derivatives. (a) Commodity Derivative Positions The Company periodically enters into natural gas, NGLs and oil derivative contracts with counterparties to hedge the price risk associated with its production. These derivatives are not entered into for trading purposes. To the extent that changes occur in the market prices of natural gas, NGLs and oil, the Company is exposed to market risk on these open contracts. This market risk exposure is generally offset by the change in market prices of natural gas, NGLs and oil recognized upon the ultimate sale of the Company’s production. The Company was party to various fixed price commodity swap contracts that settled during the three and nine months ended September 30, 2021 and 2022. The Company enters into these swap contracts when management believes that favorable future sales prices for the Company’s production can be secured. Under these swap agreements, when actual commodity prices upon settlement exceed the fixed price provided by the swap contracts, the Company pays the difference to the counterparty. When actual commodity prices upon settlement are less than the contractually provided fixed price, the Company receives the difference from the counterparty. In addition, the Company has entered into basis swap contracts in order to hedge the difference between the New York Mercantile Exchange (“NYMEX”) index price and a local index price. Under these basis swap agreements, when actual commodity prices upon settlement exceed the fixed price provided by the swap contracts, the Company receives the difference from the counterparty. When actual commodity prices upon settlement are less than the contractually provided fixed price, the Company pays the difference to the counterparty. The Company’s derivative contracts have not been designated as hedges for accounting purposes; therefore, all gains and losses are recognized in the Company’s statements of operations. As of September 30, 2022, the Company’s fixed price swap positions excluding Martica, the Company’s consolidated VIE, were as follows: Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas October-December 2022 Henry Hub 1,105,897 MMBtu/day $ 2.48 /MMBtu January-December 2023 Henry Hub 43,000 MMBtu/day 2.37 /MMBtu In addition, the Company has a swaption agreement, which entitles the counterparty the right, but not the obligation, to enter into a fixed price swap agreement on December 21, 2023 to purchase 427,500 MMBtu per day at a price of $2.77 per MMBtu for the year ending December 31, 2024. The Company also has a call option and an embedded put option tied to NYMEX pricing for the production volumes associated with the Company’s retained interest in the volumetric production payment transaction (“VPP”) properties. The put option was embedded within another contract, and since the embedded put option was not clearly and closely related to its host contract, the Company bifurcated this derivative instrument and reflects it at fair value in the unaudited condensed consolidated financial statements. As of September 30, 2022, the Company’s call option and embedded put option arrangements were as follows: Embedded Call Option Put Option Commodity / Settlement Period Index Contracted Volume Strike Price Strike Price Natural Gas October-December 2022 Henry Hub 59,000 MMBtu/day $ 2.545 /MMBtu $ 2.545 /MMBtu January-December 2023 Henry Hub 55,000 MMBtu/day 2.466 /MMBtu 2.466 /MMBtu January-December 2024 Henry Hub 53,000 MMBtu/day 2.477 /MMBtu 2.527 /MMBtu January-December 2025 Henry Hub 44,000 MMBtu/day 2.564 /MMBtu 2.614 /MMBtu January-December 2026 Henry Hub 32,000 MMBtu/day 2.629 /MMBtu 2.679 /MMBtu As of September 30, 2022, the Company’s natural gas basis swap positions, which settle on the pricing index to basis differential of the Columbia Gas Transmission pipeline (“TCO”) to the NYMEX Henry Hub natural gas price were as follows: Weighted Average Commodity / Settlement Period Index to Basis Differential Contracted Volume Hedged Differential Natural Gas October-December 2022 NYMEX to TCO 60,000 MMBtu/day $ 0.515 /MMBtu January-December 2023 NYMEX to TCO 50,000 MMBtu/day 0.525 /MMBtu January-December 2024 NYMEX to TCO 50,000 MMBtu/day 0.530 /MMBtu As of September 30, 2022, the Company’s fixed price swap positions for Martica, the Company’s consolidated VIE, were as follows: Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas October-December 2022 Henry Hub 40,592 MMBtu/day $ 2.39 /MMBtu January-December 2023 Henry Hub 35,616 MMBtu/day 2.35 /MMBtu January-December 2024 Henry Hub 23,885 MMBtu/day 2.33 /MMBtu January-March 2025 Henry Hub 18,021 MMBtu/day 2.53 /MMBtu Propane October-December 2022 Mont Belvieu Propane-OPIS Non-TET 952 Bbl/day 19.32 /Bbl Natural Gasoline October-December 2022 Mont Belvieu Natural Gasoline-OPIS Non-TET 288 Bbl/day 34.86 /Bbl January-December 2023 Mont Belvieu Natural Gasoline-OPIS Non-TET 247 Bbl/day 40.74 /Bbl Oil October-December 2022 West Texas Intermediate 105 Bbl/day 43.50 /Bbl January-December 2023 West Texas Intermediate 99 Bbl/day 44.88 /Bbl January-December 2024 West Texas Intermediate 43 Bbl/day 44.02 /Bbl January-March 2025 West Texas Intermediate 39 Bbl/day 45.06 /Bbl (b) Summary The table below presents a summary of the fair values of the Company’s derivative instruments and where such values are recorded in the condensed consolidated balance sheets (in thousands). (Unaudited) Balance Sheet December 31, September 30, Location 2021 2022 Asset derivatives not designated as hedges for accounting purposes: Commodity derivatives—current Derivative instruments $ — — Embedded derivatives—current Derivative instruments 757 954 Commodity derivatives—noncurrent Derivative instruments — — Embedded derivatives—noncurrent Derivative instruments 14,369 7,327 Total asset derivatives (1) 15,126 8,281 Liability derivatives not designated as hedges for accounting purposes: Commodity derivatives—current (2) Derivative instruments 559,851 612,237 Commodity derivatives—noncurrent (2) Derivative instruments 181,806 445,481 Total liability derivatives (1) 741,657 1,057,718 Net derivatives liability (1) $ (726,531) (1,049,437) (1) The fair value of derivative instruments was determined using Level 2 inputs. (2) As of December 31, 2021, approximately $55 million of commodity derivative liabilities, including $31 million of current commodity derivatives and $24 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. As of September 30, 2022, approximately $84 million of commodity derivative liabilities, including $53 million of current commodity derivatives and $31 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. The following table sets forth the gross values of recognized derivative assets and liabilities, the amounts offset under master netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets as of the dates presented, all at fair value (in thousands): (Unaudited) December 31, 2021 September 30, 2022 Net Amounts of Net Amounts of Gross Gross Assets Gross Gross Assets Amounts Amounts Offset (Liabilities) on Amounts Amounts Offset (Liabilities) on Recognized Recognized Balance Sheet Recognized Recognized Balance Sheet Commodity derivative assets $ 2,177 (2,177) — 516 (516) — Embedded derivative assets 15,126 — 15,126 8,281 — 8,281 Commodity derivative liabilities (743,834) 2,177 (741,657) (1,058,234) 516 (1,057,718) The following table sets forth a summary of derivative fair value gains and losses and where such values are recorded in the unaudited condensed consolidated statements of operations (in thousands): Statement of Operations Three Months Ended September 30, Nine Months Ended September 30, Location 2021 2022 2021 2022 Commodity derivative fair value losses (1) Revenue $ (1,238,384) (500,557) (2,228,076) (1,732,720) Embedded derivative fair value losses (1) Revenue (12,082) (29,966) (31,986) (74,845) (1) The fair value of derivative instruments was determined using Level 2 inputs .

Leases

Leases	9 Months Ended
Leases	Sep. 30, 2022
Leases
Leases	(12) Leases The Company leases certain office space, processing plants, drilling rigs and completion services, gas gathering lines, compressor stations, and other office and field equipment. Leases with an initial term of 12 months or less are considered short-term and are not recorded on the balance sheet. Instead, the short-term leases are recognized in expense on a straight-line basis over the lease term. Most leases include one or more options to renew, with renewal terms that can extend the lease from one or more. The exercise of the lease renewal options is at the Company’s sole discretion. The depreciable lives of the leased assets are limited by the expected lease term, unless there is a transfer of title or purchase option reasonably certain of exercise. Certain of the Company’s lease agreements include minimum payments based on a percentage of produced volumes over contractual levels and others include rental payments adjusted periodically for inflation. The Company considers all contracts that have assets specified in the contract, either explicitly or implicitly, that the Company has substantially all of the capacity of the asset, and has the right to obtain substantially all of the economic benefits of that asset, without the lessor’s ability to have a substantive right to substitute that asset, as leased assets. For any contract deemed to include a leased asset, that asset is capitalized on the balance sheet as a right-of-use asset and a corresponding lease liability is recorded at the present value of the known future minimum payments of the contract using a discount rate on the date of commencement. The leased asset classification is determined at the date of recording as either operating or financing, depending upon certain criteria of the contract. The discount rate used for present value calculations is the discount rate implicit in the contract. If an implicit rate is not determinable, a collateralized incremental borrowing rate is used at the date of commencement. As new leases commence or previous leases are modified the discount rate used in the present value calculation is the current period applicable discount rate. The Company has made an accounting policy election to adopt the practical expedient for combining lease and non-lease components on an asset class basis. This expedient allows the Company to combine non-lease components such as real estate taxes, insurance, maintenance and other operating expenses associated with the leased premises with the lease component of a lease agreement on an asset class basis when the non-lease components of the agreement cannot be easily bifurcated from the lease payment. Currently, the Company is only applying this expedient to certain office space agreements. (a) Supplemental Balance Sheet Information Related to Leases The Company’s lease assets and liabilities consisted of the following items (in thousands): (Unaudited) December 31, September 30, Leases Balance Sheet Classification 2021 2022 Operating Leases Operating lease right-of-use assets: Processing plants Operating lease right-of-use assets $ 1,739,550 1,906,419 Drilling rigs and completion services Operating lease right-of-use assets 9,860 64,022 Gas gathering lines and compressor stations (1) Operating lease right-of-use assets 1,634,928 1,523,233 Office space Operating lease right-of-use assets 33,083 42,760 Vehicles Operating lease right-of-use assets 2,009 1,074 Other office and field equipment Operating lease right-of-use assets 482 4,068 Total operating lease right-of-use assets $ 3,419,912 3,541,576 Short-term operating lease obligation Short-term lease liabilities $ 455,950 535,014 Long-term operating lease obligation Long-term lease liabilities 2,963,962 3,006,562 Total operating lease obligation $ 3,419,912 3,541,576 Finance Leases Finance lease right-of-use assets: Vehicles Other property and equipment $ 550 1,407 Total finance lease right-of-use assets (2) $ 550 1,407 Short-term finance lease obligation Short-term lease liabilities $ 397 333 Long-term finance lease obligation Long-term lease liabilities 153 1,074 Total finance lease obligation $ 550 1,407 (1) Gas gathering lines and compressor station leases includes $1.5 billion related to Antero Midstream as of December 31, 2021 and September 30, 2022. See “—Related party lease disclosure” for additional discussion. (2) Financing lease assets are recorded net of accumulated amortization of $2 million and $1 million as of December 31, 2021 and September 30, 2022, respectively. The processing plants, gathering lines and compressor stations that are classified as lease liabilities are classified as such under ASC 842, Leases (b) Supplemental Information Related to Leases Costs associated with operating and finance leases were included in the unaudited condensed consolidated statement of operations and comprehensive loss (in thousands): Three Months Ended September 30, Nine Months Ended September 30, Cost Classification Location 2021 2022 2021 2022 Operating lease cost Statement of operations Gathering, compression, processing and transportation $ 386,033 378,246 1,147,985 1,109,422 Operating lease cost Statement of operations General and administrative 2,833 2,855 8,057 8,509 Operating lease cost Statement of operations Contract termination 3,369 12,000 4,213 12,000 Operating lease cost Statement of operations Lease operating 43 44 109 133 Operating lease cost Balance sheet Proved properties (1) 25,558 34,288 82,749 83,146 Total operating lease cost $ 417,836 427,433 1,243,113 1,213,210 Finance lease cost: Amortization of right-of-use assets Statement of operations Depletion, depreciation and amortization $ 132 94 391 319 Interest on lease liabilities Statement of operations Interest expense 286 44 337 78 Total finance lease cost $ 418 138 728 397 Short-term lease payments $ 21,030 38,690 62,328 115,798 (1) Capitalized costs related to drilling and completion activities. (c) Supplemental Cash Flow Information Related to Leases The following table presents the Company’s supplemental cash flow information related to leases (in thousands): Nine Months Ended September 30, 2021 2022 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 1,042,684 1,067,786 Investing cash flows from operating leases 66,042 70,654 Financing cash flows from finance leases 692 441 Noncash activities: Right-of-use assets obtained in exchange for new operating lease obligations 232,771 366,194 Increase to existing right-of-use assets and lease obligations from operating lease modifications, net (1) 345,066 119,290 (1) During the nine months ended September 30, 2021, the weighted average discount rate for remeasured operating leases decreased from 14.4% as of December 31, 2020 to 5.5% as of September 30, 2021. During the nine months ended September 30, 2022, the weighted average discount rate for remeasured operating leases decreased from 5.6% as of December 31, 2021 to 5.2% as of September 30, 2022. (d) Maturities of Lease Liabilities The table below is a schedule of future minimum payments for operating and financing lease liabilities as of September 30, 2022 (in thousands): Operating Leases Financing Leases Total Remainder of 2022 $ 178,967 145 179,112 2023 706,880 510 707,390 2024 645,692 501 646,193 2025 585,209 459 585,668 2026 534,508 210 534,718 2027 442,252 — 442,252 Thereafter 1,203,662 — 1,203,662 Total lease payments 4,297,170 1,825 4,298,995 Less: imputed interest (755,594) (418) (756,012) Total $ 3,541,576 1,407 3,542,983 (e) Lease Term and Discount Rate The following table sets forth the Company’s weighted average remaining lease term and discount rate: (Unaudited) December 31, 2021 September 30, 2022 Operating Leases Finance Leases Operating Leases Finance Leases Weighted average remaining lease term 7.6 years 1.9 years 7.4 years 3.5 years Weighted average discount rate 5.5 % 5.6 % 5.3 % 6.8 % (f) Related Party Lease Disclosure The Company has a gathering and compression agreement with Antero Midstream, whereby Antero Midstream receives a low-pressure gathering fee per Mcf, a high-pressure gathering fee per Mcf and a compression fee per Mcf, in each case subject to annual adjustments based on the consumer price index. If and to the extent the Company requests that Antero Midstream construct new low pressure lines, high pressure lines or compressor stations, the gathering and compression agreement contains options at Antero Midstream’s election for either (i) minimum volume commitments that require Antero Resources to utilize or pay for In December 2019, the Company and Antero Midstream agreed to extend the initial term of the gathering and compression agreement to 2038 and established a growth incentive fee program whereby low pressure gathering fees will be reduced from 2020 through 2023 to the extent the Company achieves certain volumetric targets at certain points during such time. Upon completion of the initial contract term, the gathering and compression agreement will continue in effect from year to year until such time as the agreement is terminated, effective upon an anniversary of the effective date of the agreement, by either the Company or Antero Midstream on or before the 180 th day prior to the anniversary of such effective date. The Company did 30, 2021. For the three and nine months ended September 30, 2022, the Company earned rebates of Gathering and compression fees paid by Antero related to this agreement were $178 million and $164 million for the three months ended September 30, 2021 and 2022, respectively. For the nine months ended September 30, 2021 and 2022, gathering and compression fees paid by Antero related to this agreement were million, respectively. As of December 31, 2021 and September 30, 2022,

Commitments

Commitments	9 Months Ended
Commitments	Sep. 30, 2022
Commitments
Commitments	(13) Commitments The following table sets forth a schedule of future minimum payments for firm transportation, drilling rig and completion services, processing, gathering and compression, and office and equipment agreements, which include leases that have a lease term in excess of one year as of September 30, 2022 (in thousands): Processing, Gathering, Compression Firm and Water Land Payment Operating and Imputed Interest Transportation Service Obligations Financing Leases for Leases (a) (b) (c) (d) (d) Total Remainder of 2022 $ 282,279 14,932 41 132,838 46,274 476,364 2023 1,157,330 71,650 — 538,749 168,641 1,936,370 2024 1,130,195 62,693 — 505,219 140,974 1,839,081 2025 1,107,995 51,391 — 471,022 114,646 1,745,054 2026 1,102,362 18,214 — 444,514 90,204 1,655,294 2027 1,098,497 16,927 — 374,087 68,165 1,557,676 Thereafter 5,860,221 84,876 — 1,076,554 127,108 7,148,759 Total $ 11,738,879 320,683 41 3,542,983 756,012 16,358,598 (a) Firm Transportation The Company has entered into firm transportation agreements with various pipelines in order to facilitate the delivery of its production to market. These contracts commit the Company to transport minimum daily natural gas or NGLs volumes at negotiated rates or pay for any deficiencies at specified reservation fee rates. The amounts in this table are based on the Company’s minimum daily volumes at the reservation fee rate. The values in the table represent the gross amounts that the Company is committed to pay; however, the Company will record in the unaudited condensed consolidated financial statements its proportionate share of costs based on its working interest. (b) Processing, Gathering, Compression and Water Service Commitments The Company has entered into various long- term gas processing, gathering, compression and water service agreements. Certain of these agreements were determined to be leases. The minimum payment obligations under the agreements that are not leases are presented in this column. The values in the table represent the gross amounts that the Company is committed to pay; however, the Company will record in the unaudited condensed consolidated financial statements its proportionate share of costs based on its working interest. (c) Land Payment Obligations The Company has entered into various land acquisition agreements. Certain of these agreements contain minimum payment obligations over various terms. The values in the table represent the minimum payments due under these arrangements. None of these agreements were determined to be leases. (d) Leases, including Imputed Interest The Company has obligations under contracts for services provided by drilling rigs and completion fleets, processing, gathering, and compression services agreements, and office and equipment leases. The values in the table represent the gross amounts that Antero Resources is committed to pay; however, the Company will record in its financial statements its proportionate share of costs based on its working interests. See Note 12—Leases to the unaudited condensed consolidated financial statements for more information on the Company’s operating and finance leases (e) Contract Terminations The Company incurs costs associated with the delay or cancellation of certain contracts with third-parties. These costs are recorded in Contract termination and included in the statement of operations and comprehensive income (loss). There are no remaining payment obligations related to these delayed or cancelled contracts as of

Contingencies

Contingencies	9 Months Ended
Contingencies	Sep. 30, 2022
Contingencies
Contingencies	(14) Contingencies Environmental In June 2018, the Company received a Notice of Violation (“NOV”) from the U.S. Environmental Protection Agency (“EPA”) Region III for alleged violations of the federal Clean Air Act and the West Virginia State Implementation Plan. The NOV alleges that combustion devices at these facilities did not meet applicable air permitting requirements. Separately, in June 2018, the Company received an information request from the EPA Region III pursuant to Section 114(a) of the Clean Air Act relating to the facilities that were inspected in September 2017 as well as additional Antero Resources facilities for the purpose of determining if the additional facilities have the same alleged compliance issues that were identified during the September 2017 inspections. Subsequently, the West Virginia Department of Environmental Protection (“WVDEP”) and the EPA Region V (covering Ohio facilities) each conducted its own inspections, and the Company has separately received NOVs from WVDEP and EPA Region V related to similar issues being investigated by the EPA Region III. The Company continues to negotiate with the EPA and WVDEP to resolve the issues alleged in the NOVs and the information request. The Company’s operations at these facilities are not suspended, and management does not expect these matters to have a material adverse effect on the Company’s financial condition, results of operations, or cash flows. WGL The Company and Washington Gas Light Company and WGL Midstream, Inc. (collectively, “WGL”) were involved in multiple contractual disputes involving firm gas sales contracts executed June 20, 2014 (the “Contracts”) that the Company began delivering gas under in January 2016. In late 2015, WGL asserted that the natural gas index price specified in the Contracts was no longer appropriate and sought to invoke an alternative index clause in the Contracts. This dispute was referred to arbitration. In January 2017, the arbitration panel ruled in the Company’s favor and found that the natural gas index price specified in the Contracts should remain. In March of 2017, WGL filed a lawsuit against the Company in Colorado district court claiming that the Company breached contractual obligations by failing to deliver “TCO pool” gas, ultimately seeking damages of more than $40 million. Subsequently, after WGL failed to take certain volumes of gas required under the Contracts, the Company filed a separate lawsuit against WGL to recover damages that WGL refused to pay. These lawsuits were consolidated and tried in June 2019. On June 20, 2019, the Company was awarded a jury verdict of approximately million in damages against WGL. In addition, the jury rejected WGL’s claim against the Company, finding that the Company did not breach the Contracts. On December 10, 2020, the Colorado Court of Appeals affirmed the judgment of the trial court in favor of the Company. In February 2021, the Company and its royalty owners received a gross payment of approximately Other The Company is party to various other legal proceedings and claims in the ordinary course of its business. The Company believes that certain of these matters will be covered by insurance and that the outcome of other matters will not have a material adverse effect on the Company’s unaudited condensed consolidated financial position, results of operations or cash flows. In addition, pending litigation against operators in the Appalachian Basin, including the Company, could have an impact on the methods for determining the amount of permitted post-production costs and types of costs that may be deducted from royalty payments, among other things, and the Company cannot predict how these issues may ultimately be resolved.

Related Parties

Related Parties	9 Months Ended
Related Parties	Sep. 30, 2022
Related Parties
Related Parties	(15) Related Parties Substantially all of Antero Midstream’s revenues were and are derived from transactions with Antero Resources. See Note 16—Reportable Segments to the unaudited condensed consolidated financial statements for the operating results of the Company’s reportable segments.

Reportable Segments

Reportable Segments	9 Months Ended
Reportable Segments	Sep. 30, 2022
Reportable Segments
Reportable Segments	(16) Reportable Segments (a) Summary of Reportable Segments The Company’s operations, which are located in the United States, are organized into three reportable segments: (i) the exploration, development and production of natural gas, NGLs and oil; (ii) marketing and utilization of excess firm transportation capacity and (iii) midstream services through the Company’s equity method investment in Antero Midstream. Substantially all of the Company’s production revenues are attributable to customers located in the United States; however, some of the Company’s production revenues are attributable to customers who then transport the Company’s production to foreign countries for resale or consumption. These segments are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Management evaluates the performance of the Company’s business segments based on operating income (loss). General and administrative expenses were allocated to the midstream segment based on the nature of the expenses and on a combination of the segments’ proportionate share of the Company’s consolidated property and equipment, capital expenditures and labor costs, as applicable. General and administrative expenses related to the marketing segment are not allocated because they are immaterial. Other income, income taxes and interest expense are primarily managed and evaluated on a consolidated basis. Intersegment sales were transacted at prices which approximate market. Accounting policies for each segment are the same as the Company’s accounting policies described in Note 2—Summary of Significant Accounting Policies to the unaudited condensed consolidated financial statements. Exploration and Production The exploration and production segment is engaged in the development, production, exploration and acquisition of natural gas, NGLs and oil properties located in the Appalachian Basin. The Company targets large, repeatable resource plays where horizontal drilling and advanced fracture stimulation technologies provide the means to economically develop and produce natural gas, NGLs and oil from unconventional formations. Marketing Where feasible, the Company purchases and sells third-party natural gas and NGLs and markets its excess firm transportation capacity, or engages third parties to conduct these activities on the Company’s behalf, in order to optimize the revenues from these transportation agreements. The Company has entered into long-term firm transportation agreements for a significant portion of its current and expected future production in order to secure guaranteed capacity to favorable markets. Equity Method Investment in Antero Midstream The Company receives midstream services through its equity method investment in Antero Midstream. Antero Midstream owns, operates and develops midstream energy infrastructure primarily to service the Company’s production and completion activity in the Appalachian Basin. Antero Midstream’s assets consist of gathering pipelines, compressor stations, interests in processing and fractionation plants and water handling assets. Antero Midstream provides midstream services to Antero Resources under long-term contracts. (b) Reportable Segments Financial Information The summarized operating results of the Company’s reportable segments are as follows (in thousands): Three Months Ended September 30, 2021 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 300,668 232,685 245 (245) 533,353 Intersegment 530 — 224,559 (224,559) 530 Total revenue 301,198 232,685 224,804 (224,804) 533,883 Operating expenses: Lease operating 25,363 — — — 25,363 Gathering, compression, processing, transportation and water handling 628,225 — 39,499 (39,499) 628,225 General and administrative 32,442 — 14,810 (14,810) 32,442 Depletion, depreciation and amortization 182,810 — 27,487 (27,487) 182,810 Impairment of oil and gas properties 26,253 — — — 26,253 Other 56,113 266,751 1,187 (1,187) 322,864 Total operating expenses 951,206 266,751 82,983 (82,983) 1,217,957 Operating income (loss) $ (650,008) (34,066) 141,821 (141,821) (684,074) Equity in earnings of unconsolidated affiliates $ 21,450 — 24,088 (24,088) 21,450 Capital expenditures for segment assets $ 387,783 — 82,583 (82,583) 387,783 Three Months Ended September 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 1,904,302 159,985 1,651 (1,651) 2,064,287 Intersegment 337 — 229,383 (229,383) 337 Total revenue 1,904,639 159,985 231,034 (231,034) 2,064,624 Operating expenses: Lease operating 27,453 — — — 27,453 Gathering, compression, processing, transportation and water handling 716,388 — 46,648 (46,648) 716,388 General and administrative 42,903 — 13,587 (13,587) 42,903 Depletion, depreciation and amortization 169,607 — 34,206 (34,206) 169,607 Impairment of oil and gas properties 33,924 — — — 33,924 Other 114,812 185,377 (1,177) 1,177 300,189 Total operating expenses 1,105,087 185,377 93,264 (93,264) 1,290,464 Operating income (loss) $ 799,552 (25,392) 137,770 (137,770) 774,160 Equity in earnings of unconsolidated affiliates $ 14,972 — 24,411 (24,411) 14,972 Capital expenditures for segment assets $ 244,680 — 74,120 (74,120) 244,680 Nine Months Ended September 30, 2021 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 1,661,682 562,928 340 (340) 2,224,610 Intersegment 551 — 681,372 (681,372) 551 Total revenue 1,662,233 562,928 681,712 (681,712) 2,225,161 Operating expenses: Lease operating 71,555 — — — 71,555 Gathering, compression, processing, transportation and water handling 1,874,664 — 118,368 (118,368) 1,874,664 General and administrative 108,693 — 46,991 (46,991) 108,693 Depletion, depreciation and amortization 564,166 — 80,956 (80,956) 564,166 Impairment of oil and gas properties 69,618 — — — 69,618 Other 141,127 627,822 8,590 (8,590) 768,949 Total operating expenses 2,829,823 627,822 254,905 (254,905) 3,457,645 Operating income (loss) $ (1,167,590) (64,894) 426,807 (426,807) (1,232,484) Equity in earnings of unconsolidated affiliates $ 57,621 — 66,347 (66,347) 57,621 Capital expenditures for segment assets $ 510,941 — 156,948 (156,948) 510,941 Nine Months Ended September 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 4,716,827 335,173 2,288 (2,288) 5,052,000 Intersegment 1,149 — 676,144 (676,144) 1,149 Total revenue 4,717,976 335,173 678,432 (678,432) 5,053,149 Operating expenses: Lease operating 70,486 — — — 70,486 Gathering, compression, processing, transportation and water handling 1,962,878 — 131,959 (131,959) 1,962,878 General and administrative 123,033 — 47,597 (47,597) 123,033 Depletion, depreciation and amortization 511,390 — 98,181 (98,181) 511,390 Impairment of oil and gas properties 79,749 — — — 79,749 Other 258,963 415,571 5,375 (5,375) 674,534 Total operating expenses 3,006,499 415,571 283,112 (283,112) 3,422,070 Operating income (loss) $ 1,711,477 (80,398) 395,320 (395,320) 1,631,079 Equity in earnings of unconsolidated affiliates $ 54,863 — 70,467 (70,467) 54,863 Capital expenditures for segment assets $ 721,420 — 236,154 (236,154) 721,420 The summarized assets of the Company’s reportable segments are as follows (in thousands): As of December 31, 2021 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Investments in unconsolidated affiliates $ 232,399 — 696,009 (696,009) 232,399 Total assets 13,864,402 32,126 5,544,001 (5,544,001) 13,896,528 (Unaudited) As of September 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Investments in unconsolidated affiliates $ 222,882 — 659,006 (659,006) 222,882 Total assets 14,350,938 62,440 5,563,821 (5,563,821) 14,413,378

Subsidiary Guarantors

Subsidiary Guarantors	9 Months Ended
Subsidiary Guarantors	Sep. 30, 2022
Subsidiary Guarantors
Subsidiary Guarantors	(17) Subsidiary Guarantors Antero Resources’ senior notes are fully and unconditionally guaranteed by Antero Resources’ existing subsidiaries that guarantee the Credit Facility. In the event a subsidiary guarantor is sold or disposed of (whether by merger, consolidation, the sale of a sufficient amount of its capital stock so that it no longer qualifies as a “Subsidiary” of Antero (as defined in the indentures governing the notes) or the sale of all or substantially all of its assets (other than by lease)) and whether or not the subsidiary guarantor is the surviving entity in such transaction to a person that is not Antero or a restricted subsidiary of Antero, such subsidiary guarantor will be released from its obligations under its subsidiary guarantee if the sale or other disposition does not violate the covenants set forth in the indentures governing the notes. In addition, a subsidiary guarantor will be released from its obligations under the indentures and its guarantee, upon the release or discharge of the guarantee of other Indebtedness (as defined in the indentures governing the notes) that resulted in the creation of such guarantee, except a release or discharge by or as a result of payment under such guarantee; if Antero designates such subsidiary as an unrestricted subsidiary and such designation complies with the other applicable provisions of the indentures governing the notes or in connection with any covenant defeasance, legal defeasance or satisfaction and discharge of the notes. The tables set forth below present summarized financial information of Antero, as parent, and its guarantor subsidiaries (in thousands). The Company’s wholly owned subsidiaries are not restricted from making distributions to the Company. Balance Sheet (Unaudited) December 31, 2021 September 30, 2022 Accounts receivable, non-guarantor subsidiaries $ — — Accounts receivable, related parties — — Other current assets 633,014 908,074 Total current assets 633,014 908,074 Noncurrent assets 12,480,350 12,753,226 Total assets $ 13,113,364 13,661,300 Accounts payable, non-guarantor subsidiaries $ — — Accounts payable, related parties 76,240 74,584 Other current liabilities 1,961,041 2,421,768 Total current liabilities 2,037,281 2,496,352 Noncurrent liabilities 5,737,999 5,368,027 Total liabilities $ 7,775,280 7,864,379 Statement of Operations Nine Months Ended September 30, 2022 Revenues $ 4,955,613 Operating expenses 3,387,903 Income from operations 1,567,710 Net income and comprehensive income including noncontrolling interests 1,168,475 Net income and comprehensive income attributable to Antero Resources Corporation $ 1,168,475

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
Summary of Significant Accounting Policies (Policies)	Sep. 30, 2022
Summary of Significant Accounting Policies
Basis of Presentation	(a) Basis of Presentation These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information and should be read in the context of the Company’s December 31, 2021 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position and accounting policies. The Company’s December 31, 2021 consolidated financial statements were included in Antero Resources’ 2021 Annual Report on Form 10-K, which was filed with the SEC. These unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, and, accordingly, do not include all of the information and footnotes required by GAAP for complete consolidated financial statements. In the opinion of management, these unaudited condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Company’s financial position as of December 31, 2021 and September 30, 2022, results of operations for the three and nine months ended September 30, 2021 and 2022 and cash flows for the nine months ended September 30, 2021 and 2022. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss. Operating results for the period ended September 30, 2022 are not necessarily indicative of the results that may be expected for the full year because of the impact of fluctuations in prices received for natural gas, NGLs and oil, natural production declines, the uncertainty of exploration and development drilling results, fluctuations in the fair value of derivative instruments, the impacts of COVID-19 and other factors.
Principles of Consolidation	(b) Principles of Consolidation The accompanying unaudited condensed consolidated financial statements include the accounts of Antero Resources Corporation, its wholly owned subsidiaries and its variable interest entity (“VIE”), Martica Holdings LLC, (“Martica”), for which the Company is the primary beneficiary. All significant intercompany accounts and transactions have been eliminated in the Company’s unaudited condensed consolidated financial statements.
Cash and Cash Equivalents	(c) Cash and Cash Equivalents The Company considers all liquid investments purchased with an initial maturity of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments. From time to time, the Company may be in the position of a “book overdraft” in which outstanding checks exceed cash and cash equivalents. The Company classifies book overdrafts in accounts payable and revenue distributions payable within its condensed consolidated balance sheets, and classifies the change in accounts payable associated with book overdrafts as an operating activity within its unaudited condensed consolidated statements of cash flows. As of December 31, 2021, the book overdrafts included within accounts payable and revenue distributions payable were million, respectively. As of September 30, 2022, the book overdrafts included within accounts payable and revenue distributions payable were
Earnings (Loss) Per Common Share	(d) Earnings (Loss) Per Common Share Earnings (loss) per common share—basic for each period is computed by dividing net income (loss) attributable to Antero by the basic weighted average number of shares outstanding during the period. Earnings (loss) per common share—diluted for each period is computed after giving consideration to the potential dilution from (i) outstanding equity awards using the treasury stock method and (ii) shares of common stock issuable upon conversion of the 2026 Convertible Notes (as defined below in Note 7—Long-Term Debt) using the if-converted method. The Company includes restricted stock unit (“RSU”) awards, performance share unit (“PSU”) awards and stock options in the calculation of diluted weighted average shares outstanding based on the number of common shares that would be issuable if the end of the period was also the end of the performance period required for the vesting of the awards. During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effects of all equity awards and the 2026 Convertible Notes are anti-dilutive. The following is a reconciliation of the Company’s earnings (loss) attributable to common stockholders for basic and diluted earnings (loss) per share (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Net income (loss) attributable to Antero Resources Corporation—common shareholders $ (549,318) 559,759 (1,088,284) 1,168,475 Add: Interest expense for 2026 Convertible Notes — 830 — 2,764 Less: Tax-effect of interest expense for 2026 Convertible Notes — (193) — (642) Net income (loss) attributable to Antero Resources Corporation—common shareholders and assumed conversions $ (549,318) 560,396 (1,088,284) 1,170,597 Income (loss) per share—basic $ (1.75) 1.83 (3.55) 3.77 Income (loss) per share—diluted $ (1.75) 1.72 (3.55) 3.51 Weighted average common shares outstanding—basic 313,790 305,343 306,201 309,954 Weighted average common shares outstanding—diluted 313,790 325,997 306,201 333,738 The following is a reconciliation of the Company’s basic weighted average shares outstanding to diluted weighted average shares outstanding during the periods presented (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Basic weighted average number of shares outstanding 313,790 305,343 306,201 309,954 Add: Dilutive effect of RSUs — 3,041 — 3,444 Add: Dilutive effect of PSUs — 1,486 — 2,462 Add: Dilutive effect of stock options — — — — Add: Dilutive effect of 2026 Convertible Notes — 16,127 — 17,878 Diluted weighted average number of shares outstanding 313,790 325,997 306,201 333,738 Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share (1) RSUs 6,158 — 6,562 — PSUs 2,748 — 2,706 — Stock options 357 349 388 350 2026 Convertible Notes 18,778 — 18,778 — (1) The potential dilutive effects of these awards were excluded from the computation of diluted earnings (loss) per common share because the inclusion of these awards would have been anti-dilutive.
Income Taxes	(e) Income Taxes The Company recognizes deferred tax assets and liabilities for temporary differences resulting from net operating loss carryforwards for income tax purposes and the differences between the financial statement and tax basis of assets and liabilities. The effect of changes in tax laws or tax rates is recognized in income during the period such changes are enacted. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion, or all, of the deferred tax assets will not be realized. On July 8, 2022, Pennsylvania enacted new tax laws that are effective January 1, 2023 on a prospective basis that reduce the state’s corporate income tax rate. As a result of this tax law change, the Company’s net deferred income tax liability was reduced by
Recently Issued Accounting Standards	(f) Recently Issued Accounting Standards Convertible Debt Instruments In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity Debt with Conversion and Other Options , that required separate accounting for conversion features, and instead, allows the debt instrument and conversion features to be accounted for as a single debt instrument. It is effective for interim and annual reporting periods beginning after December 31, 2021. The Company adopted the standard effective January 1, 2022 Upon adoption of this new standard, the Company reclassified $24 million, net of deferred income taxes and equity issuance costs, from additional paid-in capital and increased long-term debt by $27 million, reduced deferred income tax liability by $6 million and reduced accumulated deficit by $3 million as of January 1, 2022. Additionally, annual interest expense for the 2026 Convertible Notes beginning January 1, 2022 is based on an effective interest rate of Income Taxes In December 2019, the FASB issued ASU No. 2019-12, Simplifying the Accounting for Income Taxes . Income Taxes

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	9 Months Ended
Summary of Significant Accounting Policies (Tables)	Sep. 30, 2022
Summary of Significant Accounting Policies
Reconciliation of earnings (loss) attributable to common stockholders for basic and diluted earnings (loss) per share	The following is a reconciliation of the Company’s earnings (loss) attributable to common stockholders for basic and diluted earnings (loss) per share (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Net income (loss) attributable to Antero Resources Corporation—common shareholders $ (549,318) 559,759 (1,088,284) 1,168,475 Add: Interest expense for 2026 Convertible Notes — 830 — 2,764 Less: Tax-effect of interest expense for 2026 Convertible Notes — (193) — (642) Net income (loss) attributable to Antero Resources Corporation—common shareholders and assumed conversions $ (549,318) 560,396 (1,088,284) 1,170,597 Income (loss) per share—basic $ (1.75) 1.83 (3.55) 3.77 Income (loss) per share—diluted $ (1.75) 1.72 (3.55) 3.51 Weighted average common shares outstanding—basic 313,790 305,343 306,201 309,954 Weighted average common shares outstanding—diluted 313,790 325,997 306,201 333,738
Reconciliation of basic weighted average shares outstanding to diluted weighted average shares outstanding	The following is a reconciliation of the Company’s basic weighted average shares outstanding to diluted weighted average shares outstanding during the periods presented (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Basic weighted average number of shares outstanding 313,790 305,343 306,201 309,954 Add: Dilutive effect of RSUs — 3,041 — 3,444 Add: Dilutive effect of PSUs — 1,486 — 2,462 Add: Dilutive effect of stock options — — — — Add: Dilutive effect of 2026 Convertible Notes — 16,127 — 17,878 Diluted weighted average number of shares outstanding 313,790 325,997 306,201 333,738 Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share (1) RSUs 6,158 — 6,562 — PSUs 2,748 — 2,706 — Stock options 357 349 388 350 2026 Convertible Notes 18,778 — 18,778 — (1) The potential dilutive effects of these awards were excluded from the computation of diluted earnings (loss) per common share because the inclusion of these awards would have been anti-dilutive.

Revenue (Tables)

Revenue (Tables)	9 Months Ended
Revenue (Tables)	Sep. 30, 2022
Revenue
Schedule of disaggregation of revenue	The table set forth below presents revenue disaggregated by type and reportable segment to which it relates (in thousands). See Note 16—Reportable Segments to the unaudited condensed financial statements for more information on reportable segments. Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 Reportable Segment Revenues from contracts with customers: Natural gas sales $ 884,669 1,736,039 2,231,558 4,290,825 Exploration and production Natural gas liquids sales (ethane) 57,919 117,253 137,446 274,546 Exploration and production Natural gas liquids sales (C3+ NGLs) 540,408 503,563 1,365,581 1,708,963 Exploration and production Oil sales 56,734 67,025 153,326 219,504 Exploration and production Marketing 232,685 159,985 562,928 335,173 Marketing Total revenue from contracts with customers 1,772,415 2,583,865 4,450,839 6,829,011 Loss from derivatives, deferred revenue and other sources, net (1,238,532) (519,241) (2,225,678) (1,775,862) Total revenue $ 533,883 2,064,624 2,225,161 5,053,149

Equity Method Investments (Tabl

Equity Method Investments (Tables)	9 Months Ended
Equity Method Investments (Tables)	Sep. 30, 2022
Antero Midstream Corporation
Equity Method Investments
Schedule of reconciliation of investments in unconsolidated affiliates and summarized financial information	The following table sets forth a reconciliation of Antero’s investment in unconsolidated affiliate (in thousands): Balance as of December 31, 2021 (1) $ 232,399 Equity in earnings of unconsolidated affiliate 54,863 Dividends from unconsolidated affiliate (93,854) Elimination of intercompany profit 29,474 Balance as of September 30, 2022 (1) $ 222,882 (1) The fair value of the Company’s investment in Antero Midstream as of December 31, 2021 and September 30, 2022 was $1.3 billion based on the quoted market share price of Antero Midstream. The tables set forth below present summarized financial information of Antero Midstream (in thousands): Balance Sheet (Unaudited) December 31, September 30, 2021 2022 Current assets $ 83,804 80,785 Noncurrent assets 5,460,197 5,483,036 Total assets $ 5,544,001 5,563,821 Current liabilities $ 114,009 106,382 Noncurrent liabilities 3,143,294 3,245,584 Stockholders' equity 2,286,698 2,211,855 Total liabilities and stockholders' equity $ 5,544,001 5,563,821 Statement of Operations Nine Months Ended September 30, 2021 2022 Revenues $ 681,712 678,432 Operating expenses 254,905 283,112 Income from operations 426,807 395,320 Net income $ 252,991 243,449

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
Accrued Liabilities (Tables)	Sep. 30, 2022
Accrued Liabilities
Schedule of accrued liabilities	Accrued liabilities consisted of the following items (in thousands): (Unaudited) December 31, September 30, 2021 2022 Capital expenditures $ 46,983 50,785 Gathering, compression, processing and transportation expenses 164,900 185,383 Marketing expenses 50,589 79,119 Interest expense, net 65,093 13,819 Production and ad valorem taxes 44,298 40,152 General and administrative expense 27,740 25,693 Derivative settlements payable 35,202 84,062 Other 22,439 18,534 Total accrued liabilities $ 457,244 497,547

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
Long-Term Debt (Tables)	Sep. 30, 2022
Long-Term Debt
Schedule of long-term debt	Long-term debt consisted of the following items (in thousands): (Unaudited) December 31, September 30, 2021 2022 Credit Facility (a) $ — 9,000 5.00% senior notes due 2025 (d) 584,635 — 8.375% senior notes due 2026 (e) 325,000 103,892 7.625% senior notes due 2029 (f) 584,000 415,837 5.375% senior notes due 2030 (g) 600,000 600,000 4.25% convertible senior notes due 2026 (h) 81,570 56,932 Total principal 2,175,205 1,185,661 Unamortized discount, net (27,772) — Unamortized debt issuance costs (21,989) (12,833) Long-term debt $ 2,125,444 1,172,828
4.25% convertible senior notes due 2026
Long-Term Debt
Schedule of long-term debt	The 2026 Convertible Notes consist of the following (in thousands): (Unaudited) December 31, September 30, 2021 2022 Liability component: Principal $ 81,570 56,932 Less: unamortized note discount (1) (27,772) — Less: unamortized debt issuance costs (1,592) (1,231) Net carrying value $ 52,206 55,701 Equity component (1) $ 32,799 — (1) As of December 31, 2021, the equity component attributable to the outstanding 2026 Convertible Notes was recorded in additional paid-in capital net of $1 million of issuance costs and $8 million of deferred taxes. Upon adoption of ASU 2020-06 on January 1, 2022, the equity component was reclassified from additional paid-in capital to long-term debt and fully offset the remaining discount on the 2026 Convertible Notes. See Note 2—Summary of Significant Accounting Policies to the unaudited condensed consolidated financial statements.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
Asset Retirement Obligations (Tables)	Sep. 30, 2022
Asset Retirement Obligations
Schedule of reconciliation of asset retirement obligations	The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations—December 31, 2021 $ 53,952 Obligations incurred 2,445 Accretion expense 4,069 Settlement of obligations (946) Obligations on sold properties (42) Revisions to prior estimates (1,467) Asset retirement obligations—September 30, 2022 $ 58,011

Equity-Based Compensation and_2

Equity-Based Compensation and Cash Awards (Tables)	9 Months Ended
Equity-Based Compensation and Cash Awards (Tables)	Sep. 30, 2022
Equity-Based Compensation and Cash Awards
Schedule of equity-based compensation expense	The Company’s equity-based compensation expense, by type of award, is as follows (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2021 2022 2021 2022 RSU awards $ 3,327 4,974 9,957 12,468 PSU awards 1,452 5,070 3,211 9,501 Converted AM RSU Awards (1) 186 8 988 203 Equity awards issued to directors 333 350 1,033 1,050 Total expense $ 5,298 10,402 15,189 23,222 (1) Antero Resources recognized compensation expense for equity awards granted under both the 2013 Plan and the AMP Plan because the awards under the AMP Plan are accounted for as if they are distributed by Antero Midstream Partners to Antero Resources. Antero Resources allocates a portion of equity-based compensation expense related to grants prior to March 12, 2019 (date of deconsolidation) to Antero Midstream Partners based on its proportionate share of Antero Resources’ labor costs.
Summary of RSU award activity	Weighted Average Number of Grant Date Shares Fair Value Total awarded and unvested—December 31, 2021 5,930,607 $ 5.15 Granted 992,843 35.02 Vested (2,564,930) 4.80 Forfeited (158,102) 10.63 Total awarded and unvested—September 30, 2022 4,200,418 $ 12.22
Schedule of weighted average fair value assumptions used for PSUs granted	Dividend yield — % Volatility 88 % Risk-free interest rate 2.65 % Weighted average fair value of awards granted—Absolute TSR $ 47.53
Summary of PSU award activity	Weighted Number of Average Grant Units Date Fair Value Total awarded and unvested—December 31, 2021 1,847,279 $ 8.31 Granted 436,537 29.98 Vested (1,210,712) 9.26 Forfeited — — Cancelled (unearned) — — Total awarded and unvested—September 30, 2022 1,073,104 $ 16.05
Schedule of Converted AM RSU Awards	Weighted Average Number of Grant Date Units Fair Value Total awarded and unvested—December 31, 2021 81,707 $ 13.46 Granted — — Vested (78,880) 13.50 Forfeited — — Total awarded and unvested—September 30, 2022 2,827 $ 12.38
Summary of stock option activity	Weighted Weighted Average Average Remaining Intrinsic Stock Exercise Contractual Value Options Price Life (in thousands) (1) Outstanding—December 31, 2021 351,794 $ 50.79 3.0 $ — Granted — — Exercised — — Forfeited — — Expired (3,417) 50.00 Outstanding—September 30, 2022 348,377 $ 50.80 2.1 $ — Vested—September 30, 2022 348,377 $ 50.80 2.1 $ — Exercisable—September 30, 2022 348,377 $ 50.80 2.1 $ — (1) Intrinsic values are based on the exercise price of the options and the closing price of Antero Resources’ common stock on the referenced dates.

Fair value (Tables)

Fair value (Tables)	9 Months Ended
Fair value (Tables)	Sep. 30, 2022
Fair Value
Schedule of fair value and carrying value of the senior notes and 2026 Convertible Notes	(Unaudited) December 31, 2021 September 30, 2022 Fair Carrying Fair Carrying Value (1) Value (2) Value (1) Value (2) 2025 Notes $ 594,866 581,117 — — 2026 Notes 370,013 321,738 108,692 103,028 2029 Notes 654,080 577,149 415,837 411,363 2030 Notes 641,400 593,234 537,780 593,736 2026 Convertible Notes 331,655 52,206 400,454 55,701 Total $ 2,592,014 2,125,444 1,462,763 1,163,828 (1) Fair values are based on Level 2 market data inputs. (2) Carrying values are presented net of unamortized debt issuance costs and debt discounts or premiums.

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
Derivative Instruments (Tables)	Sep. 30, 2022
Schedule of outstanding commodity derivatives for Antero Resources Corporation	Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas October-December 2022 Henry Hub 1,105,897 MMBtu/day $ 2.48 /MMBtu January-December 2023 Henry Hub 43,000 MMBtu/day 2.37 /MMBtu
Schedule of call option and embedded put option arrangements	Embedded Call Option Put Option Commodity / Settlement Period Index Contracted Volume Strike Price Strike Price Natural Gas October-December 2022 Henry Hub 59,000 MMBtu/day $ 2.545 /MMBtu $ 2.545 /MMBtu January-December 2023 Henry Hub 55,000 MMBtu/day 2.466 /MMBtu 2.466 /MMBtu January-December 2024 Henry Hub 53,000 MMBtu/day 2.477 /MMBtu 2.527 /MMBtu January-December 2025 Henry Hub 44,000 MMBtu/day 2.564 /MMBtu 2.614 /MMBtu January-December 2026 Henry Hub 32,000 MMBtu/day 2.629 /MMBtu 2.679 /MMBtu
Schedule of natural gas basis swap positions which settle on pricing index to basis differential of NYMEX to TCO	Weighted Average Commodity / Settlement Period Index to Basis Differential Contracted Volume Hedged Differential Natural Gas October-December 2022 NYMEX to TCO 60,000 MMBtu/day $ 0.515 /MMBtu January-December 2023 NYMEX to TCO 50,000 MMBtu/day 0.525 /MMBtu January-December 2024 NYMEX to TCO 50,000 MMBtu/day 0.530 /MMBtu
Summary of the fair values of derivative instruments, which are not designated as hedges for accounting purposes	(Unaudited) Balance Sheet December 31, September 30, Location 2021 2022 Asset derivatives not designated as hedges for accounting purposes: Commodity derivatives—current Derivative instruments $ — — Embedded derivatives—current Derivative instruments 757 954 Commodity derivatives—noncurrent Derivative instruments — — Embedded derivatives—noncurrent Derivative instruments 14,369 7,327 Total asset derivatives (1) 15,126 8,281 Liability derivatives not designated as hedges for accounting purposes: Commodity derivatives—current (2) Derivative instruments 559,851 612,237 Commodity derivatives—noncurrent (2) Derivative instruments 181,806 445,481 Total liability derivatives (1) 741,657 1,057,718 Net derivatives liability (1) $ (726,531) (1,049,437) (1) The fair value of derivative instruments was determined using Level 2 inputs. (2) As of December 31, 2021, approximately $55 million of commodity derivative liabilities, including $31 million of current commodity derivatives and $24 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. As of September 30, 2022, approximately $84 million of commodity derivative liabilities, including $53 million of current commodity derivatives and $31 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica.
Schedule of gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts	The following table sets forth the gross values of recognized derivative assets and liabilities, the amounts offset under master netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets as of the dates presented, all at fair value (in thousands): (Unaudited) December 31, 2021 September 30, 2022 Net Amounts of Net Amounts of Gross Gross Assets Gross Gross Assets Amounts Amounts Offset (Liabilities) on Amounts Amounts Offset (Liabilities) on Recognized Recognized Balance Sheet Recognized Recognized Balance Sheet Commodity derivative assets $ 2,177 (2,177) — 516 (516) — Embedded derivative assets 15,126 — 15,126 8,281 — 8,281 Commodity derivative liabilities (743,834) 2,177 (741,657) (1,058,234) 516 (1,057,718)
Summary of derivative fair value gains (losses)	The following table sets forth a summary of derivative fair value gains and losses and where such values are recorded in the unaudited condensed consolidated statements of operations (in thousands): Statement of Operations Three Months Ended September 30, Nine Months Ended September 30, Location 2021 2022 2021 2022 Commodity derivative fair value losses (1) Revenue $ (1,238,384) (500,557) (2,228,076) (1,732,720) Embedded derivative fair value losses (1) Revenue (12,082) (29,966) (31,986) (74,845) (1) The fair value of derivative instruments was determined using Level 2 inputs .
VIE, Martica
Schedule of outstanding commodity derivatives	Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas October-December 2022 Henry Hub 40,592 MMBtu/day $ 2.39 /MMBtu January-December 2023 Henry Hub 35,616 MMBtu/day 2.35 /MMBtu January-December 2024 Henry Hub 23,885 MMBtu/day 2.33 /MMBtu January-March 2025 Henry Hub 18,021 MMBtu/day 2.53 /MMBtu Propane October-December 2022 Mont Belvieu Propane-OPIS Non-TET 952 Bbl/day 19.32 /Bbl Natural Gasoline October-December 2022 Mont Belvieu Natural Gasoline-OPIS Non-TET 288 Bbl/day 34.86 /Bbl January-December 2023 Mont Belvieu Natural Gasoline-OPIS Non-TET 247 Bbl/day 40.74 /Bbl Oil October-December 2022 West Texas Intermediate 105 Bbl/day 43.50 /Bbl January-December 2023 West Texas Intermediate 99 Bbl/day 44.88 /Bbl January-December 2024 West Texas Intermediate 43 Bbl/day 44.02 /Bbl January-March 2025 West Texas Intermediate 39 Bbl/day 45.06 /Bbl

Leases (Tables)

Leases (Tables)	9 Months Ended
Leases (Tables)	Sep. 30, 2022
Leases
Summary of supplemental balance sheet information related to leases	The Company’s lease assets and liabilities consisted of the following items (in thousands): (Unaudited) December 31, September 30, Leases Balance Sheet Classification 2021 2022 Operating Leases Operating lease right-of-use assets: Processing plants Operating lease right-of-use assets $ 1,739,550 1,906,419 Drilling rigs and completion services Operating lease right-of-use assets 9,860 64,022 Gas gathering lines and compressor stations (1) Operating lease right-of-use assets 1,634,928 1,523,233 Office space Operating lease right-of-use assets 33,083 42,760 Vehicles Operating lease right-of-use assets 2,009 1,074 Other office and field equipment Operating lease right-of-use assets 482 4,068 Total operating lease right-of-use assets $ 3,419,912 3,541,576 Short-term operating lease obligation Short-term lease liabilities $ 455,950 535,014 Long-term operating lease obligation Long-term lease liabilities 2,963,962 3,006,562 Total operating lease obligation $ 3,419,912 3,541,576 Finance Leases Finance lease right-of-use assets: Vehicles Other property and equipment $ 550 1,407 Total finance lease right-of-use assets (2) $ 550 1,407 Short-term finance lease obligation Short-term lease liabilities $ 397 333 Long-term finance lease obligation Long-term lease liabilities 153 1,074 Total finance lease obligation $ 550 1,407 (1) Gas gathering lines and compressor station leases includes $1.5 billion related to Antero Midstream as of December 31, 2021 and September 30, 2022. See “—Related party lease disclosure” for additional discussion. (2) Financing lease assets are recorded net of accumulated amortization of $2 million and $1 million as of December 31, 2021 and September 30, 2022, respectively.
Summary of costs associated with operating leases and finance leases	Costs associated with operating and finance leases were included in the unaudited condensed consolidated statement of operations and comprehensive loss (in thousands): Three Months Ended September 30, Nine Months Ended September 30, Cost Classification Location 2021 2022 2021 2022 Operating lease cost Statement of operations Gathering, compression, processing and transportation $ 386,033 378,246 1,147,985 1,109,422 Operating lease cost Statement of operations General and administrative 2,833 2,855 8,057 8,509 Operating lease cost Statement of operations Contract termination 3,369 12,000 4,213 12,000 Operating lease cost Statement of operations Lease operating 43 44 109 133 Operating lease cost Balance sheet Proved properties (1) 25,558 34,288 82,749 83,146 Total operating lease cost $ 417,836 427,433 1,243,113 1,213,210 Finance lease cost: Amortization of right-of-use assets Statement of operations Depletion, depreciation and amortization $ 132 94 391 319 Interest on lease liabilities Statement of operations Interest expense 286 44 337 78 Total finance lease cost $ 418 138 728 397 Short-term lease payments $ 21,030 38,690 62,328 115,798 (1) Capitalized costs related to drilling and completion activities.
Summary of supplemental cash flow information related to leases	The following table presents the Company’s supplemental cash flow information related to leases (in thousands): Nine Months Ended September 30, 2021 2022 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 1,042,684 1,067,786 Investing cash flows from operating leases 66,042 70,654 Financing cash flows from finance leases 692 441 Noncash activities: Right-of-use assets obtained in exchange for new operating lease obligations 232,771 366,194 Increase to existing right-of-use assets and lease obligations from operating lease modifications, net (1) 345,066 119,290 (1) During the nine months ended September 30, 2021, the weighted average discount rate for remeasured operating leases decreased from 14.4% as of December 31, 2020 to 5.5% as of September 30, 2021. During the nine months ended September 30, 2022, the weighted average discount rate for remeasured operating leases decreased from 5.6% as of December 31, 2021 to 5.2% as of September 30, 2022.
Summary of maturities of operating lease liabilities	The table below is a schedule of future minimum payments for operating and financing lease liabilities as of September 30, 2022 (in thousands): Operating Leases Financing Leases Total Remainder of 2022 $ 178,967 145 179,112 2023 706,880 510 707,390 2024 645,692 501 646,193 2025 585,209 459 585,668 2026 534,508 210 534,718 2027 442,252 — 442,252 Thereafter 1,203,662 — 1,203,662 Total lease payments 4,297,170 1,825 4,298,995 Less: imputed interest (755,594) (418) (756,012) Total $ 3,541,576 1,407 3,542,983
Summary of maturities of financing lease liabilities	The table below is a schedule of future minimum payments for operating and financing lease liabilities as of September 30, 2022 (in thousands): Operating Leases Financing Leases Total Remainder of 2022 $ 178,967 145 179,112 2023 706,880 510 707,390 2024 645,692 501 646,193 2025 585,209 459 585,668 2026 534,508 210 534,718 2027 442,252 — 442,252 Thereafter 1,203,662 — 1,203,662 Total lease payments 4,297,170 1,825 4,298,995 Less: imputed interest (755,594) (418) (756,012) Total $ 3,541,576 1,407 3,542,983
Summary of weighted-average remaining lease term and discount rate	(Unaudited) December 31, 2021 September 30, 2022 Operating Leases Finance Leases Operating Leases Finance Leases Weighted average remaining lease term 7.6 years 1.9 years 7.4 years 3.5 years Weighted average discount rate 5.5 % 5.6 % 5.3 % 6.8 %

Commitments (Tables)

Commitments (Tables)	9 Months Ended
Commitments (Tables)	Sep. 30, 2022
Commitments
Schedule of future minimum payments for firm transportation, drilling rig and completion services, processing, gathering and compression, and office and equipment agreements, which include leases that have remaining lease terms in excess of one year	The following table sets forth a schedule of future minimum payments for firm transportation, drilling rig and completion services, processing, gathering and compression, and office and equipment agreements, which include leases that have a lease term in excess of one year as of September 30, 2022 (in thousands): Processing, Gathering, Compression Firm and Water Land Payment Operating and Imputed Interest Transportation Service Obligations Financing Leases for Leases (a) (b) (c) (d) (d) Total Remainder of 2022 $ 282,279 14,932 41 132,838 46,274 476,364 2023 1,157,330 71,650 — 538,749 168,641 1,936,370 2024 1,130,195 62,693 — 505,219 140,974 1,839,081 2025 1,107,995 51,391 — 471,022 114,646 1,745,054 2026 1,102,362 18,214 — 444,514 90,204 1,655,294 2027 1,098,497 16,927 — 374,087 68,165 1,557,676 Thereafter 5,860,221 84,876 — 1,076,554 127,108 7,148,759 Total $ 11,738,879 320,683 41 3,542,983 756,012 16,358,598

Reportable Segments (Tables)

Reportable Segments (Tables)	9 Months Ended
Reportable Segments (Tables)	Sep. 30, 2022
Reportable Segments
Schedule of operating results and assets of reportable segments	The summarized operating results of the Company’s reportable segments are as follows (in thousands): Three Months Ended September 30, 2021 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 300,668 232,685 245 (245) 533,353 Intersegment 530 — 224,559 (224,559) 530 Total revenue 301,198 232,685 224,804 (224,804) 533,883 Operating expenses: Lease operating 25,363 — — — 25,363 Gathering, compression, processing, transportation and water handling 628,225 — 39,499 (39,499) 628,225 General and administrative 32,442 — 14,810 (14,810) 32,442 Depletion, depreciation and amortization 182,810 — 27,487 (27,487) 182,810 Impairment of oil and gas properties 26,253 — — — 26,253 Other 56,113 266,751 1,187 (1,187) 322,864 Total operating expenses 951,206 266,751 82,983 (82,983) 1,217,957 Operating income (loss) $ (650,008) (34,066) 141,821 (141,821) (684,074) Equity in earnings of unconsolidated affiliates $ 21,450 — 24,088 (24,088) 21,450 Capital expenditures for segment assets $ 387,783 — 82,583 (82,583) 387,783 Three Months Ended September 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 1,904,302 159,985 1,651 (1,651) 2,064,287 Intersegment 337 — 229,383 (229,383) 337 Total revenue 1,904,639 159,985 231,034 (231,034) 2,064,624 Operating expenses: Lease operating 27,453 — — — 27,453 Gathering, compression, processing, transportation and water handling 716,388 — 46,648 (46,648) 716,388 General and administrative 42,903 — 13,587 (13,587) 42,903 Depletion, depreciation and amortization 169,607 — 34,206 (34,206) 169,607 Impairment of oil and gas properties 33,924 — — — 33,924 Other 114,812 185,377 (1,177) 1,177 300,189 Total operating expenses 1,105,087 185,377 93,264 (93,264) 1,290,464 Operating income (loss) $ 799,552 (25,392) 137,770 (137,770) 774,160 Equity in earnings of unconsolidated affiliates $ 14,972 — 24,411 (24,411) 14,972 Capital expenditures for segment assets $ 244,680 — 74,120 (74,120) 244,680 Nine Months Ended September 30, 2021 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 1,661,682 562,928 340 (340) 2,224,610 Intersegment 551 — 681,372 (681,372) 551 Total revenue 1,662,233 562,928 681,712 (681,712) 2,225,161 Operating expenses: Lease operating 71,555 — — — 71,555 Gathering, compression, processing, transportation and water handling 1,874,664 — 118,368 (118,368) 1,874,664 General and administrative 108,693 — 46,991 (46,991) 108,693 Depletion, depreciation and amortization 564,166 — 80,956 (80,956) 564,166 Impairment of oil and gas properties 69,618 — — — 69,618 Other 141,127 627,822 8,590 (8,590) 768,949 Total operating expenses 2,829,823 627,822 254,905 (254,905) 3,457,645 Operating income (loss) $ (1,167,590) (64,894) 426,807 (426,807) (1,232,484) Equity in earnings of unconsolidated affiliates $ 57,621 — 66,347 (66,347) 57,621 Capital expenditures for segment assets $ 510,941 — 156,948 (156,948) 510,941 Nine Months Ended September 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Sales and revenues: Third-party $ 4,716,827 335,173 2,288 (2,288) 5,052,000 Intersegment 1,149 — 676,144 (676,144) 1,149 Total revenue 4,717,976 335,173 678,432 (678,432) 5,053,149 Operating expenses: Lease operating 70,486 — — — 70,486 Gathering, compression, processing, transportation and water handling 1,962,878 — 131,959 (131,959) 1,962,878 General and administrative 123,033 — 47,597 (47,597) 123,033 Depletion, depreciation and amortization 511,390 — 98,181 (98,181) 511,390 Impairment of oil and gas properties 79,749 — — — 79,749 Other 258,963 415,571 5,375 (5,375) 674,534 Total operating expenses 3,006,499 415,571 283,112 (283,112) 3,422,070 Operating income (loss) $ 1,711,477 (80,398) 395,320 (395,320) 1,631,079 Equity in earnings of unconsolidated affiliates $ 54,863 — 70,467 (70,467) 54,863 Capital expenditures for segment assets $ 721,420 — 236,154 (236,154) 721,420 The summarized assets of the Company’s reportable segments are as follows (in thousands): As of December 31, 2021 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Investments in unconsolidated affiliates $ 232,399 — 696,009 (696,009) 232,399 Total assets 13,864,402 32,126 5,544,001 (5,544,001) 13,896,528 (Unaudited) As of September 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliates Total Investments in unconsolidated affiliates $ 222,882 — 659,006 (659,006) 222,882 Total assets 14,350,938 62,440 5,563,821 (5,563,821) 14,413,378

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	9 Months Ended
Subsidiary Guarantors (Tables)	Sep. 30, 2022
Subsidiary Guarantors
Schedule of summarized financial information of Antero and its guarantor subsidiaries	The tables set forth below present summarized financial information of Antero, as parent, and its guarantor subsidiaries (in thousands). The Company’s wholly owned subsidiaries are not restricted from making distributions to the Company. Balance Sheet (Unaudited) December 31, 2021 September 30, 2022 Accounts receivable, non-guarantor subsidiaries $ — — Accounts receivable, related parties — — Other current assets 633,014 908,074 Total current assets 633,014 908,074 Noncurrent assets 12,480,350 12,753,226 Total assets $ 13,113,364 13,661,300 Accounts payable, non-guarantor subsidiaries $ — — Accounts payable, related parties 76,240 74,584 Other current liabilities 1,961,041 2,421,768 Total current liabilities 2,037,281 2,496,352 Noncurrent liabilities 5,737,999 5,368,027 Total liabilities $ 7,775,280 7,864,379 Statement of Operations Nine Months Ended September 30, 2022 Revenues $ 4,955,613 Operating expenses 3,387,903 Income from operations 1,567,710 Net income and comprehensive income including noncontrolling interests 1,168,475 Net income and comprehensive income attributable to Antero Resources Corporation $ 1,168,475

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Accounts Payable
Basis of Presentation
Book overdrafts	$ 61	$ 5
Revenue distributions payable
Basis of Presentation
Book overdrafts	$ 159	$ 52

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Reconciliation of Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Summary of Significant Accounting Policies
Net income (loss) attributable to Antero Resources Corporation-common shareholders	$ 559,759	$ (549,318)	$ 1,168,475	$ (1,088,284)
Add: Interest expense for 2026 Convertible Notes	830		2,764
Less: Tax-effect of interest expense for 2026 Convertible Notes	(193)		(642)
Net income (loss) attributable to Antero Resources Corporation-common shareholders and assumed conversions	$ 560,396	$ (549,318)	$ 1,170,597	$ (1,088,284)
Income (loss) per share-basic (in dollars per share)	$ 1.83	$ (1.75)	$ 3.77	$ (3.55)
Income (loss) per share-diluted (in dollars per share)	$ 1.72	$ (1.75)	$ 3.51	$ (3.55)
Weighted average common shares outstanding-basic (in shares)	305,343	313,790	309,954	306,201
Weighted average common shares outstanding-diluted (in shares)	325,997	313,790	333,738	306,201

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Reconciliation of Weighted Average Shares Outstanding (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Earnings per share and New Accounting Principle
Basic weighted average number of shares outstanding	305,343	313,790	309,954	306,201
Diluted weighted average number of shares outstanding	325,997	313,790	333,738	306,201
RSUs
Earnings per share and New Accounting Principle
Add: Dilutive effect	3,041		3,444
Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share		6,158		6,562
PSUs
Earnings per share and New Accounting Principle
Add: Dilutive effect	1,486		2,462
Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share		2,748		2,706
Stock options
Earnings per share and New Accounting Principle
Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share	349	357	350	388
4.25% convertible senior notes due 2026
Earnings per share and New Accounting Principle
Add: Dilutive effect	16,127		17,878
Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share		18,778		18,778

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Income Taxes (Details) $ in Millions	3 Months Ended
	Sep. 30, 2022 USD ($)
Summary of Significant Accounting Policies
Reduction of net deferred income tax liability	$ 21

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Recently Issued Accounting Standards (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Jan. 01, 2022	Dec. 31, 2021	Sep. 30, 2021	Aug. 21, 2020
Recently Issued Accounting Standards
Additional paid-in capital	$ 5,941,977		$ 6,371,398
Long-term debt	1,172,828		2,125,444
Deferred income tax liability, net	619,342		318,126
Retained earnings (accumulated deficit)	266,468		(617,377)
4.25% convertible senior notes due 2026
Recently Issued Accounting Standards
Long-term debt	$ 55,701		$ 52,206
Effective interest rate (as a percent)				15.10%	15.10%
Accounting Standards Update 2020-06 \| Adjustment Effect
Recently Issued Accounting Standards
Additional paid-in capital		$ (24,000)
Long-term debt		27,000
Deferred income tax liability, net		(6,000)
Retained earnings (accumulated deficit)		$ 3,000
Accounting Standards Update 2020-06 \| Adjustment Effect \| 4.25% convertible senior notes due 2026
Recently Issued Accounting Standards
Effective interest rate (as a percent)		4.90%

Transactions (Details)

Transactions (Details) - USD ($) $ in Thousands		3 Months Ended				9 Months Ended
Transactions (Details) - USD ($) $ in Thousands	Jun. 15, 2020	Sep. 30, 2022	Sep. 30, 2021	Jun. 30, 2021	Dec. 31, 2020	Sep. 30, 2022	Sep. 30, 2021	Feb. 17, 2021
Transactions
Cash contribution							$ 51,000
ORRI \| Sixth Street
Transactions
Cash contribution	$ 300,000
Additional contribution upon achievement of production target	$ 102,000
Cash distributions received				$ 51,000	$ 51,000
Drilling Partnership \| QL
Transactions
Percent of total development capital spending in current year funded by drilling partner								20%
Percent of total development capital spending in the next year to be funded by drilling partner								15%
Gain (loss) on interests conveyed		$ 0	$ 0			$ 0	$ 0
Drilling Partnership \| QL \| Minimum
Transactions
Percent of total development capital spending in years 2-3 to be funded by drilling partner								15%
Drilling Partnership \| QL \| Maximum
Transactions
Percent of total development capital spending in years 2-3 to be funded by drilling partner								20%

Revenue (Details)

Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Revenue (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue
Revenue	$ 2,583,865	$ 1,772,415	$ 6,829,011	$ 4,450,839
Income (loss) from derivatives, deferred revenue and other sources	(519,241)	(1,238,532)	(1,775,862)	(2,225,678)
Total revenue	2,064,624	533,883	5,053,149	2,225,161
Natural gas sales
Disaggregation of Revenue
Revenue	1,736,039	884,669	4,290,825	2,231,558
Oil sales
Disaggregation of Revenue
Revenue	67,025	56,734	219,504	153,326
Marketing
Disaggregation of Revenue
Revenue	159,985	232,685	335,173	562,928
Exploration and production \| Natural gas sales
Disaggregation of Revenue
Revenue	1,736,039	884,669	4,290,825	2,231,558
Exploration and production \| Natural gas liquids sales (ethane)
Disaggregation of Revenue
Revenue	117,253	57,919	274,546	137,446
Exploration and production \| Natural gas liquids sales (C3+ NGLs)
Disaggregation of Revenue
Revenue	503,563	540,408	1,708,963	1,365,581
Exploration and production \| Oil sales
Disaggregation of Revenue
Revenue	67,025	56,734	219,504	153,326
Marketing \| Marketing
Disaggregation of Revenue
Revenue	$ 159,985	$ 232,685	$ 335,173	$ 562,928

Revenue - Transaction Price All

Revenue - Transaction Price Allocation and Contract Balances (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Revenue
Original expected duration	true
Receivables from contracts with customers	$ 924,343	$ 591,442

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Investments in unconsolidated affiliates
Equity in earnings of unconsolidated affiliates	$ 14,972			$ 21,450			$ 54,863	$ 57,621
Dividends from unconsolidated affiliate							(93,854)	(105,325)
Summarized Financial Information
Current assets	977,654						977,654		$ 686,119
Total assets	14,413,378						14,413,378		13,896,528
Current liabilities	2,544,022						2,544,022		2,068,117
Total equity	6,470,262	$ 6,273,863	$ 5,728,684	5,135,242	$ 5,718,414	$ 6,227,949	6,470,262	5,135,242	6,066,092	$ 6,090,271
Total liabilities and equity	14,413,378						14,413,378		13,896,528
Revenues	2,064,624			533,883			5,053,149	2,225,161
Operating expenses	1,290,464			1,217,957			3,422,070	3,457,645
Income from operations	774,160			(684,074)			1,631,079	(1,232,484)
Net income	$ 594,507	$ 812,033	(174,696)	$ (566,575)	$ (534,451)	$ (11,104)	$ 1,231,844	(1,112,130)
Antero Midstream Corporation
Equity Method Investments
Ownership percentage	29.10%						29.10%
Investments in unconsolidated affiliates
Balance at beginning of period			$ 232,399				$ 232,399
Equity in earnings of unconsolidated affiliates							54,863
Dividends from unconsolidated affiliate							(93,854)
Elimination of intercompany profit							29,474
Balance at end of period	$ 222,882						222,882
Fair value of investment	1,300,000						1,300,000		1,300,000
Antero Midstream Corporation
Summarized Financial Information
Current assets	80,785						80,785		83,804
Noncurrent assets	5,483,036						5,483,036		5,460,197
Total assets	5,563,821						5,563,821		5,544,001
Current liabilities	106,382						106,382		114,009
Noncurrent liabilities	3,245,584						3,245,584		3,143,294
Total equity	2,211,855						2,211,855		2,286,698
Total liabilities and equity	$ 5,563,821						5,563,821		$ 5,544,001
Revenues							678,432	681,712
Operating expenses							283,112	254,905
Income from operations							395,320	426,807
Net income							$ 243,449	$ 252,991

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Accrued Liabilities
Capital expenditures	$ 50,785	$ 46,983
Gathering, compression, processing, and transportation expenses	185,383	164,900
Marketing expenses	79,119	50,589
Interest expense, net	13,819	65,093
Production and ad valorem taxes	40,152	44,298
General and administrative expense	25,693	27,740
Derivative settlements payable	84,062	35,202
Other	18,534	22,439
Total accrued liabilities	$ 497,547	$ 457,244

Long-Term Debt (Details)

Long-Term Debt (Details) $ / shares in Units, $ in Thousands, shares in Millions								3 Months Ended						9 Months Ended		12 Months Ended
	Jul. 01, 2022 shares	Jun. 01, 2021 USD ($)	May 13, 2021 USD ($) $ / shares shares	Jan. 26, 2021 USD ($)	Jan. 12, 2021 USD ($) $ / shares shares	Jan. 04, 2021 USD ($)	Aug. 21, 2020 USD ($) D	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2021 USD ($)	Jun. 30, 2021 USD ($)	Mar. 31, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)	Oct. 18, 2021 USD ($)	Jul. 01, 2021 USD ($)	Sep. 02, 2020 USD ($)	Dec. 21, 2016 USD ($)	Mar. 17, 2015 USD ($)	Sep. 18, 2014 USD ($)	May 06, 2014 USD ($)
Long-Term Debt
Total principal								$ 1,185,661						$ 1,185,661		$ 2,175,205
Unamortized discount, net																(27,772)
Unamortized debt issuance costs								(12,833)						(12,833)		(21,989)
Long-term debt								1,172,828						1,172,828		2,125,444
Payments of deferred financing costs														814	$ 22,814
Loss on convertible note equitizations								169						169	50,777
Gain (loss) on extinguishment of debt repurchased								(30,307)			$ (16,567)			(45,375)	(82,836)
Credit Facility
Long-Term Debt
Credit facility								9,000						9,000		0
Current borrowing base								3,500,000						3,500,000		3,500,000
Lender commitments								1,500,000						$ 1,500,000		1,500,000
Debt maturity threshold date														180 days
Available borrowing capacity								986,000						$ 986,000
Outstanding letters of credit								$ 505,000						$ 505,000		531,000
Weighted average interest rate (as a percent)								5.20%						5.20%
Credit Facility \| Minimum
Long-Term Debt
Commitment fees on the unused portion during any period that is not an Investment Grade Period (as a percent)														0.375%
Credit Facility \| Maximum
Long-Term Debt
Commitment fees on the unused portion during any period that is not an Investment Grade Period (as a percent)														0.50%
5.125 senior notes due 2022
Long-Term Debt
Total principal																						$ 500,000	$ 600,000
Interest rate (as a percent)																						5.125%	5.125%
Issue price as percentage of par value																						100.50%	100%
5.125 senior notes due 2022 \| Debt Repurchase Program
Long-Term Debt
Amount of debt repurchased													$ 661,000
5.625% senior notes due 2023
Long-Term Debt
Total principal																					$ 750,000
Interest rate (as a percent)																					5.625%
Issue price as percentage of par value																					100%
Amount of debt repurchased												$ 574,000
5.00% senior notes due 2025
Long-Term Debt
Senior notes																$ 584,635				$ 600,000
Interest rate (as a percent)																5%				5%
Issue price as percentage of par value																				100%
5.00% senior notes due 2025 \| Debt Repurchase Program
Long-Term Debt
Amount of debt repurchased										$ 585,000
Gain (loss) on extinguishment of debt repurchased										$ (11,000)
Percentage of redeemed amount										101.25%
8.375% Senior Notes Due 2026 and 7.625% Senior Notes Due 2029
Long-Term Debt
Gain (loss) on extinguishment of debt repurchased								$ (30,000)	$ (4,000)					$ 45,000
Weighted average percentage premium on repurchases of debt									106%
8.375% Senior Notes Due 2026
Long-Term Debt
Senior notes						$ 500,000		$ 103,892						$ 103,892		$ 325,000
Interest rate (as a percent)						8.375%		8.375%						8.375%		8.375%
Issue price as percentage of par value						100%
Redemption price								109%
Redemption price of the debt instrument in the event of change of control (as a percent)						101%
Amount of debt repurchased								$ 221,000	$ 13,000					$ 221,000
Carrying value of debt repurchased								208,000						208,000
8.375% Senior Notes Due 2026 \| Debt Repurchase Program
Long-Term Debt
Redemption amount																		$ 175,000
8.375% Senior Notes Due 2026 \| On or after January 15, 2024
Long-Term Debt
Redemption price						104.188%
8.375% Senior Notes Due 2026 \| On or after January 15, 2026
Long-Term Debt
Redemption price						100%
8.375% Senior Notes Due 2026 \| Prior to January 15, 2024
Long-Term Debt
Redemption price						100%
7.625% Senior Notes Due 2029
Long-Term Debt
Senior notes				$ 700,000				$ 415,837						$ 415,837		$ 584,000
Interest rate (as a percent)				7.625%				7.625%						7.625%		7.625%
Issue price as percentage of par value				100%
Redemption amount																$ 116,000
Redemption price								107%
Redemption price of the debt instrument in the event of change of control (as a percent)				101%
Amount of debt repurchased								$ 168,000	$ 50,000					$ 168,000			$ 116,000
Carrying value of debt repurchased								118,000						118,000
7.625% Senior Notes Due 2029 \| On or after February 1, 2024
Long-Term Debt
Redemption price				103.813%
7.625% Senior Notes Due 2029 \| On or after February 1, 2027
Long-Term Debt
Redemption price				100%
7.625% Senior Notes Due 2029 \| On or before February 1, 2024
Long-Term Debt
Redemption price of the debt instrument if redeemed with the proceeds of certain equity offerings (as a percent)				107.625%
Percentage of the principal amount of the debt instrument which the entity may redeem with the proceeds from certain equity offerings				35%
7.625% Senior Notes Due 2029 \| Prior to February 1, 2024
Long-Term Debt
Redemption price				100%
5.375% senior notes due 2030
Long-Term Debt
Senior notes		$ 600,000						$ 600,000						$ 600,000		$ 600,000
Interest rate (as a percent)		5.375%						5.375%						5.375%		5.375%
Issue price as percentage of par value		100%
Redemption price of the debt instrument in the event of change of control (as a percent)		101%
5.375% senior notes due 2030 \| On or after March 1, 2025
Long-Term Debt
Redemption price		102.688%
5.375% senior notes due 2030 \| On or after March 1, 2028
Long-Term Debt
Redemption price		100%
5.375% senior notes due 2030 \| On or Before March 1, 2025
Long-Term Debt
Redemption price of the debt instrument if redeemed with the proceeds of certain equity offerings (as a percent)		105.375%
Percentage of the principal amount of the debt instrument which the entity may redeem with the proceeds from certain equity offerings		35%
5.375% senior notes due 2030 \| Prior to March 1, 2025
Long-Term Debt
Redemption price		100%
4.25% convertible senior notes due 2026
Long-Term Debt
Convertible senior notes							$ 250,000	$ 56,932						$ 56,932		$ 81,570			$ 37,500
Unamortized discount, net							$ (116,000)									(27,772)
Unamortized debt issuance costs								(1,231)						(1,231)		(1,592)
Long-term debt								$ 55,701						$ 55,701		52,206
Equity component																$ 32,799
Interest rate (as a percent)							4.25%	4.25%						4.25%		4.25%
Redemption price											108.375%
Amount of debt repurchased											$ 175,000				$ 175,000
Amount of debt converted								$ 5,000						$ 20,000		$ 206,000
Shares issued on conversion \| shares	6
Issuance of convertible notes							$ 278,500
Payments of deferred financing costs							$ 9,000
Conversion rate							230.2026
If-converted value								400,000						400,000
If-converted value above principal amount								343,000						343,000
Cash paid on settlement of debt														200
Effective interest rate (as a percent)							15.10%				15.10%				15.10%
Gain (loss) on extinguishment of debt repurchased											$ (17,000)
Debt issuance cost																1,000
Deferred taxes																$ 8,000
Interest expense								$ 1,000			$ 2,000			$ 3,000	$ 9,000
4.25% convertible senior notes due 2026 \| January Share Offering
Long-Term Debt
Amount of debt converted					$ 150,000
Conversion rate					275.3525
Number of shares of common stock issued (in shares) \| shares					31.4
Share price \| $ / shares					$ 6.35
Line of credit proceeds used to repurchase convertible notes					$ 63,000
Loss on convertible note equitizations													39,000
Gain (loss) on extinguishment of debt repurchased													$ (41,000)
4.25% convertible senior notes due 2026 \| May Share Offering
Long-Term Debt
Amount of debt converted			$ 56,000
Conversion rate			245.2802
Number of shares of common stock issued (in shares) \| shares			11.6
Share price \| $ / shares			$ 11.01
Line of credit proceeds used to repurchase convertible notes			$ 26,000
Loss on convertible note equitizations												12,000
Gain (loss) on extinguishment of debt repurchased												$ (21,000)
4.25% convertible senior notes due 2026 \| Convertible debt threshold minimum percentage
Long-Term Debt
Stock price trigger							98%
Trading days \| D							5
Consecutive trading days \| D							10
4.25% convertible senior notes due 2026 \| Convertible debt threshold maximum percentage
Long-Term Debt
Stock price trigger							130%
Trading days \| D							20
Consecutive trading days \| D							30
4.25% convertible senior notes due 2026 \| Fair value
Long-Term Debt
Fair value							$ 172,000

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Thousands	9 Months Ended
Asset Retirement Obligations (Details) $ in Thousands	Sep. 30, 2022 USD ($)
Asset Retirement Obligations
Asset retirement obligations - beginning of period	$ 53,952
Obligations incurred	2,445
Accretion expense	4,069
Settlement of obligations	(946)
Obligations on sold properties	(42)
Revisions to prior estimates	(1,467)
Asset retirement obligations - end of period	$ 58,011

Equity-Based Compensation and_3

Equity-Based Compensation and Cash Awards (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
	Mar. 12, 2019	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Jun. 17, 2020	Mar. 11, 2019
Stock-based compensation expense
Equity based compensation expense recognized		$ 10,402	$ 5,298	$ 23,222	$ 15,189
2020 Plan
Stock-based compensation expense
Number of stock-based compensation awards authorized						10,050,000
Number of shares available for future grant under the Plan		8,406,240		8,406,240
AMP Plan
Stock-based compensation expense
Number of stock-based compensation awards authorized							10,000,000
AMC Plan \| Common Stock
Stock-based compensation expense
Conversion rate	1
AMC Plan RSUs
Stock-based compensation expense
Conversion rate	1.8926
RSUs
Stock-based compensation expense
Equity based compensation expense recognized		$ 4,974	3,327	$ 12,468	9,957
PSUs
Stock-based compensation expense
Equity based compensation expense recognized		5,070	1,452	9,501	3,211
Converted AM RSU Awards
Stock-based compensation expense
Equity based compensation expense recognized		8	186	203	988
Equity awards issued to directors
Stock-based compensation expense
Equity based compensation expense recognized		$ 350	$ 333	$ 1,050	$ 1,033

Equity-Based Compensation and_4

Equity-Based Compensation and Cash Awards - Restricted Stock and RSU Awards (Details) - RSUs $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) $ / shares shares
Number of shares
Total awarded and unvested at the beginning of the period (in shares) \| shares	5,930,607
Granted (in shares) \| shares	992,843
Vested (in shares) \| shares	(2,564,930)
Forfeited (in shares) \| shares	(158,102)
Total awarded and unvested at the end of the period (in shares) \| shares	4,200,418
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share) \| $ / shares	$ 5.15
Granted (in dollars per share) \| $ / shares	35.02
Vested (in dollars per share) \| $ / shares	4.80
Forfeited (in dollars per share) \| $ / shares	10.63
Total awarded and unvested at the end of the period (in dollars per share) \| $ / shares	$ 12.22
Unamortized equity-based compensation expense \| $	$ 41
Weighted average period for recognizing unrecognized stock-based compensation expense	2 years 4 months 24 days

Equity-Based Compensation and_5

Equity-Based Compensation and Cash Awards - Stock Options (Details) - Stock options - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Stock options
Outstanding at the beginning of the period (in shares)	351,794
Options expired (in shares)	(3,417)
Outstanding at the end of the period (in shares)	348,377	351,794
Vested (in shares)	348,377
Exercisable (in shares)	348,377
Weighted average exercise price
Outstanding at the beginning of the period (in dollars per share)	$ 50.79
Options expired (in dollars per share)	50
Outstanding at the end of the period (in dollars per share)	50.80	$ 50.79
Vested (in dollars per share)	50.80
Exercisable (in dollars per share)	$ 50.80
Weighted average remaining contractual life
Outstanding	2 years 1 month 6 days	3 years
Vested	2 years 1 month 6 days
Exercisable	2 years 1 month 6 days
Additional disclosures
Unamortized equity based compensation expense	$ 0

Equity-Based Compensation and_6

Equity-Based Compensation and Cash Awards - PSU awards (Details) $ / shares in Units, $ in Millions	1 Months Ended			3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 30, 2022 period	Jul. 31, 2020 USD ($)	Jan. 31, 2020 USD ($) tranche	Jun. 30, 2022	Sep. 30, 2022 USD ($) $ / shares shares	Dec. 31, 2019	Dec. 31, 2021 USD ($)
Cash Awards
Unvested cash awards recorded in other liabilities \| $					$ 1		$ 2
2013 Plan
Cash Awards
Cash awards granted \| $			$ 3
Number of tranches related to cash awards \| tranche			3
2020 Plan
Cash Awards
Cash awards granted \| $		$ 3
Vesting period for cash awards		4 years
PSUs
Number of units
Total awarded and unvested at the beginning of the period (in shares) \| shares					1,847,279
Granted (in shares) \| shares					436,537
Vested (in shares) \| shares					(1,210,712)
Total awarded and unvested at the end of the period (in shares) \| shares					1,073,104
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share)					$ 8.31
Granted (in dollars per share)					29.98
Vested (in dollars per share)					9.26
Total awarded and unvested at the end of the period (in dollars per share)					$ 16.05
Additional disclosures
Unamortized equity-based compensation expense \| $					$ 15
Weighted average period for recognizing unrecognized stock-based compensation expense					1 year 7 months 6 days
PSU Awards Based on Absolute TSR \| One Year Period
Stock-based compensation
Service period	1 year
Number of performance periods \| period	3
PSU Awards Based on Absolute TSR \| Three Year Period
Stock-based compensation
Service period	3 years					3 years
Vesting percentage achieved				200%
Number of cumulative performance periods \| period	1
PSU Awards Based on Absolute TSR \| Three Year Period \| Minimum
Stock-based compensation
Number of PSUs that may vest, as a percent	0%					0%
PSU Awards Based on Absolute TSR \| Three Year Period \| Maximum
Stock-based compensation
Number of PSUs that may vest, as a percent	200%					200%
2022 PSU Awards Based on Absolute TSR
Weighted-average assumptions used to calculate fair value of performance share units granted
Volatility (as a percent)					88%
Risk-free interest rate (as a percent)					2.65%
Weighted average fair value of awards granted - Absolute TSR					$ 47.53
PSU Awards Based On Leverage Ratio
Stock-based compensation
Service period	1 year
Number of performance periods \| period	3
PSU Awards Based On Leverage Ratio \| Minimum
Stock-based compensation
Number of PSUs that may vest, as a percent	0%
PSU Awards Based On Leverage Ratio \| Maximum
Stock-based compensation
Number of PSUs that may vest, as a percent	200%

Equity-Based Compensation and_7

Equity-Based Compensation and Cash Awards - Converted AM RSU Awards (Details) - Converted AM RSU Awards $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) $ / shares shares
Number of units
Total awarded and unvested at the beginning of the period (in shares) \| shares	81,707
Vested (in shares) \| shares	(78,880)
Total awarded and unvested at the end of the period (in shares) \| shares	2,827
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share) \| $ / shares	$ 13.46
Vested (in dollars per share) \| $ / shares	13.50
Total awarded and unvested at the end of the period (in dollars per share) \| $ / shares	$ 12.38
Weighted average period for recognizing unrecognized stock-based compensation expense	3 months 18 days
Maximum
Weighted average grant date fair value
Unamortized equity-based compensation expense \| $	$ 0.1

Fair Value (Details)

Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Fair value \| Level 2 market data
Financial Instruments
Value	$ 1,462,763	$ 2,592,014
Fair value \| Level 2 market data \| 5.00% senior notes due 2025
Financial Instruments
Value		594,866
Fair value \| Level 2 market data \| 8.375% Senior Notes Due 2026
Financial Instruments
Value	108,692	370,013
Fair value \| Level 2 market data \| 7.625% Senior Notes Due 2029
Financial Instruments
Value	415,837	654,080
Fair value \| Level 2 market data \| 5.375% senior notes due 2030
Financial Instruments
Value	537,780	641,400
Fair value \| Level 2 market data \| 4.25% convertible senior notes due 2026
Financial Instruments
Value	400,454	331,655
Carrying value
Financial Instruments
Value	1,163,828	2,125,444
Carrying value \| 5.00% senior notes due 2025
Financial Instruments
Value		581,117
Carrying value \| 8.375% Senior Notes Due 2026
Financial Instruments
Value	103,028	321,738
Carrying value \| 7.625% Senior Notes Due 2029
Financial Instruments
Value	411,363	577,149
Carrying value \| 5.375% senior notes due 2030
Financial Instruments
Value	593,736	593,234
Carrying value \| 4.25% convertible senior notes due 2026
Financial Instruments
Value	$ 55,701	$ 52,206

Derivative Instruments - Commod

Derivative Instruments - Commodity derivatives (Details)	Sep. 30, 2022 MMBTU / d bbl / d $ / MMBTU $ / bbl
Swaption Agreement
Derivative Instruments
Notional amount \| MMBTU / d	427,500
Strike price	2.77
Swaps \| Natural gas. \| Henry Hub \| October-December 2022
Derivative Instruments
Notional amount \| MMBTU / d	1,105,897
Weighted average index price	2.48
Swaps \| Natural gas. \| Henry Hub \| January-December 2023
Derivative Instruments
Notional amount \| MMBTU / d	43,000
Weighted average index price	2.37
Swaps \| Natural gas. \| Henry Hub \| January-December 2023 \| VIE, Martica
Derivative Instruments
Notional amount \| MMBTU / d	35,616
Weighted average index price	2.35
Swaps \| Natural gas. \| Henry Hub \| January-December 2024 \| VIE, Martica
Derivative Instruments
Notional amount \| MMBTU / d	23,885
Weighted average index price	2.33
Swaps \| Natural gas. \| NYMEX to TCO \| October-December 2022
Derivative Instruments
Notional amount \| MMBTU / d	60,000
Weighted average hedged differential	0.515
Swaps \| Natural gas. \| NYMEX to TCO \| January-December 2023
Derivative Instruments
Notional amount \| MMBTU / d	50,000
Weighted average hedged differential	0.525
Swaps \| Natural gas. \| NYMEX to TCO \| January-December 2024
Derivative Instruments
Notional amount \| MMBTU / d	50,000
Weighted average hedged differential	0.530
Swaps \| Propane \| Mont Belvieu Propane OPIS Non TET \| October-December 2022 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	952
Weighted average index price \| $ / bbl	19.32
Swaps \| Natural Gasoline \| Henry Hub \| October-December 2022 \| VIE, Martica
Derivative Instruments
Notional amount \| MMBTU / d	40,592
Weighted average index price	2.39
Swaps \| Natural Gasoline \| Mont Belvieu Natural Gasoline-OPIS Non-TET \| October-December 2022 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	288
Weighted average index price \| $ / bbl	34.86
Swaps \| Natural Gasoline \| Mont Belvieu Natural Gasoline-OPIS Non-TET \| January-December 2023 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	247
Weighted average index price \| $ / bbl	40.74
Swaps \| Oil \| Henry Hub \| January-March 2025 \| VIE, Martica
Derivative Instruments
Notional amount \| MMBTU / d	18,021
Weighted average index price	2.53
Swaps \| Oil \| West Texas Intermediate \| October-December 2022 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	105
Weighted average index price \| $ / bbl	43.50
Swaps \| Oil \| West Texas Intermediate \| January-December 2023 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	99
Weighted average index price \| $ / bbl	44.88
Swaps \| Oil \| West Texas Intermediate \| January-December 2024 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	43
Weighted average index price \| $ / bbl	44.02
Swaps \| Oil \| West Texas Intermediate \| January-March 2025 \| VIE, Martica
Derivative Instruments
Notional amount \| bbl / d	39
Weighted average index price \| $ / bbl	45.06
Call option and embedded put option \| Natural gas. \| Henry Hub \| October-December 2022
Derivative Instruments
Notional amount \| MMBTU / d	59,000
Call option and embedded put option \| Natural gas. \| Henry Hub \| January-December 2023
Derivative Instruments
Notional amount \| MMBTU / d	55,000
Call option and embedded put option \| Natural gas. \| Henry Hub \| January-December 2024
Derivative Instruments
Notional amount \| MMBTU / d	53,000
Call option and embedded put option \| Natural gas. \| Henry Hub \| January-December 2025
Derivative Instruments
Notional amount \| MMBTU / d	44,000
Call option and embedded put option \| Natural gas. \| Henry Hub \| January-December 2026
Derivative Instruments
Notional amount \| MMBTU / d	32,000
Call option and embedded put option \| Natural gas. \| Put option \| Henry Hub \| October-December 2022
Derivative Instruments
Strike price	2.545
Call option and embedded put option \| Natural gas. \| Put option \| Henry Hub \| January-December 2023
Derivative Instruments
Strike price	2.466
Call option and embedded put option \| Natural gas. \| Put option \| Henry Hub \| January-December 2024
Derivative Instruments
Strike price	2.527
Call option and embedded put option \| Natural gas. \| Put option \| Henry Hub \| January-December 2025
Derivative Instruments
Strike price	2.614
Call option and embedded put option \| Natural gas. \| Put option \| Henry Hub \| January-December 2026
Derivative Instruments
Strike price	2.679
Call option and embedded put option \| Natural gas. \| Call Option \| Henry Hub \| October-December 2022
Derivative Instruments
Strike price	2.545
Call option and embedded put option \| Natural gas. \| Call Option \| Henry Hub \| January-December 2023
Derivative Instruments
Strike price	2.466
Call option and embedded put option \| Natural gas. \| Call Option \| Henry Hub \| January-December 2024
Derivative Instruments
Strike price	2.477
Call option and embedded put option \| Natural gas. \| Call Option \| Henry Hub \| January-December 2025
Derivative Instruments
Strike price	2.564
Call option and embedded put option \| Natural gas. \| Call Option \| Henry Hub \| January-December 2026
Derivative Instruments
Strike price	2.629

Derivative Instruments - Fair v

Derivative Instruments - Fair value (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Fair value of derivative instruments
Current portion of fair value of derivative assets	$ 954	$ 757
Noncurrent portion of fair value of derivative assets	7,327	14,369
Current portion of fair value of derivative liabilities	612,237	559,851
Noncurrent portion of fair value of derivative liabilities	445,481	181,806
Derivatives not designated as hedges for accounting purposes
Fair value of derivative instruments
Total asset derivatives	8,281	15,126
Total liability derivatives	1,057,718	741,657
Net derivatives assets (liabilities)	(1,049,437)	(726,531)
Derivatives not designated as hedges for accounting purposes \| Commodity derivatives
Fair value of derivative instruments
Current portion of fair value of derivative liabilities	612,237	559,851
Noncurrent portion of fair value of derivative liabilities	445,481	181,806
Derivatives not designated as hedges for accounting purposes \| Commodity derivatives \| VIE, Martica
Fair value of derivative instruments
Current portion of fair value of derivative liabilities	53,000	31,000
Noncurrent portion of fair value of derivative liabilities	31,000	24,000
Total liability derivatives	84,000	55,000
Derivatives not designated as hedges for accounting purposes \| Embedded derivatives
Fair value of derivative instruments
Current portion of fair value of derivative assets	954	757
Noncurrent portion of fair value of derivative assets	$ 7,327	$ 14,369

Derivative Instruments - Assets

Derivative Instruments - Assets and liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Commodity derivatives
Commodity derivative assets
Gross amounts on balance sheet	$ 516	$ 2,177
Gross amounts offset on balance sheet	(516)	(2,177)
Commodity derivative liabilities
Gross amounts on balance sheet	(1,058,234)	(743,834)
Gross amounts offset on balance sheet	516	2,177
Total liability derivatives	(1,057,718)	(741,657)
Embedded derivatives
Commodity derivative assets
Gross amounts on balance sheet	8,281	15,126
Total asset derivatives	$ 8,281	$ 15,126

Derivative Instruments - Fair_2

Derivative Instruments - Fair value gains (losses) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Summary of realized and unrealized gains (losses) on derivative instruments
Derivative fair value gains (losses)	$ (530,523)	$ (1,250,466)	$ (1,807,565)	$ (2,260,062)
Commodity derivatives \| Revenue.
Summary of realized and unrealized gains (losses) on derivative instruments
Derivative fair value gains (losses)	(500,557)	(1,238,384)	(1,732,720)	(2,228,076)
Embedded derivatives \| Revenue.
Summary of realized and unrealized gains (losses) on derivative instruments
Derivative fair value gains (losses)	$ (29,966)	$ (12,082)	$ (74,845)	$ (31,986)

Leases (Details)

Leases (Details)	9 Months Ended
Leases (Details)	Sep. 30, 2022
Leases
Options to renew - Operating lease	true
Minimum
Leases
Renewal terms - Operating lease	1 year
Maximum
Leases
Renewal terms - Operating lease	20 years

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information Related to Leases (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Lease Assets
Operating leases right-of-use assets	$ 3,541,576	$ 3,419,912
Short-term operating lease obligation	$ 535,014	$ 455,950
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Operating And Finance Lease Liability Current	Operating And Finance Lease Liability Current
Long-term operating lease obligation	$ 3,006,562	$ 2,963,962
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Operating And Finance Lease Liability Noncurrent	Operating And Finance Lease Liability Noncurrent
Total operating lease obligation	$ 3,541,576	$ 3,419,912
Finance leases, right of use assets	1,407	550
Short-term finance lease obligation	$ 333	$ 397
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	Operating And Finance Lease Liability Current	Operating And Finance Lease Liability Current
Long-term finance lease obligation	$ 1,074	$ 153
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Operating And Finance Lease Liability Noncurrent	Operating And Finance Lease Liability Noncurrent
Total finance lease obligation	$ 1,407	$ 550
Finance leases, accumulated amortization	1,000	2,000
Vehicles
Lease Assets
Operating leases right-of-use assets	$ 1,074	$ 2,009
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating leases right-of-use assets	Operating leases right-of-use assets
Finance leases, right of use assets	$ 1,407	$ 550
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Property, Plant and Equipment, Other, Gross	Property, Plant and Equipment, Other, Gross
Other office and field equipment
Lease Assets
Operating leases right-of-use assets	$ 4,068	$ 482
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating leases right-of-use assets	Operating leases right-of-use assets
Processing plants
Lease Assets
Operating leases right-of-use assets	$ 1,906,419	$ 1,739,550
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating leases right-of-use assets	Operating leases right-of-use assets
Drilling rigs and completion services
Lease Assets
Operating leases right-of-use assets	$ 64,022	$ 9,860
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating leases right-of-use assets	Operating leases right-of-use assets
Gas gathering lines and compressor stations
Lease Assets
Operating leases right-of-use assets	$ 1,523,233	$ 1,634,928
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating leases right-of-use assets	Operating leases right-of-use assets
Gas gathering lines and compressor stations \| Antero Midstream Corporation
Lease Assets
Operating leases right-of-use assets	$ 1,500,000	$ 1,500,000
Office space
Lease Assets
Operating leases right-of-use assets	$ 42,760	$ 33,083
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating leases right-of-use assets	Operating leases right-of-use assets

Leases - Supplemental Informati

Leases - Supplemental Information Related to Leases (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Leases
Total operating lease cost	$ 427,433	$ 417,836	$ 1,213,210	$ 1,243,113
Total finance lease cost	138	418	397	728
Short-term lease payments	$ 38,690	$ 21,030	115,798	62,328
Operating cash flows from operating leases			1,067,786	1,042,684
Investing cash flows from operating leases			70,654	66,042
Financing cash flows from finance leases			441	692
Right-of-use assets obtained in exchange for new operating lease obligations			366,194	232,771
Increase (decrease) to existing right-of-use assets and lease obligations from operating lease modifications, net			$ 119,290	$ 345,066
Weighted average discount rate for remeasured operating leases (as a percent)	5.20%	5.50%	5.20%	5.50%	5.60%	14.40%
Proved properties
Leases
Total operating lease cost	$ 34,288	$ 25,558	$ 83,146	$ 82,749
Gathering, compression, water handling and treatment, processing, and transportation
Leases
Total operating lease cost	378,246	386,033	1,109,422	1,147,985
General and administrative.
Leases
Total operating lease cost	2,855	2,833	8,509	8,057
Contract termination
Leases
Total operating lease cost	12,000	3,369	12,000	4,213
Lease operating.
Leases
Total operating lease cost	44	43	133	109
Depletion, depreciation and amortization
Leases
Amortization of right-of-use assets	94	132	319	391
Interest expense
Leases
Interest on lease liabilities	$ 44	$ 286	$ 78	$ 337

Leases - Maturities of Lease Li

Leases - Maturities of Lease Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Future minimum payments for operating lease liabilities
Remainder of 2022	$ 178,967
2023	706,880
2024	645,692
2025	585,209
2026	534,508
2027	442,252
Thereafter	1,203,662
Total lease payments	4,297,170
Less: imputed interest	(755,594)
Total operating lease obligation	3,541,576	$ 3,419,912
Future minimum payments for financing lease liabilities
Remainder of 2022	145
2023	510
2024	501
2025	459
2026	210
Total lease payments	1,825
Less: imputed interest	(418)
Total finance lease obligation	1,407	$ 550
Future minimum payments for total lease liabilities
Remainder of 2022	179,112
2023	707,390
2024	646,193
2025	585,668
2026	534,718
2027	442,252
Thereafter	1,203,662
Total lease payments	4,298,995
Less: imputed interest	(756,012)
Total	$ 3,542,983

Leases - Lease Term and Discoun

Leases - Lease Term and Discount Rate (Details)	Sep. 30, 2022	Dec. 31, 2021
Leases
Weighted-average remaining lease term: Operating lease	7 years 4 months 24 days	7 years 7 months 6 days
Weighted-average discount rate: Operating lease	5.30%	5.50%
Weighted-average remaining lease term: Finance lease	3 years 6 months	1 year 10 months 24 days
Weighted-average discount rate: Finance lease	6.80%	5.60%

Leases - Related Party Lease Di

Leases - Related Party Lease Disclosure (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Leases
Accounts payable, related parties	$ 74,584				$ 74,584		$ 76,240
Antero Midstream Corporation
Leases
Minimum volume commitments that require Antero to utilize or pay certain percentage of the capacity of new construction for high pressure lines (as a percent)					75%
Minimum volume commitments that require Antero to utilize or pay certain percentage of the capacity of new construction of compressor stations (as a percent)					70%
Term of lease	10 years				10 years
Notice period					180 days
Rebate received	$ 12,000		$ 0	$ 0	$ 36,000
Gathering and compression fees paid	164,000	$ 178,000			492,000	$ 539,000
Accounts payable, related parties	$ 53,000				$ 53,000		$ 54,000
Percentage of rate of return	13%				13%
Term for rate of return on constructions					7 years

Commitments (Details)

Commitments (Details) $ in Thousands	Sep. 30, 2022 USD ($)
Future minimum payments
Remainder of 2022	$ 476,364
2023	1,936,370
2024	1,839,081
2025	1,745,054
2026	1,655,294
2027	1,557,676
Thereafter	7,148,759
Total	16,358,598
Firm transportation
Future minimum payments
Remainder of 2022	282,279
2023	1,157,330
2024	1,130,195
2025	1,107,995
2026	1,102,362
2027	1,098,497
Thereafter	5,860,221
Total	11,738,879
Processing, Gathering, Compression and Water Service
Future minimum payments
Remainder of 2022	14,932
2023	71,650
2024	62,693
2025	51,391
2026	18,214
2027	16,927
Thereafter	84,876
Total	320,683
Land payment obligations
Future minimum payments
Remainder of 2022	41
Total	41
Operating and Financing Leases
Future minimum payments
Remainder of 2022	132,838
2023	538,749
2024	505,219
2025	471,022
2026	444,514
2027	374,087
Thereafter	1,076,554
Total	3,542,983
Imputed Interest for Leases
Future minimum payments
Remainder of 2022	46,274
2023	168,641
2024	140,974
2025	114,646
2026	90,204
2027	68,165
Thereafter	127,108
Total	$ 756,012

Contingencies (Details)

Contingencies (Details) - WGL $ in Millions		1 Months Ended
Contingencies (Details) - WGL $ in Millions	Jun. 20, 2019 USD ($)	Feb. 28, 2021 USD ($)	Jun. 30, 2019 lawsuit	Mar. 31, 2017 USD ($)
Settled Litigation
Contingencies
Damages awarded	$ 96
Settlement amount received		$ 107
Pending Litigation
Contingencies
Number of lawsuits \| lawsuit			2
Pending Litigation \| Minimum
Contingencies
Damages sought				$ 40

Reportable Segments (Details)

Reportable Segments (Details) $ in Thousands	3 Months Ended		9 Months Ended
Reportable Segments (Details) $ in Thousands	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) segment	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Operating results and assets of reportable segments
Number of reportable segments \| segment			3
Sales and revenues:
Sales and revenues - Third-party	$ 2,064,287	$ 533,353	$ 5,052,000	$ 2,224,610
Sales and revenues - Intersegment	337	530	1,149	551
Revenues	2,064,624	533,883	5,053,149	2,225,161
Operating expenses:
Lease operating	27,453	25,363	70,486	71,555
General and administrative	42,903	32,442	123,033	108,693
Depletion, depreciation, and amortization	169,607	182,810	511,390	564,166
Impairment of oil and gas properties	33,924	26,253	79,749	69,618
Other	300,189	322,864	674,534	768,949
Total operating expenses	1,290,464	1,217,957	3,422,070	3,457,645
Operating income (loss)	774,160	(684,074)	1,631,079	(1,232,484)
Equity in earnings of unconsolidated affiliates	14,972	21,450	54,863	57,621
Capital expenditures for segment assets	244,680	387,783	721,420	510,941
Investments in unconsolidated affiliates	222,882		222,882		$ 232,399
Total assets	14,413,378		14,413,378		13,896,528
Gathering, compression, water handling and treatment, processing, and transportation
Operating expenses:
Cost of goods and services sold	716,388	628,225	1,962,878	1,874,664
Operating segments \| Exploration and production
Sales and revenues:
Sales and revenues - Third-party	1,904,302	300,668	4,716,827	1,661,682
Sales and revenues - Intersegment	337	530	1,149	551
Revenues	1,904,639	301,198	4,717,976	1,662,233
Operating expenses:
Lease operating	27,453	25,363	70,486	71,555
General and administrative	42,903	32,442	123,033	108,693
Depletion, depreciation, and amortization	169,607	182,810	511,390	564,166
Impairment of oil and gas properties	33,924	26,253	79,749	69,618
Other	114,812	56,113	258,963	141,127
Total operating expenses	1,105,087	951,206	3,006,499	2,829,823
Operating income (loss)	799,552	(650,008)	1,711,477	(1,167,590)
Equity in earnings of unconsolidated affiliates	14,972	21,450	54,863	57,621
Capital expenditures for segment assets	244,680	387,783	721,420	510,941
Investments in unconsolidated affiliates	222,882		222,882		232,399
Total assets	14,350,938		14,350,938		13,864,402
Operating segments \| Exploration and production \| Gathering, compression, water handling and treatment, processing, and transportation
Operating expenses:
Cost of goods and services sold	716,388	628,225	1,962,878	1,874,664
Operating segments \| Marketing
Sales and revenues:
Sales and revenues - Third-party	159,985	232,685	335,173	562,928
Revenues	159,985	232,685	335,173	562,928
Operating expenses:
Other	185,377	266,751	415,571	627,822
Total operating expenses	185,377	266,751	415,571	627,822
Operating income (loss)	(25,392)	(34,066)	(80,398)	(64,894)
Total assets	62,440		62,440		32,126
Operating segments \| Antero Midstream Corporation
Sales and revenues:
Sales and revenues - Third-party	1,651	245	2,288	340
Sales and revenues - Intersegment	229,383	224,559	676,144	681,372
Revenues	231,034	224,804	678,432	681,712
Operating expenses:
General and administrative	13,587	14,810	47,597	46,991
Depletion, depreciation, and amortization	34,206	27,487	98,181	80,956
Other	(1,177)	1,187	5,375	8,590
Total operating expenses	93,264	82,983	283,112	254,905
Operating income (loss)	137,770	141,821	395,320	426,807
Equity in earnings of unconsolidated affiliates	24,411	24,088	70,467	66,347
Capital expenditures for segment assets	74,120	82,583	236,154	156,948
Investments in unconsolidated affiliates	659,006		659,006		696,009
Total assets	5,563,821		5,563,821		5,544,001
Operating segments \| Antero Midstream Corporation \| Gathering, compression, water handling and treatment, processing, and transportation
Operating expenses:
Cost of goods and services sold	46,648	39,499	131,959	118,368
Elimination of intersegment transaction
Sales and revenues:
Sales and revenues - Third-party	(1,651)	(245)	(2,288)	(340)
Sales and revenues - Intersegment	(229,383)	(224,559)	(676,144)	(681,372)
Revenues	(231,034)	(224,804)	(678,432)	(681,712)
Operating expenses:
General and administrative	(13,587)	(14,810)	(47,597)	(46,991)
Depletion, depreciation, and amortization	(34,206)	(27,487)	(98,181)	(80,956)
Other	1,177	(1,187)	(5,375)	(8,590)
Total operating expenses	(93,264)	(82,983)	(283,112)	(254,905)
Operating income (loss)	(137,770)	(141,821)	(395,320)	(426,807)
Equity in earnings of unconsolidated affiliates	(24,411)	(24,088)	(70,467)	(66,347)
Capital expenditures for segment assets	(74,120)	(82,583)	(236,154)	(156,948)
Investments in unconsolidated affiliates	(659,006)		(659,006)		(696,009)
Total assets	(5,563,821)		(5,563,821)		$ (5,544,001)
Elimination of intersegment transaction \| Gathering, compression, water handling and treatment, processing, and transportation
Operating expenses:
Cost of goods and services sold	$ (46,648)	$ (39,499)	$ (131,959)	$ (118,368)

Subsidiary Guarantors - Balance

Subsidiary Guarantors - Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Other current assets	$ 28,587	$ 14,922
Total current assets	977,654	686,119
Total assets	14,413,378	13,896,528
Liabilities and Stockholders' Equity
Accounts payable, non-guarantor subsidiaries	74,584	76,240
Other current liabilities	6,010	11,140
Total current liabilities	2,544,022	2,068,117
Total liabilities	7,943,116	7,830,436
Parent (Antero) And Guarantor Subsidiaries
Current assets:
Other current assets	908,074	633,014
Total current assets	908,074	633,014
Noncurrent assets	12,753,226	12,480,350
Total assets	13,661,300	13,113,364
Liabilities and Stockholders' Equity
Accounts payable, related parties	74,584	76,240
Other current liabilities	2,421,768	1,961,041
Total current liabilities	2,496,352	2,037,281
Noncurrent liabilities	5,368,027	5,737,999
Total liabilities	$ 7,864,379	$ 7,775,280

Subsidiary Guarantors - Stateme

Subsidiary Guarantors - Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Condensed consolidated statement of operations and comprehensive income (loss)
Revenues	$ 2,583,865			$ 1,772,415			$ 6,829,011	$ 4,450,839
Operating expenses	1,290,464			1,217,957			3,422,070	3,457,645
Income from operations	774,160			(684,074)			1,631,079	(1,232,484)
Net income and comprehensive income including noncontrolling interests	594,507	$ 812,033	$ (174,696)	(566,575)	$ (534,451)	$ (11,104)	1,231,844	(1,112,130)
Net income and comprehensive income attributable to Antero Resources Corporation	$ 559,759			$ (549,318)			1,168,475	$ (1,088,284)
Parent (Antero) And Guarantor Subsidiaries
Condensed consolidated statement of operations and comprehensive income (loss)
Revenues							4,955,613
Operating expenses							3,387,903
Income from operations							1,567,710
Net income and comprehensive income including noncontrolling interests							1,168,475
Net income and comprehensive income attributable to Antero Resources Corporation							$ 1,168,475