Antero Resources (AR) 10-Q 28 Apr 21 2021 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2021	Apr. 23, 2021
Document and Entity Information
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2021
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		301,901,385
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q1
Entity Central Index Key	0001433270
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Current assets:
Accounts receivable	$ 86,657	$ 28,457
Accrued revenue	446,513	425,314
Derivative instruments	41,356	105,130
Other current assets	11,781	15,238
Total current assets	586,307	574,139
Oil and gas properties, at cost (successful efforts method):
Unproved properties	1,144,531	1,175,178
Proved properties	12,330,278	12,260,713
Gathering systems and facilities	5,802	5,802
Other property and equipment	77,826	74,361
Property and equipment, gross	13,558,437	13,516,054
Less accumulated depletion, depreciation, and amortization	(3,990,460)	(3,869,116)
Property and equipment, net	9,567,977	9,646,938
Operating lease right-of-use assets	2,549,297	2,613,603
Derivative instruments	43,240	47,293
Investment in unconsolidated affiliate	241,158	255,082
Other assets	12,403	13,790
Total assets	13,000,382	13,150,845
Current liabilities:
Accounts payable	41,990	26,728
Accounts payable, related parties	85,846	69,860
Accrued liabilities	350,763	343,524
Revenue distributions payable	282,413	198,117
Derivative instruments	146,720	31,242
Short-term lease liabilities	265,551	266,024
Deferred revenue, VPP	43,357	45,257
Other current liabilities	4,688	2,302
Total current liabilities	1,221,328	983,054
Long-term liabilities:
Long-term debt	2,568,686	3,001,593
Deferred income tax liability	395,244	412,252
Derivative instruments	98,944	99,172
Long-term lease liabilities	2,284,680	2,348,785
Deferred revenue, VPP	146,695	156,024
Other liabilities	56,856	59,694
Total liabilities	6,772,433	7,060,574
Commitments and contingencies (Notes 13 and 14)
Equity:
Preferred stock, $0.01 par value; authorized - 50,000 shares; none issued
Common stock, $0.01 par value; authorized - 1,000,000 shares; 268,672 shares and 301,190 shares issued and outstanding as of December 31, 2020 and March 31, 2021, respectively	3,011	2,686
Additional paid-in capital	6,317,653	6,195,497
Accumulated deficit	(445,977)	(430,478)
Total stockholders' equity	5,874,687	5,767,705
Noncontrolling interests	353,262	322,566
Total equity	6,227,949	6,090,271
Total liabilities and equity	$ 13,000,382	$ 13,150,845

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2021	Dec. 31, 2020
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	301,190,000	268,672,000
Common stock, shares outstanding	301,190,000	268,672,000

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations and Comprehensive Loss - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Revenue and other:
Revenue	$ 1,370,164	$ 750,474
Commodity derivative fair value gains (losses)	(177,756)	565,833
Amortization of deferred revenue, VPP	11,150
Total revenue	1,204,198	1,317,105
Operating expenses:
Production and ad valorem taxes	44,697	25,699
Impairment of oil and gas properties	34,062	89,220
Depletion, depreciation, and amortization	194,026	199,677
Accretion of asset retirement obligations	788	1,104
General and administrative (including equity-based compensation expense of $3,329 and $5,642 in 2020 and 2021, respectively)	44,074	31,221
Contract termination and rig stacking	91
Total operating expenses	1,109,658	1,054,672
Operating income	94,540	262,433
Other income (expense):
Interest expense, net	(42,743)	(53,102)
Equity in earnings (loss) of unconsolidated affiliates	18,694	(128,055)
Gain (loss) on early extinguishment of debt	(43,204)	80,561
Loss on convertible note equitization	(39,046)
Impairment of equity method investment		(610,632)
Transaction expense	(2,291)
Total other expenses	(108,590)	(711,228)
Loss before income taxes	(14,050)	(448,795)
Provision for income tax benefit	2,946	109,985
Net loss and comprehensive loss including noncontrolling interests	(11,104)	(338,810)
Less: net income and comprehensive income attributable to noncontrolling interests	4,395
Net loss and comprehensive loss attributable to Antero Resources Corporation	$ (15,499)	$ (338,810)
Loss per share-basic (in dollars per share)	$ (0.05)	$ (1.19)
Loss per share-diluted (in dollars per share)	$ (0.05)	$ (1.19)
Weighted average number of shares outstanding:
Basic (in shares)	296,746	284,227
Diluted (in shares)	296,746	284,227
Natural gas sales
Revenue and other:
Revenue	$ 720,369	$ 411,082
Natural gas liquids sales
Revenue and other:
Revenue	440,319	257,673
Oil sales
Revenue and other:
Revenue	44,686	35,646
Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	605,077	588,624
Marketing
Revenue and other:
Revenue	164,790	46,073
Operating expenses:
Cost of goods and services sold	162,077	93,273
Other income
Revenue and other:
Revenue	640	798
Lease operating
Operating expenses:
Cost of goods and services sold	24,547	25,644
Exploration
Operating expenses:
Cost of goods and services sold	$ 219	$ 210

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Operations and Comprehensive Loss (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Condensed Consolidated Statements of Operations and Comprehensive Loss
Equity-based compensation expense	$ 5,642	$ 3,329

Condensed Consolidated Statem_3

Condensed Consolidated Statement of Equity - USD ($) $ in Thousands	Common Stock	Additional paid-in capital	Accumulated earnings (deficit)	Noncontrolling Interests	Total
Balances at Dec. 31, 2019	$ 2,959	$ 6,130,365	$ 837,419		$ 6,970,743
Balances (in shares) at Dec. 31, 2019	295,941
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes	$ 2	(34)			(32)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares)	178
Repurchases and retirements of common stock	$ (272)	(42,418)			(42,690)
Repurchases and retirements of common stock (in shares)	(27,193)
Equity-based compensation		3,329			3,329
Net income (loss) and comprehensive income (loss)			(338,810)		(338,810)
Balance at Mar. 31, 2020	$ 2,689	6,091,242	498,609		6,592,540
Balance (in shares) at Mar. 31, 2020	268,926
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
Distributions to non-controlling interests				(24,699)	(24,699)
Equity-based compensation		5,642			5,642
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

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash flows provided by (used in) operating activities:
Net loss including noncontrolling interests	$ (11,104)	$ (338,810)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion	194,814	200,781
Impairments	34,062	699,852
Commodity derivative fair value losses (gains)	177,756	(565,833)
Gains on settled commodity derivatives	5,322	210,926
Equity-based compensation expense	5,642	3,329
Deferred income tax benefit	(2,946)	(109,985)
Equity in (earnings) loss of unconsolidated affiliates	(18,694)	128,055
Dividends of earnings from unconsolidated affiliates	42,756	42,756
Amortization of deferred revenue	(11,150)
Amortization of debt issuance costs, debt discount, debt premium and other	4,536	2,440
Gain (loss) on early extinguishment of debt	43,204	(80,561)
Loss on convertible note equitization	39,046
Changes in current assets and liabilities:
Accounts receivable	(7,200)	(54,514)
Accrued revenue	(21,199)	116,566
Other current assets	3,593	(583)
Accounts payable including related parties	16,527	(1,251)
Accrued liabilities	(17,779)	(19,593)
Revenue distributions payable	84,296	(33,333)
Other current liabilities	2,249	435
Net cash provided by operating activities	563,731	200,677
Cash flows provided by (used in) investing activities:
Additions to unproved properties	(14,691)	(10,357)
Drilling and completion costs	(105,131)	(300,483)
Additions to other property and equipment	(3,336)	(771)
Settlement of water earnout		125,000
Change in other liabilities	(79)
Change in other assets	262	(70)
Net cash used in investing activities	(122,975)	(186,681)
Cash flows provided by (used in) financing activities:
Repurchases of common stock		(42,690)
Issuance of senior notes	1,200,000
Repayment of senior notes	(660,516)	(300,835)
Borrowings (repayments) on bank credit facilities, net	(873,800)	330,000
Payment of debt issuance costs	(15,370)
Distributions to noncontrolling interests	(24,699)
Employee tax withholding for settlement of equity compensation awards	(5,645)	(32)
Convertible note equitization	(60,461)
Other	(265)	(439)
Net cash used in financing activities	(440,756)	(13,996)
Net decrease in cash and cash equivalents	0	0
Cash and cash equivalents, end of period	0	0
Supplemental disclosure of cash flow information:
Cash paid during the period for interest	35,097	30,089
Increase in accounts payable and accrued liabilities for additions to property and equipment	$ 35,882	$ 10,767

Organization

Organization	3 Months Ended
	Mar. 31, 2021
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 are located in Denver, Colorado.

Summary of Significant Accounti

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2021
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, 2020 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, 2020 consolidated financial statements were included in Antero Resources’ 2020 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, 2020 and March 31, 2021 and its results of operations and cash flows for the three months ended March 31, 2020 and 2021. 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 March 31, 2021 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, any entities in which the Company owns a controlling interest, and variable interest entities (“VIEs”) for which the Company is the primary beneficiary, including Martica Holdings LLC (“Martica”). The noncontrolling interest reflected in the Company’s unaudited condensed consolidated financial statements for the three months ended March 31, 2021 represents the Company’s interest in Martica owned by third parties. (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 unaudited 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 March 31, 2021, the book overdrafts included within accounts payable and revenue distributions payable were $12 million and $23 million, respectively. As of December 31, 2020, the book overdrafts included within accounts payable and revenue distributions payable were $11 million and $15 million, respectively. (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 outstanding equity awards and shares of common stock issuable upon conversion of the 2026 Convertible Notes (as defined below in Note 7—Long-Term Debt), calculated using the treasury stock method. The Company includes restricted stock unit (“RSUs”) awards, performance share unit (“PSUs”) 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 effect of all equity awards is anti-dilutive. 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 March 31, ​ ​ 2020 2021 ​ Basic weighted average number of shares outstanding ​ 284,227 ​ 296,746 ​ Add: Dilutive effect of RSUs ​ — ​ — ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ Add: Dilutive effect of PSUs ​ — ​ — ​ Add: Dilutive effect of 2026 Convertible Notes ​ — ​ — ​ Diluted weighted average number of shares outstanding ​ 284,227 ​ 296,746 ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ RSUs ​ 5,952 ​ 6,455 ​ Outstanding stock options ​ 459 ​ 427 ​ PSUs ​ 1,621 ​ 1,863 ​ 2026 Convertible Notes ​ — ​ 15,307 ​ (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) Recently Issued Accounting Standards Convertible 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 require separate accounting for conversion features, and instead, allows the debt instrument and conversion features to be accounted for as a single debt instrument. The new standard becomes effective for the Company on January 1, 2022, and early adoption is permitted. The Company Upon adoption of this new standard, the Company expects to reclassify $15 million, net of deferred income taxes and equity issuance costs, to long-term debt and deferred income tax liability, as applicable, from stockholders’ equity, which amount is subject to adjustment for any conversions or other transactions until adoption of this new standard. Additionally, annual interest expense for the 2026 Convertible Notes will be based on an effective interest rate of . T he Company does not believe that adoption of the standard will impact its operational strategies or development prospects . ​ Income Taxes ​ In December 2019, the FASB issued ASU No. 2019-12, Simplifying the Accounting for Income Taxes . Income Taxes (“ASC 740”) and also simplifies portions of ASC 740 by clarifying and amending existing guidance. It is effective for interim and annual reporting periods after December 15, 2020. The Company adopted this ASU on January 1, 2021, and it did not have a material impact on the Company's unaudited condensed consolidated financial statements .

Transactions

Transactions	3 Months Ended
	Mar. 31, 2021
Transactions
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 first quarter of 2021 as of September 31, 2020 and March 31, 2021, respectively. The Company received a $51 million cash distribution during the fourth quarter of 2020 and expects to receive an additional $51 million cash distribution that will be paid during the second quarter of 2021. The ORRIs include an overriding royalty interest of 1.25% of the Company’s working interest in all of its proved operated developed properties in West Virginia and Ohio, subject to certain excluded wells (the “Initial PDP Override”), and an overriding royalty interest of 3.75% of the Company’s working interest in all of its undeveloped properties in West Virginia and Ohio (the “Development Override”). Wells turned to sales after April 1, 2020 and prior to the later of (a) the date on which the Company turns to sales 2.2 million lateral feet (net to the Company’s interest) of horizontal wells burdened by the Development Override and (b) the earlier of (i) April 1, 2023 and (ii) the date on which the Company turns to sales 3.82 million lateral feet (net to the Company’s interest) of horizontal wells are subject to the Development Override. The ORRIs also include an additional overriding royalty interest of 2.00% of the Company’s working interest in the properties underlying the Initial PDP Override (the “Incremental Override”). The Incremental Override (or a portion thereof, as applicable) may be re-conveyed to the Company (at the Company’s election) if certain production targets attributable to the ORRIs are achieved through March 31, 2023. Any portion of the Incremental Override that may not be re-conveyed to the Company based on the Company failing to achieve such production volumes through March 31, 2023 will remain with Martica. Prior to Sixth Street achieving an internal rate of return of 13% and 1.5 x cash-on-cash return (the “Hurdle”), Sixth Street will receive all distributions in respect of the Initial PDP Override and the Development Override, and the Company will receive all distributions in respect of the Incremental Override, unless certain production targets are not achieved, in which case Sixth Street will receive some or all of the distributions in respect of the Incremental Override. Following Sixth Street achieving the Hurdle, the Company will receive 85% of the distributions in respect of the ORRIs to which Sixth Street was entitled immediately prior to the Hurdle being achieved. The conveyance of the ORRIs from the Company to Martica was accounted for as a transaction between entities under common control. As a result, the contributed ORRIs have been recorded by Martica at their historical cost. (b) Volumetric Production Payment Transaction On August 10, 2020, the Company completed a volumetric production payment transaction and received net proceeds of approximately $216 million (the "VPP"). In connection with the VPP, the Company entered into a purchase and sale agreement, together with a conveyance agreement and production and marketing agreement, with J.P. Morgan Ventures Energy Corporation ("JPM-VEC") to convey, effective July 1, 2020, an overriding royalty interest in dry gas producing properties in West Virginia (the "VPP Properties") equal to 136,589,000 MMBtu over the expected seven-year term of the VPP. The Company has accounted for the VPP as a conveyance under ASC 932, Extractive Activities—Oil and Gas (“ASC 932”), and the net proceeds were recorded as deferred revenue in the unaudited condensed consolidated balance sheets. Deferred revenue is recognized as volumes are delivered using the units-of-production method over the term of the VPP. Under the production and marketing agreement, Antero and its affiliates provide certain marketing services as JPM-VEC’s agent, and any income or expenses related to these services will be recorded as marketing revenue or marketing expenses as appropriate. Contemporaneously with the VPP, the Company executed a call option related to the production volumes associated with its retained interest in the VPP properties, which is collateralized by a mortgage on the VPP properties. Additionally, the production and marketing agreement contains an embedded put option related to the production volumes for the Company’s retained interest in the VPP properties, which has been bifurcated from the production and marketing arrangement and accounted for as a derivative instrument recorded at fair value. See Note 11—Derivative Instruments to the unaudited condensed consolidated financial statements for more information on the Company’s derivative instruments. (c) 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, Antero Resources and QL agreed to a capital budget for such annual tranche, and for each subsequent year through 2024, Antero Resources will propose a capital budget and estimated internal rate of return (“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 an assignment, bill of sale and conveyance pursuant to which QL will be conveyed a proportionate working interest percentage in each well spud in that year, which conveyance will not be subject to any reversion. Under the terms of the arrangement, QL will fund 20% of development capital for wells spud in 2021 and is expected to fund between 15% and 20% of development capital for wells spud from 2022 through 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 December 31 following the end of each tranche year. 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 and such conveyances are recorded in the unaudited condensed consolidated financial statements as QL obtains its proportionate working interest in each well. No

Revenue

Revenue	3 Months Ended
	Mar. 31, 2021
Revenue
Revenue	(4) Revenue (a) Disaggregation of Revenue The table set forth below presents revenue disaggregated by type and the reportable segment to which it relates (in thousands). See Note 16—Reportable Segments for more information on reportable segments. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ ​ ​ 2020 2021 Reportable Segment ​ Revenues from contracts with customers: ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 411,082 ​ ​ 720,369 ​ Exploration and production ​ Natural gas liquids sales (ethane) ​ ​ 26,796 ​ ​ 36,110 ​ Exploration and production ​ Natural gas liquids sales (C3+ NGLs) ​ ​ 230,877 ​ ​ 404,209 ​ Exploration and production ​ Oil sales ​ ​ 35,646 ​ ​ 44,686 ​ Exploration and production ​ Marketing ​ ​ 46,073 ​ ​ 164,790 ​ Marketing ​ Total revenue from contracts with customers ​ ​ 750,474 ​ ​ 1,370,164 ​ ​ ​ Income from derivatives, deferred revenue and other sources ​ ​ 566,631 ​ ​ (165,966) ​ ​ ​ Total revenue ​ $ 1,317,105 ​ ​ 1,204,198 ​ ​ ​ ​ (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 one year or less. (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, 2020 and March 31, 2021, the Company’s receivables from contracts with customers were $425 million and $447 million, respectively.

Equity Method Investments

Equity Method Investments	3 Months Ended
	Mar. 31, 2021
Equity Method Investments.
Equity Method Investments	(5) Equity Method Investment (a) Summary of Equity Method Investment As of March 31, 2021, Antero owned approximately 29.2% of Antero Midstream Corporation’s 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 for the three months ended March 31, 2021 (in thousands): ​ ​ ​ ​ ​ Balance as of December 31, 2020 (1) ​ $ 255,082 ​ Equity in loss of unconsolidated affiliate ​ ​ 18,694 ​ Dividends from unconsolidated affiliate ​ ​ (42,756) ​ Elimination of intercompany profit ​ ​ 10,138 ​ Balance as of March 31, 2021 (1) ​ $ 241,158 ​ (1) The Company’s investment in Antero Midstream Corporation as of December 31, 2020 and March 31, 2021 was $1.1 billion and $1.3 billion, respectively, based on the quoted market share price of Antero Midstream Corporation . (b) Summarized Financial Information of Antero Midstream Corporation The tables set forth below present summarized financial information of Antero Midstream Corporation (in thousands). Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ 2020 2021 ​ Current assets ​ $ 93,931 ​ ​ 91,167 ​ Noncurrent assets ​ ​ 5,516,981 ​ ​ 5,455,593 ​ Total assets ​ $ 5,610,912 ​ ​ 5,546,760 ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 94,005 ​ ​ 79,750 ​ Noncurrent liabilities ​ ​ 3,098,621 ​ ​ 3,110,144 ​ Stockholders' equity ​ ​ 2,418,286 ​ ​ 2,356,866 ​ Total liabilities and stockholders' equity ​ $ 5,610,912 ​ ​ 5,546,760 ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ 2020 2021 ​ Revenues ​ $ 243,708 ​ ​ 224,121 ​ Operating expenses ​ ​ 762,872 ​ ​ 90,534 ​ Income (loss) from operations ​ ​ (519,164) ​ ​ 133,587 ​ Income (loss) attributable to the equity method investment ​ ​ (392,933) ​ ​ 83,441 ​ ​

Accrued Liabilities

Accrued Liabilities	3 Months Ended
	Mar. 31, 2021
Accrued Liabilities
Accrued Liabilities	(6) Accrued Liabilities Accrued liabilities as of December 31, 2020 and March 31, 2021 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ 2020 2021 ​ Capital expenditures ​ $ 32,372 ​ 44,476 ​ Gathering, compression, processing, and transportation expenses ​ ​ 152,724 ​ ​ 149,266 ​ Marketing expenses ​ ​ 68,193 ​ ​ 59,396 ​ Interest expense, net ​ 25,645 ​ 39,049 ​ Accrued taxes ​ ​ 40,796 ​ ​ 24,386 ​ Other ​ 23,794 ​ 34,190 ​ Total accrued liabilities ​ $ 343,524 ​ 350,763 ​ ​

Long-Term Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2021
Long-Term Debt.
Long-Term Debt	(7) Long-Term Debt Long-term debt as of December 31, 2020 and March 31, 2021 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ 2020 2021 ​ Credit Facility (a) ​ $ 1,017,000 ​ ​ 143,200 ​ 5.125% senior notes due 2022 (b) ​ ​ 660,516 ​ ​ — ​ 5.625% senior notes due 2023 (c) ​ ​ 574,182 ​ ​ 574,182 ​ 5.00% senior notes due 2025 (d) ​ ​ 590,000 ​ ​ 590,000 ​ 8.375% senior notes due 2026 (e) ​ ​ — ​ ​ 500,000 ​ 7.625% senior notes due 2029 (f) ​ ​ — ​ ​ 700,000 ​ 4.25% convertible senior notes due 2026 (g) ​ ​ 287,500 ​ ​ 137,500 ​ Total principal ​ ​ 3,129,198 ​ ​ 2,644,882 ​ Unamortized premium (discount), net ​ ​ (111,886) ​ ​ (51,669) ​ Unamortized debt issuance costs ​ ​ (15,719) ​ ​ (24,527) ​ Long-term debt ​ $ 3,001,593 ​ ​ 2,568,686 ​ ​ (a) Senior Secured Revolving Credit Facility Antero Resources has a senior secured revolving credit facility (the “Credit Facility”) with a consortium of bank lenders. Borrowings under the Credit Facility are subject to borrowing base limitations based on the collateral value of Antero Resources’ assets and are subject to regular semi-annual redeterminations. As of March 31, 2021, the borrowing base under the Credit Facility was $2.85 billion and lender commitments were $2.64 billion. The borrowing base was re-affirmed in the semi-annual redetermination in April 2021. The next redetermination of the borrowing base is scheduled to occur in October 2021. The Credit Facility is scheduled to mature on October 26, 2022. Antero Resources was in compliance with all of the financial covenants under the Credit Facility as of December 31, 2020 and March 31, 2021. As of March 31, 2021, Antero Resources had an outstanding balance under the Credit Facility of $143 million, with a weighted average interest rate of 3.13%, and outstanding letters of credit of $742 million. As of December 31, 2020, Antero Resources had an outstanding balance under the Credit Facility of $1.0 billion, with a weighted average interest rate of 3.26%, and outstanding letters of credit of $730 million. Commitment fees on the unused portion of the Credit Facility are due quarterly at rates ranging from 0.300% to 0.375% (subject to certain exceptions) of the unused portion based on utilization. ​ (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 $500 million of the 2022 Notes at 100.5 % of par. The Company repurchased or otherwise redeemed all of the 2022 Notes between 2019 and the first quarter of 2021. The 2022 Notes were unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2022 Notes ranked pari passu to Antero Resources’ other outstanding senior notes. The 2022 Notes were 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 2022 Notes was payable on June 1 and December 1 of each year. See —Debt Repurchase Program below for further details on 2022 Notes repurchases. (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 . The Company repurchased $176 million of the 2023 Notes from time to time during 2020, and as of March 31, 2021, $574 million principal amount of the 2023 Notes remained outstanding. The 2023 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2023 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2023 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 2023 Notes is payable on June 1 and December 1 of each year. Antero Resources may redeem all or part of the 2023 Notes at any time at redemption prices ranging from 101.406% currently to 100.00% on or after June 1, 2021. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2023 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to 101% of the principal amount of the 2023 Notes, plus accrued and unpaid interest. (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 $10 million of the 2025 Notes from time to time during 2020, and as of March 31, 2021, $590 million principal amount of the 2023 Notes remained outstanding. The 2025 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2025 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2025 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 2025 Notes is payable on March 1 and September 1 of each year. Antero Resources may redeem all or part of the 2025 Notes at any time at redemption prices ranging from 102.5% currently to 100.00 % on or after March 1, 2023. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2025 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to 101% of the principal amount of the 2025 Notes, plus accrued and unpaid interest. (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 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. In addition, on or before January 15, 2024, Antero Resources may redeem up to the 2026 Notes, plus accrued and unpaid interest. 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 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 of the principal amount of the 2029 Notes, plus accrued and unpaid interest. 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) 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 2026 (the “ 2026 Convertible Notes”). On September 2, 2020, Antero Resources issued an additional million of the 2026 Convertible Notes. 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 March 31, 2020, 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, note holders 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. Antero Resources’ current intent is to settle the remaining principal amount of the 2026 Convertible Notes in cash upon conversion. The 2026 Convertible Notes have met the Stock Price Condition allowing holders of the 2026 Convertible Notes to exercise their conversion right as of March 31, 2021. 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 will be 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 unaudited condensed consolidated balance sheet and statement of stockholders’ equity and will not be remeasured as long as it continues to meet the conditions for equity classification. 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 unaudited condensed consolidated balance sheet and are 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 unaudited condensed consolidated balance sheet and statement of stockholders’ equity. Partial Equitization of 2026 Convertible Notes On January 12, 2021, the Company completed a registered direct offering (the “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 Share Offering and approximately $63 million of borrowings under the Credit Facility to repurchase from such holders $150 million aggregate principal amount of the 2026 Convertible Notes in privately negotiated transactions (the “Convertible Note Repurchase,” and, collectively with the Share Offering, the “Equitization Transactions”). The 2026 Convertible Notes have an initial conversion rate of 230.2026 shares of the Company’s common stock per $1,000 principal amount, and the Equitization Transactions had the effect of increasing this conversion rate to 275.3525 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 $39 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 Equitization Transactions resulted in a loss on early extinguishment of debt of $43 million in the unaudited condensed consolidated statement of operations and comprehensive loss for the three months ended March 31, 2021. The 2026 Convertible Notes consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ ​ 2020 ​ 2021 ​ Liability component: ​ ​ ​ ​ ​ ​ ​ Principal ​ $ 287,500 ​ ​ 137,500 ​ Less: unamortized note discount ​ ​ (112,265) ​ ​ (51,669) ​ Less: unamortized debt issuance costs ​ ​ (5,852) ​ ​ (3,029) ​ Net carrying value ​ $ 169,383 ​ ​ 82,802 ​ Equity component (1) ​ $ 115,601 ​ ​ (14,755) ​ (1) As of December 31, 2020, the equity component of the 2026 Convertible Notes was recorded in additional paid-in capital, net of $3 million of issuance costs and $28 million of deferred taxes. As a result of the Equitization Transactions during the first quarter of 2021, the Company repurchased a portion of the equity component for $116 million, net of $14 million of deferred taxes. ​ Interest expense recognized on the 2026 Convertible Notes related to the stated interest rate, amortization of the debt discount and debt issuance costs totaled $4.4 million for the three months ended March 31, 2021. (h) Debt Repurchase Program During the three months ended March 31, 2020, Antero Resources repurchased $383 million principal amount of debt at a weighted average discount of 21% . The Company recognized a gain of million for the three months ended March 31, 2020 on the early extinguishment of the debt repurchased. ​ During the three months ended March 31, 2021, the Company redeemed the remaining $661 million of the 2022 Notes at par, which included a portion of the Company’s 5.375% senior notes due 2021 and the 2022 Notes, plus accrued and unpaid interest, and as a result, the 2022 Notes were fully retired as of February 10, 2021.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2021
Asset Retirement Obligations
Asset Retirement Obligations	(8) Asset Retirement Obligations The following table sets forth a reconciliation of the Company’s asset retirement obligations for the three months ended March 31, 2021 (in thousands): ​ ​ ​ ​ ​ Asset retirement obligations—December 31, 2020 $ 54,452 ​ Obligations incurred ​ 70 ​ Accretion expense ​ ​ 788 ​ Asset retirement obligations—March 31, 2021 ​ $ 55,310 ​ ​ Asset retirement obligations are included in other liabilities on the Company’s unaudited condensed consolidated balance sheets.

Equity-Based Compensation and C

Equity-Based Compensation and Cash Awards	3 Months Ended
	Mar. 31, 2021
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 7,928,770 shares were available for future grant under the 2020 Plan as of March 31, 2021. 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 include 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 Corporation and converted into 1.8926 RSUs under the Antero Midstream Corporation Long Term Incentive Plan (the “AMC Plan”). Each RSU award under the AMC Plan represents a right to receive one share of Antero Midstream Corporation common stock. The Company’s equity-based compensation expense, by type of award, was as follows for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ 2020 ​ 2021 ​ RSU awards ​ $ 1,878 ​ ​ 3,238 ​ PSU awards ​ ​ 922 ​ ​ 1,536 ​ Antero Midstream Partners phantom unit awards (1) ​ ​ 160 ​ ​ 518 ​ Equity awards issued to directors ​ ​ 369 ​ ​ 350 ​ Total expense ​ $ 3,329 ​ ​ 5,642 ​ (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 the deconsolidation of Antero Midstream Partners on March 12, 2019 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 for the three months ended March 31, 2021 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ Average ​ ​ ​ Number of ​ Grant Date ​ ​ Shares Fair Value ​ Total awarded and unvested—December 31, 2020 ​ 8,432,397 ​ $ 4.06 ​ Granted ​ 14,738 ​ ​ 7.26 ​ Vested ​ (1,906,286) ​ ​ 2.70 ​ Forfeited ​ (83,359) ​ ​ 4.82 ​ Total awarded and unvested—March 31, 2021 ​ 6,457,490 ​ $ 4.46 ​ ​ As of March 31, 2021, there was approximately $20 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 2.1 years. (b) Stock Options A summary of stock option activity for the three months ended March 31, 2021 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ Weighted ​ Average ​ ​ ​ ​ ​ ​ ​ Average ​ Remaining ​ Intrinsic ​ ​ ​ Stock ​ Exercise ​ Contractual ​ Value ​ ​ Options Price Life (in thousands) ​ Outstanding—December 31, 2020 ​ 432,461 ​ $ 50.64 ​ 4.1 ​ $ — ​ Granted ​ — ​ ​ — ​ ​ ​ ​ ​ ​ Exercised ​ — ​ ​ — ​ ​ ​ ​ ​ ​ Forfeited ​ — ​ ​ — ​ ​ ​ ​ ​ ​ Expired ​ (5,000) ​ ​ 50.00 ​ ​ ​ ​ ​ ​ Outstanding—March 31, 2021 ​ 427,461 ​ $ 50.65 ​ 3.8 ​ $ — ​ Vested—March 31, 2021 ​ 427,461 ​ $ 50.65 ​ 3.8 ​ $ — ​ Exercisable —March 31, 2021 ​ 427,461 ​ $ 50.65 ​ 3.8 ​ $ — ​ ​ 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 March 31, 2021, all stock options were fully vested resulting in no unamortized equity-based compensation expense. (c) Performance Share Unit Awards ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ Number of ​ Average Grant ​ ​ Units Date Fair Value ​ Total awarded and unvested—December 31, 2020 ​ 2,547,798 ​ $ 12.66 ​ Granted ​ — ​ ​ — ​ Forfeited ​ (23,283) ​ ​ 9.26 ​ Cancelled (unearned) ​ (133,334) ​ ​ 25.64 ​ Total awarded and unvested—March 31, 2021 ​ 2,391,181 ​ $ 11.97 ​ ​ As of March 31, 2021, there was approximately $6 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 1.2 years. (d) Cash Awards In January 2020, the Company granted cash awards of approximately $3.3 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 $2.6 million to certain non-executive employees under the 2020 Plan that vest ratably over four years . As of March 31, 2021, the Company has recorded approximately $2.4 million in Other liabilities in the unaudited condensed consolidated balance sheet related to cash awards. (e) Antero Midstream Corporation Restricted Stock Unit Awards A summary of Antero Midstream Corporation RSU awards for the three months ended March 31, 2021 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ Average ​ ​ ​ Number of ​ Grant Date ​ ​ Units Fair Value ​ Total awarded and unvested—December 31, 2020 ​ 296,390 ​ $ 15.06 ​ Granted ​ — ​ ​ ​ ​ Vested ​ (10,122) ​ ​ 15.81 ​ Forfeited ​ — ​ ​ ​ ​ Total awarded and unvested—March 31, 2021 ​ 286,268 ​ $ 15.04 ​ ​ As of March 31, 2021, there was approximately $1.6 million of unamortized equity-based compensation expense related to unvested phantom unit awards. That expense is expected to be recognized over a weighted average period of approximately less than 1.0 year, and the Company’s proportionate share will be allocated to it as it is recognized.

Fair Value

Fair Value	3 Months Ended
	Mar. 31, 2021
Fair Value
Fair Value	(10) Fair Value The carrying values of accounts receivable and accounts payable as of December 31, 2020 and March 31, 2021 approximated market values because of their short-term nature. The carrying values of the amounts outstanding under the Credit Facility as of 31, 2021 approximated fair value because the variable interest rates are reflective of current market conditions. The fair value and carrying value of the senior notes and 2026 Convertible Notes as of December 31, 2020 and March 31, 2021 is as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ March 31, 2021 ​ ​ Fair Carrying Fair Carrying ​ ​ ​ Value (1) ​ Value (2) ​ Value (1) ​ Value (2) ​ 5.125% senior notes due 2022 ​ $ 658,468 ​ ​ 658,400 ​ ​ — ​ ​ — ​ 5.625% senior notes due 2023 ​ ​ 562,698 ​ ​ 571,370 ​ ​ 576,077 ​ ​ 571,644 ​ 5.00% senior notes due 2025 ​ ​ 560,500 ​ ​ 585,440 ​ ​ 590,413 ​ ​ 585,687 ​ 8.375% senior notes due 2026 ​ ​ — ​ ​ — ​ ​ 551,250 ​ ​ 494,209 ​ 7.625% senior notes due 2029 ​ ​ — ​ ​ — ​ ​ 742,840 ​ ​ 691,144 ​ 4.25% convertible senior notes due 2026 ​ ​ 430,963 ​ ​ 169,383 ​ ​ 347,999 ​ ​ 82,802 ​ Total ​ $ 2,212,629 ​ ​ 1,984,593 ​ ​ 2,808,579 ​ ​ 2,425,486 ​ (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 11—Derivative Instruments to the unaudited condensed consolidated financial statements for information regarding the fair value of derivative financial instruments.

Derivative Instruments

Derivative Instruments	3 Months Ended
	Mar. 31, 2021
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 months ended March 31, 2020 and 2021. 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. The Company also entered into NGL derivative contracts, which establish a contractual price for the settlement month as a fixed percentage of the West Texas Intermediate Crude Oil index (“WTI”) price for the settlement month. When the percentage of the contractual price is above the contracted percentage, the Company pays the difference to the counterparty. When it is below the contracted percentage, the Company receives the difference from 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 March 31, 2021, the Company’s fixed price natural gas, oil and NGL swap positions excluding Martica, the Company’s consolidated VIE, were as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ ​ Average ​ Commodity / Settlement Period Index Contracted Volume Price Natural Gas ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Henry Hub ​ 2,160,000 MMBtu/day ​ $ 2.76 /MMBtu ​ January-December 2022 ​ Henry Hub ​ 1,155,486 MMBtu/day ​ ​ 2.50 /MMBtu ​ January-December 2023 ​ Henry Hub ​ 43,000 MMBtu/day ​ ​ 2.37 /MMBtu ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Propane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Propane-OPIS TET ​ 16,655 Bbl/day ​ $ 30.64 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Butane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Butane-OPIS Non-TET ​ 3,331 Bbl/day ​ $ 33.42 /Bbl ​ April-December 2021 ​ Mont Belvieu Butane-OPIS TET ​ 1,415 Bbl/day ​ $ 31.36 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural Gasoline ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 8,617 Bbl/day ​ $ 51.19 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Isobutane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-June 2021 ​ Mont Belvieu Isobutane-OPIS Non-TET ​ 662 Bbl/day ​ $ 33.30 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ West Texas Intermediate ​ 3,000 Bbl/day ​ $ 55.16 /Bbl ​ ​ In addition, the Company has a call option agreement, which entitles the holder 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. ​ As of March 31, 2021, 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 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ NYMEX to TCO ​ 40,000 MMBtu/day ​ $ 0.414 /MMBtu ​ January-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 March 31, 2021, the Company had natural gas and NGL contracts that fix the Mont Belvieu index price for natural gasoline to percentages of WTI as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted Average ​ Commodity / Settlement Period Index to Basis Differential Contracted Volume Payout Ratio ​ Gas Liquids ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Natural Gasoline to WTI ​ 9,325 Bbl/day ​ 78 % ​ ​ As of March 31, 2021, the Company’s fixed price natural gas, oil and NGL swap positions for Martica, the Company’s consolidated VIE, were as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ ​ Average ​ Commodity / Settlement Period Index Contracted Volume Price ​ Natural Gas ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Henry Hub ​ 47,385 MMBtu/day ​ $ 2.61 /MMBtu January-December 2022 ​ Henry Hub ​ 38,356 MMBtu/day ​ ​ 2.39 /MMBtu ​ January-December 2023 ​ Henry Hub ​ 35,615 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 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Ethane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Purity Ethane-OPIS ​ 1,033 Bbl/day ​ $ 7.01 /Bbl ​ January-March 2022 ​ Mont Belvieu Purity Ethane-OPIS ​ 521 Bbl/day ​ ​ 6.68 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Propane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Propane-OPIS Non-TET ​ 1,149 Bbl/day ​ $ 18.71 /Bbl ​ January-December 2022 ​ Mont Belvieu Propane-OPIS Non-TET ​ 934 Bbl/day ​ ​ 19.20 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural Gasoline ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 354 Bbl/day ​ $ 31.61 /Bbl ​ January-December 2022 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 282 Bbl/day ​ ​ 34.37 /Bbl ​ January-December 2023 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 247 Bbl/day ​ ​ 40.74 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ West Texas Intermediate ​ 129 Bbl/day ​ $ 40.86 /Bbl ​ January-December 2022 ​ West Texas Intermediate ​ 112 Bbl/day ​ ​ 43.51 /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) Embedded Derivatives The VPP includes an embedded put option tied to NYMEX pricing for the production volumes associated with the Company’s retained interest in the VPP properties of 106,073,000 MMBtu remaining through December 31, 2026 at a weighted average strike price of $2.59 per MMBtu. The embedded put option is not clearly and closely related to the host contract, and therefore, the Company bifurcated this derivative instrument and reflected it at fair value in the unaudited condensed consolidated financial statements. (c) Summary The following table presents a summary of the fair values in thousands of the Company’s derivative instruments and where such values are recorded in the unaudited condensed consolidated balance sheets as of December 31, 2020 and March 31, 2021. None of the Company’s derivative instruments are designated as hedges for accounting purposes. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Balance Sheet ​ December 31, ​ March 31, ​ ​ Location 2020 ​ 2021 ​ Asset derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives—current ​ Derivative instruments ​ $ 97,144 ​ ​ 36,633 ​ Embedded derivatives—current ​ Derivative instruments ​ ​ 7,986 ​ ​ 4,723 ​ Commodity derivatives—noncurrent ​ Derivative instruments ​ ​ 14,689 ​ ​ 15,681 ​ Embedded derivatives—noncurrent ​ Derivative instruments ​ ​ 32,604 ​ ​ 27,559 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total asset derivatives ​ ​ ​ ​ 152,423 ​ ​ 84,596 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liability derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives—current (1) ​ Derivative instruments ​ ​ 31,242 ​ ​ 146,720 ​ Commodity derivatives—noncurrent (1) ​ Derivative instruments ​ ​ 99,172 ​ ​ 98,944 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total liability derivatives ​ ​ ​ ​ 130,414 ​ ​ 245,664 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net derivatives assets (liabilities) ​ ​ ​ $ 22,009 ​ ​ (161,068) ​ (1) As of March 31, 2021, approximately $23 million of commodity derivative liabilities, including $13 million of current commodity derivatives and $10 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. As of December 31, 2020, approximately $14 million of commodity derivative liabilities, including $7 million of current commodity derivatives and $7 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. The following table presents 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 unaudited condensed consolidated balance sheets as of the dates presented, all at fair value (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ March 31, 2021 ​ ​ ​ ​ ​ ​ ​ Net Amounts of ​ ​ ​ ​ ​ Net Amounts of ​ ​ ​ Gross ​ Gross Amounts ​ Assets ​ Gross ​ Gross Amounts ​ Assets ​ ​ ​ Amounts on ​ Offset on ​ (Liabilities) on ​ Amounts on ​ Offset on ​ (Liabilities) on ​ ​ Balance Sheet Balance Sheet Balance Sheet Balance Sheet Balance Sheet Balance Sheet Commodity derivative assets ​ $ 181,375 ​ ​ (69,542) ​ ​ 111,833 ​ $ 90,891 ​ ​ (38,577) ​ ​ 52,314 ​ Embedded derivative assets ​ $ 40,590 ​ ​ — ​ ​ 40,590 ​ $ 32,282 ​ ​ — ​ ​ 32,282 ​ Commodity derivative liabilities ​ $ (199,956) ​ ​ 69,542 ​ ​ (130,414) ​ $ (284,241) ​ ​ 38,577 ​ ​ (245,664) ​ ​ The following is a summary of derivative fair value gains and losses and where such values are recorded in the unaudited condensed consolidated statements of operations for the three March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Statement of ​ ​ ​ ​ ​ Operations ​ Three Months Ended March 31, ​ ​ Location ​ 2020 ​ 2021 ​ Commodity derivative fair value gains (losses) ​ Revenue ​ $ 565,833 ​ ​ (169,967) ​ Embedded derivative fair value gains (losses) ​ Revenue ​ $ — ​ ​ (7,789) ​ ​ The fair value of derivative instruments was determined using Level 2 inputs.

Leases

Leases	3 Months Ended
	Mar. 31, 2021
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 lease 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 as of December 31, 2020 and March 31, 2021 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ Leases Balance Sheet Classification 2020 2021 ​ Operating Leases ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating lease right-of-use assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ Processing plants ​ Operating lease right-of-use assets ​ $ 1,302,290 ​ ​ 1,279,755 ​ Drilling rigs and completion services ​ Operating lease right-of-use assets ​ ​ 29,894 ​ ​ 22,632 ​ Gas gathering lines and compressor stations (1) ​ Operating lease right-of-use assets ​ ​ 1,241,090 ​ ​ 1,208,252 ​ Office space ​ Operating lease right-of-use assets ​ ​ 36,879 ​ ​ 35,959 ​ Vehicles ​ Operating lease right-of-use assets ​ ​ 2,704 ​ ​ 2,024 ​ Other office and field equipment ​ Operating lease right-of-use assets ​ ​ 746 ​ ​ 675 ​ Total operating lease right-of-use assets ​ ​ ​ $ 2,613,603 ​ ​ 2,549,297 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Short-term operating lease obligation ​ Short-term lease liabilities ​ $ 265,178 ​ ​ 264,858 ​ Long-term operating lease obligation ​ Long-term lease liabilities ​ ​ 2,348,425 ​ ​ 2,284,439 ​ Total operating lease obligation ​ ​ ​ $ 2,613,603 ​ ​ 2,549,297 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Finance Leases ​ ​ ​ ​ ​ ​ ​ ​ ​ Finance lease right-of-use assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ Vehicles ​ Other property and equipment ​ $ 1,206 ​ ​ 934 ​ Total finance lease right-of-use assets (2) ​ ​ ​ $ 1,206 ​ ​ 934 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Short-term finance lease obligation ​ Short-term lease liabilities ​ $ 845 ​ ​ 693 ​ Long-term finance lease obligation ​ Long-term lease liabilities ​ ​ 361 ​ ​ 241 ​ Total finance lease obligation ​ ​ ​ $ 1,206 ​ ​ 934 ​ (1) Gas gathering lines and compressor stations leases includes $1.1 billion related to Antero Midstream Corporation as of December 31, 2020 and March 31, 2021 . See “—Related party lease disclosure” for additional discussion. (2) Financing lease assets are recorded net of accumulated amortization of $3 million as of both December 31, 2020 and March 31, 2021. ​ Leases ​ (b) Supplemental Information Related to Leases Costs associated with operating leases were included in the unaudited condensed consolidated statement of operations and comprehensive loss for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ ​ ​ ​ ​ ​ ​ March 31, ​ Cost Classification Location 2020 2021 ​ Operating lease cost ​ Statement of operations ​ Gathering, compression, processing, and transportation ​ $ 352,643 ​ ​ 376,930 ​ Operating lease cost ​ Statement of operations ​ General and administrative ​ ​ 2,881 ​ ​ 2,488 ​ Operating lease cost ​ Statement of operations ​ Lease operating ​ ​ — ​ ​ 22 ​ Operating lease cost ​ Balance sheet ​ Proved properties (1) ​ ​ 32,994 ​ ​ 28,759 ​ Total operating lease cost ​ ​ ​ ​ ​ $ 388,518 ​ ​ 408,199 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Finance lease cost: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Amortization of right-of-use assets ​ Statement of operations ​ Depletion, depreciation, and amortization ​ $ 145 ​ ​ 127 ​ Interest on lease liabilities ​ Statement of operations ​ Interest expense ​ ​ 36 ​ ​ 28 ​ Total finance lease cost ​ ​ ​ ​ ​ $ 181 ​ ​ 155 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Short-term lease payments ​ ​ ​ ​ ​ $ 62,717 ​ ​ 16,842 ​ (1) Capitalized costs related to drilling and completion activities. ​ (c) Supplemental Cash Flow Information Related to Leases The following is the Company’s supplemental cash flow information related to leases for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ 2020 2021 ​ Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ ​ ​ ​ ​ Operating cash flows from operating leases ​ $ 358,039 ​ ​ 388,983 ​ Investing cash flows from operating leases ​ ​ 27,534 ​ ​ 24,027 ​ Financing cash flows from finance leases ​ ​ 439 ​ ​ 265 ​ ​ ​ ​ ​ ​ ​ ​ ​ Noncash activities: ​ ​ ​ ​ ​ ​ ​ Right-of-use assets obtained in exchange for new operating lease obligations ​ $ 9,382 ​ ​ 28 ​ ​ (d) Maturities of Lease Liabilities The table below is a schedule of future minimum payments for operating and financing lease liabilities as of March 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2021 ​ $ 457,065 ​ ​ 612 ​ ​ 457,677 ​ 2022 ​ ​ 579,086 ​ ​ 366 ​ ​ 579,452 ​ 2023 ​ ​ 575,235 ​ ​ 9 ​ ​ 575,244 ​ 2024 ​ ​ 566,467 ​ ​ — ​ ​ 566,467 ​ 2025 ​ ​ 493,790 ​ ​ — ​ ​ 493,790 ​ 2026 ​ ​ 442,971 ​ ​ — ​ ​ 442,971 ​ Thereafter ​ ​ 1,115,499 ​ ​ — ​ ​ 1,115,499 ​ Total lease payments ​ ​ 4,230,113 ​ ​ 987 ​ ​ 4,231,100 ​ Less: imputed interest ​ ​ (1,680,816) ​ ​ (53) ​ ​ (1,680,869) ​ Total ​ $ 2,549,297 ​ ​ 934 ​ ​ 2,550,231 ​ ​ (e) Lease Term and Discount Rate The following table sets forth the Company’s weighted-average remaining lease term and discount rate as of December 31, 2020 and March 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ March 31, 2021 ​ ​ ​ ​ Operating Leases ​ Finance Leases ​ Operating Leases ​ Finance Leases ​ ​ Weighted-average remaining lease term ​ 8.0 years ​ 1.5 years ​ 7.7 years ​ 1.3 years ​ ​ Weighted-average discount rate ​ 13.7 % 6.2 % 13.8 % 6.2 % ​ ​ (f) Related Party Lease Disclosure The Company has a gathering and compression agreement with Antero Midstream Corporation, whereby Antero Midstream Corporation 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 adjustments based on the consumer price index. If and to the extent the Company requests that Antero Midstream Corporation construct new high pressure lines and compressor stations, the gathering and compression agreement contains minimum volume commitments that require Antero Resources to utilize or pay for . In December 2019, the Company and Antero Midstream Corporation 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 Corporation on or before the 180 th day prior to the anniversary of such effective date. The Company achieved the volumetric targets during the first quarter of 2020, and Antero Midstream Corporation provided a rebate of $12 million for the three months ended March 31, 2020. The Company did not achieve the volumetric target during the first quarter of 2021. ​ For the three months ended March 31, 2020 and 2021, gathering and compression fees paid by Antero related to this agreement were $156 million and $177 million, respectively. As of

Commitments

Commitments	3 Months Ended
	Mar. 31, 2021
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 remaining lease terms in excess of one year as of March 31, 2021 (in thousands). ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Processing, ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Firm ​ Gathering and ​ Land Payment ​ Operating and ​ Imputed Interest ​ ​ ​ ​ ​ Transportation ​ Compression ​ Obligations ​ Financing Leases ​ for Leases ​ ​ ​ ​ (a) (b) (c) (d) (d) Total Remainder of 2021 ​ $ 816,349 ​ ​ 41,199 ​ ​ 2,576 ​ ​ 201,248 ​ ​ 256,429 ​ ​ 1,317,801 ​ 2022 ​ ​ 1,042,065 ​ ​ 52,265 ​ ​ 400 ​ ​ 267,895 ​ ​ 311,557 ​ ​ 1,674,182 ​ 2023 ​ ​ 1,072,312 ​ ​ 59,140 ​ ​ — ​ ​ 300,977 ​ ​ 274,267 ​ ​ 1,706,696 ​ 2024 ​ ​ 1,045,230 ​ ​ 59,262 ​ ​ — ​ ​ 334,699 ​ ​ 231,768 ​ ​ 1,670,959 ​ 2025 ​ ​ 1,024,573 ​ ​ 47,960 ​ ​ — ​ ​ 306,925 ​ ​ 186,865 ​ ​ 1,566,323 ​ 2026 ​ ​ 1,018,610 ​ ​ 14,783 ​ ​ — ​ ​ 299,354 ​ ​ 143,617 ​ ​ 1,476,364 ​ Thereafter ​ ​ 6,027,905 ​ ​ 98,596 ​ ​ — ​ ​ 839,133 ​ ​ 276,366 ​ ​ 7,242,000 ​ Total ​ $ 12,047,044 ​ ​ 373,205 ​ ​ 2,976 ​ ​ 2,550,231 ​ ​ 1,680,869 ​ ​ 16,654,325 ​ ​ (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, and Compression Service Commitments The Company has entered into various long- term gas processing, gathering and compression 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. Refer to Note 12—Leases to the unaudited condensed consolidated financial statements for more information on the Company’s operating and finance leases.

Contingencies

Contingencies	3 Months Ended
	Mar. 31, 2021
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 the EPA Region V related to similar issues being investigated by the EPA Region III. The Company continues to negotiate with the EPA overall 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 two lawsuits were consolidated and tried in June 2019. On June 20, 2019, the Company was awarded a jury verdict of approximately $96 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 $107 million from WGL, which was in full satisfaction and discharge of the June 2019 judgment entered in favor of the Company. 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. ​

Related Parties

Related Parties	3 Months Ended
	Mar. 31, 2021
Related Parties
Related Parties	(15) Related Parties Substantially all of Antero Midstream Corporation’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	3 Months Ended
	Mar. 31, 2021
Reportable Segments
Reportable Segments	(16) Reportable Segments Management evaluated how the Company is organized and managed and identified the following 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 Corporation. All of the Company’s assets are located in the United States and substantially all of its 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. Operating segments are evaluated based on their contribution to consolidated results, which is primarily determined by the respective operating income (loss) of each segment. 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. The operating results and assets of the Company’s reportable segments were as follows for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, 2020 ​ ​ ​ ​ ​ ​ ​ Equity Method ​ Elimination of ​ ​ ​ ​ ​ ​ ​ ​ ​ Investment in ​ Intersegment ​ ​ ​ ​ ​ Exploration ​ ​ ​ Antero ​ Transactions and ​ ​ ​ ​ ​ and ​ ​ ​ Midstream ​ Unconsolidated ​ Consolidated ​ ​ Production Marketing Corporation Affiliates Total ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,270,234 ​ ​ 46,073 ​ ​ — ​ ​ — ​ ​ 1,316,307 ​ Intersegment ​ 798 ​ ​ — ​ ​ 243,708 ​ ​ (243,708) ​ ​ 798 ​ Total ​ $ 1,271,032 ​ ​ 46,073 ​ ​ 243,708 ​ ​ (243,708) ​ ​ 1,317,105 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 25,644 ​ ​ — ​ ​ — ​ ​ — ​ ​ 25,644 ​ Gathering, compression, processing, and transportation ​ ​ 588,624 ​ ​ — ​ ​ 55,908 ​ ​ (55,908) ​ ​ 588,624 ​ Impairment of oil and gas properties ​ ​ 89,220 ​ ​ — ​ ​ — ​ ​ — ​ ​ 89,220 ​ Impairment of midstream assets ​ ​ — ​ ​ — ​ ​ 664,544 ​ ​ (664,544) ​ ​ — ​ Depletion, depreciation, and amortization ​ ​ 199,677 ​ ​ — ​ ​ 27,343 ​ ​ (27,343) ​ ​ 199,677 ​ General and administrative ​ ​ 31,221 ​ ​ — ​ ​ 13,537 ​ ​ (13,537) ​ ​ 31,221 ​ Other ​ ​ 27,013 ​ ​ 93,273 ​ ​ 4,836 ​ ​ (4,836) ​ ​ 120,286 ​ Total ​ ​ 961,399 ​ ​ 93,273 ​ ​ 766,168 ​ ​ (766,168) ​ ​ 1,054,672 ​ Operating income (loss) ​ $ 309,633 ​ ​ (47,200) ​ ​ (522,460) ​ ​ 522,460 ​ ​ 262,433 ​ Equity in earnings (loss) of unconsolidated affiliates ​ $ (128,055) ​ ​ — ​ ​ 19,077 ​ ​ (19,077) ​ ​ (128,055) ​ Investments in unconsolidated affiliates ​ $ 291,989 ​ ​ — ​ ​ 716,778 ​ ​ (716,778) ​ ​ 291,989 ​ Segment assets ​ $ 14,516,150 ​ ​ 9,639 ​ ​ 5,781,359 ​ ​ (5,781,359) ​ ​ 14,525,789 ​ Capital expenditures for segment assets ​ $ 311,611 ​ ​ — ​ ​ 67,983 ​ ​ (67,983) ​ ​ 311,611 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, 2021 ​ ​ ​ ​ ​ ​ ​ Equity Method ​ Elimination of ​ ​ ​ ​ ​ ​ ​ ​ ​ Investment in ​ Intersegment ​ ​ ​ ​ ​ Exploration ​ ​ ​ Antero ​ Transactions and ​ ​ ​ ​ ​ and ​ ​ ​ Midstream ​ Unconsolidated ​ Consolidated ​ ​ Production Marketing Corporation Affiliates Total ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,038,768 ​ ​ 164,790 ​ ​ — ​ ​ — ​ ​ 1,203,558 ​ Intersegment ​ 640 ​ ​ — ​ ​ 224,121 ​ ​ (224,121) ​ ​ 640 ​ Total ​ $ 1,039,408 ​ ​ 164,790 ​ ​ 224,121 ​ ​ (224,121) ​ ​ 1,204,198 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 24,547 ​ ​ — ​ ​ — ​ ​ — ​ ​ 24,547 ​ Gathering, compression, processing, and transportation ​ ​ 605,077 ​ ​ — ​ ​ 39,314 ​ ​ (39,314) ​ ​ 605,077 ​ Impairment of oil and gas properties ​ ​ 34,062 ​ ​ — ​ ​ — ​ ​ — ​ ​ 34,062 ​ Impairment of midstream assets ​ ​ — ​ ​ — ​ ​ 1,379 ​ ​ (1,379) ​ ​ — ​ Depletion, depreciation, and amortization ​ ​ 194,026 ​ ​ — ​ ​ 26,850 ​ ​ (26,850) ​ ​ 194,026 ​ General and administrative ​ ​ 44,074 ​ ​ — ​ ​ 17,930 ​ ​ (17,930) ​ ​ 44,074 ​ Other ​ ​ 45,795 ​ ​ 162,077 ​ ​ 5,061 ​ ​ (5,061) ​ ​ 207,872 ​ Total ​ ​ 947,581 ​ ​ 162,077 ​ ​ 90,534 ​ ​ (90,534) ​ ​ 1,109,658 ​ Operating income ​ $ 91,827 ​ ​ 2,713 ​ ​ 133,587 ​ ​ (133,587) ​ ​ 94,540 ​ Equity in earnings of unconsolidated affiliates ​ $ 18,694 ​ ​ — ​ ​ 20,744 ​ ​ (20,744) ​ ​ 18,694 ​ Investments in unconsolidated affiliates ​ $ 241,158 ​ ​ — ​ ​ 712,069 ​ ​ (712,069) ​ ​ 241,158 ​ Segment assets ​ $ 13,000,382 ​ ​ — ​ ​ 5,546,760 ​ ​ (5,546,760) ​ ​ 13,000,382 ​ Capital expenditures for segment assets ​ $ 123,158 ​ ​ — ​ ​ 28,389 ​ ​ (28,389) ​ ​ 123,158 ​ ​

Subsidiary Guarantors

Subsidiary Guarantors	3 Months Ended
	Mar. 31, 2021
Subsidiary Guarantors
Subsidiary Guarantors	(17) Subsidiary Guarantors Each of the Company’s wholly owned subsidiaries has fully and unconditionally guaranteed Antero Resources’ senior notes. 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 following tables present summarized financial information of Antero and its guarantor subsidiaries (in thousands). The Company’s wholly owned subsidiaries are not restricted from making distributions to the Company. ​ ​ ​ ​ ​ ​ Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ March 31, 2021 ​ ​ ​ Parent (Antero) ​ ​ and Guarantor Subsidiaries ​ Accounts receivable, non-guarantor subsidiaries ​ $ 51,000 ​ Accounts receivable, related parties ​ ​ — ​ Other current assets ​ ​ 505,539 ​ Total current assets ​ ​ 556,539 ​ Noncurrent assets ​ ​ 11,636,099 ​ Total assets ​ $ 12,192,638 ​ ​ ​ ​ ​ ​ Accounts payable, non-guarantor subsidiaries ​ $ — ​ Accounts payable, related parties ​ ​ 85,846 ​ Other current liabilities ​ ​ 1,121,886 ​ Total current liabilities ​ ​ 1,207,732 ​ Noncurrent liabilities ​ ​ 5,540,027 ​ Total liabilities ​ $ 6,747,759 ​ ​ ​ ​ ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, 2021 ​ ​ ​ Parent (Antero) ​ ​ and Guarantor Subsidiaries ​ Revenues ​ $ 1,189,088 ​ Operating expenses ​ ​ 1,098,943 ​ Income from operations ​ ​ 90,145 ​ Net loss and comprehensive loss including noncontrolling interests ​ ​ (15,499) ​ Net loss and comprehensive loss attributable to Antero Resources Corporation ​ $ (15,499) ​ ​

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2021
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, 2020 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, 2020 consolidated financial statements were included in Antero Resources’ 2020 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, 2020 and March 31, 2021 and its results of operations and cash flows for the three months ended March 31, 2020 and 2021. 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 March 31, 2021 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, any entities in which the Company owns a controlling interest, and variable interest entities (“VIEs”) for which the Company is the primary beneficiary, including Martica Holdings LLC (“Martica”). The noncontrolling interest reflected in the Company’s unaudited condensed consolidated financial statements for the three months ended March 31, 2021 represents the Company’s interest in Martica owned by third parties.
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 unaudited 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 March 31, 2021, the book overdrafts included within accounts payable and revenue distributions payable were $12 million and $23 million, respectively. As of December 31, 2020, the book overdrafts included within accounts payable and revenue distributions payable were $11 million and $15 million, respectively.
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 outstanding equity awards and shares of common stock issuable upon conversion of the 2026 Convertible Notes (as defined below in Note 7—Long-Term Debt), calculated using the treasury stock method. The Company includes restricted stock unit (“RSUs”) awards, performance share unit (“PSUs”) 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 effect of all equity awards is anti-dilutive. 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 March 31, ​ ​ 2020 2021 ​ Basic weighted average number of shares outstanding ​ 284,227 ​ 296,746 ​ Add: Dilutive effect of RSUs ​ — ​ — ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ Add: Dilutive effect of PSUs ​ — ​ — ​ Add: Dilutive effect of 2026 Convertible Notes ​ — ​ — ​ Diluted weighted average number of shares outstanding ​ 284,227 ​ 296,746 ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ RSUs ​ 5,952 ​ 6,455 ​ Outstanding stock options ​ 459 ​ 427 ​ PSUs ​ 1,621 ​ 1,863 ​ 2026 Convertible Notes ​ — ​ 15,307 ​ (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. ​
Recently Issued Accounting Standards	(e) Recently Issued Accounting Standards Convertible 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 require separate accounting for conversion features, and instead, allows the debt instrument and conversion features to be accounted for as a single debt instrument. The new standard becomes effective for the Company on January 1, 2022, and early adoption is permitted. The Company Upon adoption of this new standard, the Company expects to reclassify $15 million, net of deferred income taxes and equity issuance costs, to long-term debt and deferred income tax liability, as applicable, from stockholders’ equity, which amount is subject to adjustment for any conversions or other transactions until adoption of this new standard. Additionally, annual interest expense for the 2026 Convertible Notes will be based on an effective interest rate of . T he Company does not believe that adoption of the standard will impact its operational strategies or development prospects . ​ Income Taxes ​ In December 2019, the FASB issued ASU No. 2019-12, Simplifying the Accounting for Income Taxes . Income Taxes (“ASC 740”) and also simplifies portions of ASC 740 by clarifying and amending existing guidance. It is effective for interim and annual reporting periods after December 15, 2020. The Company adopted this ASU on January 1, 2021, and it did not have a material impact on the Company's unaudited condensed consolidated financial statements .

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2021
Summary of Significant Accounting Policies
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 March 31, ​ ​ 2020 2021 ​ Basic weighted average number of shares outstanding ​ 284,227 ​ 296,746 ​ Add: Dilutive effect of RSUs ​ — ​ — ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ Add: Dilutive effect of PSUs ​ — ​ — ​ Add: Dilutive effect of 2026 Convertible Notes ​ — ​ — ​ Diluted weighted average number of shares outstanding ​ 284,227 ​ 296,746 ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding securities excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ RSUs ​ 5,952 ​ 6,455 ​ Outstanding stock options ​ 459 ​ 427 ​ PSUs ​ 1,621 ​ 1,863 ​ 2026 Convertible Notes ​ — ​ 15,307 ​ (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)	3 Months Ended
	Mar. 31, 2021
Revenue
Schedule of disaggregation of revenue	The table set forth below presents revenue disaggregated by type and the reportable segment to which it relates (in thousands). See Note 16—Reportable Segments for more information on reportable segments. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ ​ ​ 2020 2021 Reportable Segment ​ Revenues from contracts with customers: ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 411,082 ​ ​ 720,369 ​ Exploration and production ​ Natural gas liquids sales (ethane) ​ ​ 26,796 ​ ​ 36,110 ​ Exploration and production ​ Natural gas liquids sales (C3+ NGLs) ​ ​ 230,877 ​ ​ 404,209 ​ Exploration and production ​ Oil sales ​ ​ 35,646 ​ ​ 44,686 ​ Exploration and production ​ Marketing ​ ​ 46,073 ​ ​ 164,790 ​ Marketing ​ Total revenue from contracts with customers ​ ​ 750,474 ​ ​ 1,370,164 ​ ​ ​ Income from derivatives, deferred revenue and other sources ​ ​ 566,631 ​ ​ (165,966) ​ ​ ​ Total revenue ​ $ 1,317,105 ​ ​ 1,204,198 ​ ​ ​

Equity Method Investments (Tabl

Equity Method Investments (Tables)	3 Months Ended
	Mar. 31, 2021
Equity Method Investments
Schedule of reconciliation of investments in unconsolidated affiliates	The following table sets forth a reconciliation of Antero’s investment in unconsolidated affiliate for the three months ended March 31, 2021 (in thousands): ​ ​ ​ ​ ​ Balance as of December 31, 2020 (1) ​ $ 255,082 ​ Equity in loss of unconsolidated affiliate ​ ​ 18,694 ​ Dividends from unconsolidated affiliate ​ ​ (42,756) ​ Elimination of intercompany profit ​ ​ 10,138 ​ Balance as of March 31, 2021 (1) ​ $ 241,158 ​ (1) The Company’s investment in Antero Midstream Corporation as of December 31, 2020 and March 31, 2021 was $1.1 billion and $1.3 billion, respectively, based on the quoted market share price of Antero Midstream Corporation .
Antero Midstream Corporation
Equity Method Investments
Schedule of summarized financial information	The tables set forth below present summarized financial information of Antero Midstream Corporation (in thousands). Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ 2020 2021 ​ Current assets ​ $ 93,931 ​ ​ 91,167 ​ Noncurrent assets ​ ​ 5,516,981 ​ ​ 5,455,593 ​ Total assets ​ $ 5,610,912 ​ ​ 5,546,760 ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 94,005 ​ ​ 79,750 ​ Noncurrent liabilities ​ ​ 3,098,621 ​ ​ 3,110,144 ​ Stockholders' equity ​ ​ 2,418,286 ​ ​ 2,356,866 ​ Total liabilities and stockholders' equity ​ $ 5,610,912 ​ ​ 5,546,760 ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ 2020 2021 ​ Revenues ​ $ 243,708 ​ ​ 224,121 ​ Operating expenses ​ ​ 762,872 ​ ​ 90,534 ​ Income (loss) from operations ​ ​ (519,164) ​ ​ 133,587 ​ Income (loss) attributable to the equity method investment ​ ​ (392,933) ​ ​ 83,441 ​

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2021
Accrued Liabilities
Schedule of accrued liabilities	Accrued liabilities as of December 31, 2020 and March 31, 2021 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ 2020 2021 ​ Capital expenditures ​ $ 32,372 ​ 44,476 ​ Gathering, compression, processing, and transportation expenses ​ ​ 152,724 ​ ​ 149,266 ​ Marketing expenses ​ ​ 68,193 ​ ​ 59,396 ​ Interest expense, net ​ 25,645 ​ 39,049 ​ Accrued taxes ​ ​ 40,796 ​ ​ 24,386 ​ Other ​ 23,794 ​ 34,190 ​ Total accrued liabilities ​ $ 343,524 ​ 350,763 ​

Long-Term Debt (Tables)

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2021
Schedule of long-term debt	Long-term debt as of December 31, 2020 and March 31, 2021 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ 2020 2021 ​ Credit Facility (a) ​ $ 1,017,000 ​ ​ 143,200 ​ 5.125% senior notes due 2022 (b) ​ ​ 660,516 ​ ​ — ​ 5.625% senior notes due 2023 (c) ​ ​ 574,182 ​ ​ 574,182 ​ 5.00% senior notes due 2025 (d) ​ ​ 590,000 ​ ​ 590,000 ​ 8.375% senior notes due 2026 (e) ​ ​ — ​ ​ 500,000 ​ 7.625% senior notes due 2029 (f) ​ ​ — ​ ​ 700,000 ​ 4.25% convertible senior notes due 2026 (g) ​ ​ 287,500 ​ ​ 137,500 ​ Total principal ​ ​ 3,129,198 ​ ​ 2,644,882 ​ Unamortized premium (discount), net ​ ​ (111,886) ​ ​ (51,669) ​ Unamortized debt issuance costs ​ ​ (15,719) ​ ​ (24,527) ​ Long-term debt ​ $ 3,001,593 ​ ​ 2,568,686 ​
4.25% convertible senior notes due 2026
Schedule of long-term debt	The 2026 Convertible Notes consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ ​ ​ 2020 ​ 2021 ​ Liability component: ​ ​ ​ ​ ​ ​ ​ Principal ​ $ 287,500 ​ ​ 137,500 ​ Less: unamortized note discount ​ ​ (112,265) ​ ​ (51,669) ​ Less: unamortized debt issuance costs ​ ​ (5,852) ​ ​ (3,029) ​ Net carrying value ​ $ 169,383 ​ ​ 82,802 ​ Equity component (1) ​ $ 115,601 ​ ​ (14,755) ​ (1) As of December 31, 2020, the equity component of the 2026 Convertible Notes was recorded in additional paid-in capital, net of $3 million of issuance costs and $28 million of deferred taxes. As a result of the Equitization Transactions during the first quarter of 2021, the Company repurchased a portion of the equity component for $116 million, net of $14 million of deferred taxes. ​

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2021
Asset Retirement Obligations
Schedule of reconciliation of asset retirement obligations	The following table sets forth a reconciliation of the Company’s asset retirement obligations for the three months ended March 31, 2021 (in thousands): ​ ​ ​ ​ ​ Asset retirement obligations—December 31, 2020 $ 54,452 ​ Obligations incurred ​ 70 ​ Accretion expense ​ ​ 788 ​ Asset retirement obligations—March 31, 2021 ​ $ 55,310 ​

Equity-Based Compensation and_2

Equity-Based Compensation and Cash Awards (Tables)	3 Months Ended
	Mar. 31, 2021
Schedule of equity-based compensation expense	The Company’s equity-based compensation expense, by type of award, was as follows for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ 2020 ​ 2021 ​ RSU awards ​ $ 1,878 ​ ​ 3,238 ​ PSU awards ​ ​ 922 ​ ​ 1,536 ​ Antero Midstream Partners phantom unit awards (1) ​ ​ 160 ​ ​ 518 ​ Equity awards issued to directors ​ ​ 369 ​ ​ 350 ​ Total expense ​ $ 3,329 ​ ​ 5,642 ​ (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 the deconsolidation of Antero Midstream Partners on March 12, 2019 to Antero Midstream Partners based on its proportionate share of Antero Resources’ labor costs.
Summary of restricted stock unit awards activity	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ Average ​ ​ ​ Number of ​ Grant Date ​ ​ Shares Fair Value ​ Total awarded and unvested—December 31, 2020 ​ 8,432,397 ​ $ 4.06 ​ Granted ​ 14,738 ​ ​ 7.26 ​ Vested ​ (1,906,286) ​ ​ 2.70 ​ Forfeited ​ (83,359) ​ ​ 4.82 ​ Total awarded and unvested—March 31, 2021 ​ 6,457,490 ​ $ 4.46 ​
Summary of stock option activity	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ Weighted ​ Average ​ ​ ​ ​ ​ ​ ​ Average ​ Remaining ​ Intrinsic ​ ​ ​ Stock ​ Exercise ​ Contractual ​ Value ​ ​ Options Price Life (in thousands) ​ Outstanding—December 31, 2020 ​ 432,461 ​ $ 50.64 ​ 4.1 ​ $ — ​ Granted ​ — ​ ​ — ​ ​ ​ ​ ​ ​ Exercised ​ — ​ ​ — ​ ​ ​ ​ ​ ​ Forfeited ​ — ​ ​ — ​ ​ ​ ​ ​ ​ Expired ​ (5,000) ​ ​ 50.00 ​ ​ ​ ​ ​ ​ Outstanding—March 31, 2021 ​ 427,461 ​ $ 50.65 ​ 3.8 ​ $ — ​ Vested—March 31, 2021 ​ 427,461 ​ $ 50.65 ​ 3.8 ​ $ — ​ Exercisable —March 31, 2021 ​ 427,461 ​ $ 50.65 ​ 3.8 ​ $ — ​
Summary of Performance Share Unit activity	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ Number of ​ Average Grant ​ ​ Units Date Fair Value ​ Total awarded and unvested—December 31, 2020 ​ 2,547,798 ​ $ 12.66 ​ Granted ​ — ​ ​ — ​ Forfeited ​ (23,283) ​ ​ 9.26 ​ Cancelled (unearned) ​ (133,334) ​ ​ 25.64 ​ Total awarded and unvested—March 31, 2021 ​ 2,391,181 ​ $ 11.97 ​
Antero Midstream Corporation
Schedule of outstanding unvested restricted stock awards vesting schedule	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ Average ​ ​ ​ Number of ​ Grant Date ​ ​ Units Fair Value ​ Total awarded and unvested—December 31, 2020 ​ 296,390 ​ $ 15.06 ​ Granted ​ — ​ ​ ​ ​ Vested ​ (10,122) ​ ​ 15.81 ​ Forfeited ​ — ​ ​ ​ ​ Total awarded and unvested—March 31, 2021 ​ 286,268 ​ $ 15.04 ​

Fair value (Tables)

Fair value (Tables)	3 Months Ended
	Mar. 31, 2021
Fair Value
Schedule of fair value and carrying value of the senior notes and 2026 Convertible Notes	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ March 31, 2021 ​ ​ Fair Carrying Fair Carrying ​ ​ ​ Value (1) ​ Value (2) ​ Value (1) ​ Value (2) ​ 5.125% senior notes due 2022 ​ $ 658,468 ​ ​ 658,400 ​ ​ — ​ ​ — ​ 5.625% senior notes due 2023 ​ ​ 562,698 ​ ​ 571,370 ​ ​ 576,077 ​ ​ 571,644 ​ 5.00% senior notes due 2025 ​ ​ 560,500 ​ ​ 585,440 ​ ​ 590,413 ​ ​ 585,687 ​ 8.375% senior notes due 2026 ​ ​ — ​ ​ — ​ ​ 551,250 ​ ​ 494,209 ​ 7.625% senior notes due 2029 ​ ​ — ​ ​ — ​ ​ 742,840 ​ ​ 691,144 ​ 4.25% convertible senior notes due 2026 ​ ​ 430,963 ​ ​ 169,383 ​ ​ 347,999 ​ ​ 82,802 ​ Total ​ $ 2,212,629 ​ ​ 1,984,593 ​ ​ 2,808,579 ​ ​ 2,425,486 ​ (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)	3 Months Ended
	Mar. 31, 2021
Schedule of outstanding commodity derivatives	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ ​ Average ​ Commodity / Settlement Period Index Contracted Volume Price Natural Gas ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Henry Hub ​ 2,160,000 MMBtu/day ​ $ 2.76 /MMBtu ​ January-December 2022 ​ Henry Hub ​ 1,155,486 MMBtu/day ​ ​ 2.50 /MMBtu ​ January-December 2023 ​ Henry Hub ​ 43,000 MMBtu/day ​ ​ 2.37 /MMBtu ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Propane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Propane-OPIS TET ​ 16,655 Bbl/day ​ $ 30.64 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Butane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Butane-OPIS Non-TET ​ 3,331 Bbl/day ​ $ 33.42 /Bbl ​ April-December 2021 ​ Mont Belvieu Butane-OPIS TET ​ 1,415 Bbl/day ​ $ 31.36 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural Gasoline ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 8,617 Bbl/day ​ $ 51.19 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Isobutane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-June 2021 ​ Mont Belvieu Isobutane-OPIS Non-TET ​ 662 Bbl/day ​ $ 33.30 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ West Texas Intermediate ​ 3,000 Bbl/day ​ $ 55.16 /Bbl ​
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 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ NYMEX to TCO ​ 40,000 MMBtu/day ​ $ 0.414 /MMBtu ​ January-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 ​
Schedule of commodity derivatives basis differential positions which settle on the pricing index to basis differential of Columbia Gas (TCO) to the NYMEX Henry Hub natural gas price.	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted Average ​ Commodity / Settlement Period Index to Basis Differential Contracted Volume Payout Ratio ​ Gas Liquids ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Natural Gasoline to WTI ​ 9,325 Bbl/day ​ 78 % ​
Summary of the fair values of derivative instruments, which are not designated as hedges for accounting purposes	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Balance Sheet ​ December 31, ​ March 31, ​ ​ Location 2020 ​ 2021 ​ Asset derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives—current ​ Derivative instruments ​ $ 97,144 ​ ​ 36,633 ​ Embedded derivatives—current ​ Derivative instruments ​ ​ 7,986 ​ ​ 4,723 ​ Commodity derivatives—noncurrent ​ Derivative instruments ​ ​ 14,689 ​ ​ 15,681 ​ Embedded derivatives—noncurrent ​ Derivative instruments ​ ​ 32,604 ​ ​ 27,559 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total asset derivatives ​ ​ ​ ​ 152,423 ​ ​ 84,596 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liability derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives—current (1) ​ Derivative instruments ​ ​ 31,242 ​ ​ 146,720 ​ Commodity derivatives—noncurrent (1) ​ Derivative instruments ​ ​ 99,172 ​ ​ 98,944 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total liability derivatives ​ ​ ​ ​ 130,414 ​ ​ 245,664 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net derivatives assets (liabilities) ​ ​ ​ $ 22,009 ​ ​ (161,068) ​ (1) As of March 31, 2021, approximately $23 million of commodity derivative liabilities, including $13 million of current commodity derivatives and $10 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. As of December 31, 2020, approximately $14 million of commodity derivative liabilities, including $7 million of current commodity derivatives and $7 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 presents 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 unaudited condensed consolidated balance sheets as of the dates presented, all at fair value (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ March 31, 2021 ​ ​ ​ ​ ​ ​ ​ Net Amounts of ​ ​ ​ ​ ​ Net Amounts of ​ ​ ​ Gross ​ Gross Amounts ​ Assets ​ Gross ​ Gross Amounts ​ Assets ​ ​ ​ Amounts on ​ Offset on ​ (Liabilities) on ​ Amounts on ​ Offset on ​ (Liabilities) on ​ ​ Balance Sheet Balance Sheet Balance Sheet Balance Sheet Balance Sheet Balance Sheet Commodity derivative assets ​ $ 181,375 ​ ​ (69,542) ​ ​ 111,833 ​ $ 90,891 ​ ​ (38,577) ​ ​ 52,314 ​ Embedded derivative assets ​ $ 40,590 ​ ​ — ​ ​ 40,590 ​ $ 32,282 ​ ​ — ​ ​ 32,282 ​ Commodity derivative liabilities ​ $ (199,956) ​ ​ 69,542 ​ ​ (130,414) ​ $ (284,241) ​ ​ 38,577 ​ ​ (245,664) ​
Summary of derivative fair value gains (losses)	The following is a summary of derivative fair value gains and losses and where such values are recorded in the unaudited condensed consolidated statements of operations for the three March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Statement of ​ ​ ​ ​ ​ Operations ​ Three Months Ended March 31, ​ ​ Location ​ 2020 ​ 2021 ​ Commodity derivative fair value gains (losses) ​ Revenue ​ $ 565,833 ​ ​ (169,967) ​ Embedded derivative fair value gains (losses) ​ Revenue ​ $ — ​ ​ (7,789) ​
VIE, Martica
Schedule of outstanding commodity derivatives	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ ​ Average ​ Commodity / Settlement Period Index Contracted Volume Price ​ Natural Gas ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Henry Hub ​ 47,385 MMBtu/day ​ $ 2.61 /MMBtu January-December 2022 ​ Henry Hub ​ 38,356 MMBtu/day ​ ​ 2.39 /MMBtu ​ January-December 2023 ​ Henry Hub ​ 35,615 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 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Ethane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Purity Ethane-OPIS ​ 1,033 Bbl/day ​ $ 7.01 /Bbl ​ January-March 2022 ​ Mont Belvieu Purity Ethane-OPIS ​ 521 Bbl/day ​ ​ 6.68 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Propane ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Propane-OPIS Non-TET ​ 1,149 Bbl/day ​ $ 18.71 /Bbl ​ January-December 2022 ​ Mont Belvieu Propane-OPIS Non-TET ​ 934 Bbl/day ​ ​ 19.20 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural Gasoline ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 354 Bbl/day ​ $ 31.61 /Bbl ​ January-December 2022 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 282 Bbl/day ​ ​ 34.37 /Bbl ​ January-December 2023 ​ Mont Belvieu Natural Gasoline-OPIS Non-TET ​ 247 Bbl/day ​ ​ 40.74 /Bbl ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ April-December 2021 ​ West Texas Intermediate ​ 129 Bbl/day ​ $ 40.86 /Bbl ​ January-December 2022 ​ West Texas Intermediate ​ 112 Bbl/day ​ ​ 43.51 /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)	3 Months Ended
	Mar. 31, 2021
Leases
Summary of supplemental balance sheet information related to leases	The Company’s lease assets and liabilities as of December 31, 2020 and March 31, 2021 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ March 31, ​ Leases Balance Sheet Classification 2020 2021 ​ Operating Leases ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating lease right-of-use assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ Processing plants ​ Operating lease right-of-use assets ​ $ 1,302,290 ​ ​ 1,279,755 ​ Drilling rigs and completion services ​ Operating lease right-of-use assets ​ ​ 29,894 ​ ​ 22,632 ​ Gas gathering lines and compressor stations (1) ​ Operating lease right-of-use assets ​ ​ 1,241,090 ​ ​ 1,208,252 ​ Office space ​ Operating lease right-of-use assets ​ ​ 36,879 ​ ​ 35,959 ​ Vehicles ​ Operating lease right-of-use assets ​ ​ 2,704 ​ ​ 2,024 ​ Other office and field equipment ​ Operating lease right-of-use assets ​ ​ 746 ​ ​ 675 ​ Total operating lease right-of-use assets ​ ​ ​ $ 2,613,603 ​ ​ 2,549,297 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Short-term operating lease obligation ​ Short-term lease liabilities ​ $ 265,178 ​ ​ 264,858 ​ Long-term operating lease obligation ​ Long-term lease liabilities ​ ​ 2,348,425 ​ ​ 2,284,439 ​ Total operating lease obligation ​ ​ ​ $ 2,613,603 ​ ​ 2,549,297 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Finance Leases ​ ​ ​ ​ ​ ​ ​ ​ ​ Finance lease right-of-use assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ Vehicles ​ Other property and equipment ​ $ 1,206 ​ ​ 934 ​ Total finance lease right-of-use assets (2) ​ ​ ​ $ 1,206 ​ ​ 934 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Short-term finance lease obligation ​ Short-term lease liabilities ​ $ 845 ​ ​ 693 ​ Long-term finance lease obligation ​ Long-term lease liabilities ​ ​ 361 ​ ​ 241 ​ Total finance lease obligation ​ ​ ​ $ 1,206 ​ ​ 934 ​ (1) Gas gathering lines and compressor stations leases includes $1.1 billion related to Antero Midstream Corporation as of December 31, 2020 and March 31, 2021 . See “—Related party lease disclosure” for additional discussion. (2) Financing lease assets are recorded net of accumulated amortization of $3 million as of both December 31, 2020 and March 31, 2021.
Summary of costs associated with operating leases	Costs associated with operating leases were included in the unaudited condensed consolidated statement of operations and comprehensive loss for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ ​ ​ ​ ​ ​ ​ March 31, ​ Cost Classification Location 2020 2021 ​ Operating lease cost ​ Statement of operations ​ Gathering, compression, processing, and transportation ​ $ 352,643 ​ ​ 376,930 ​ Operating lease cost ​ Statement of operations ​ General and administrative ​ ​ 2,881 ​ ​ 2,488 ​ Operating lease cost ​ Statement of operations ​ Lease operating ​ ​ — ​ ​ 22 ​ Operating lease cost ​ Balance sheet ​ Proved properties (1) ​ ​ 32,994 ​ ​ 28,759 ​ Total operating lease cost ​ ​ ​ ​ ​ $ 388,518 ​ ​ 408,199 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Finance lease cost: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Amortization of right-of-use assets ​ Statement of operations ​ Depletion, depreciation, and amortization ​ $ 145 ​ ​ 127 ​ Interest on lease liabilities ​ Statement of operations ​ Interest expense ​ ​ 36 ​ ​ 28 ​ Total finance lease cost ​ ​ ​ ​ ​ $ 181 ​ ​ 155 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Short-term lease payments ​ ​ ​ ​ ​ $ 62,717 ​ ​ 16,842 ​ (1) Capitalized costs related to drilling and completion activities.
Summary of supplemental cash flow information related to leases	The following is the Company’s supplemental cash flow information related to leases for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, ​ ​ 2020 2021 ​ Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ ​ ​ ​ ​ Operating cash flows from operating leases ​ $ 358,039 ​ ​ 388,983 ​ Investing cash flows from operating leases ​ ​ 27,534 ​ ​ 24,027 ​ Financing cash flows from finance leases ​ ​ 439 ​ ​ 265 ​ ​ ​ ​ ​ ​ ​ ​ ​ Noncash activities: ​ ​ ​ ​ ​ ​ ​ Right-of-use assets obtained in exchange for new operating lease obligations ​ $ 9,382 ​ ​ 28 ​
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 March 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2021 ​ $ 457,065 ​ ​ 612 ​ ​ 457,677 ​ 2022 ​ ​ 579,086 ​ ​ 366 ​ ​ 579,452 ​ 2023 ​ ​ 575,235 ​ ​ 9 ​ ​ 575,244 ​ 2024 ​ ​ 566,467 ​ ​ — ​ ​ 566,467 ​ 2025 ​ ​ 493,790 ​ ​ — ​ ​ 493,790 ​ 2026 ​ ​ 442,971 ​ ​ — ​ ​ 442,971 ​ Thereafter ​ ​ 1,115,499 ​ ​ — ​ ​ 1,115,499 ​ Total lease payments ​ ​ 4,230,113 ​ ​ 987 ​ ​ 4,231,100 ​ Less: imputed interest ​ ​ (1,680,816) ​ ​ (53) ​ ​ (1,680,869) ​ Total ​ $ 2,549,297 ​ ​ 934 ​ ​ 2,550,231 ​
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 March 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2021 ​ $ 457,065 ​ ​ 612 ​ ​ 457,677 ​ 2022 ​ ​ 579,086 ​ ​ 366 ​ ​ 579,452 ​ 2023 ​ ​ 575,235 ​ ​ 9 ​ ​ 575,244 ​ 2024 ​ ​ 566,467 ​ ​ — ​ ​ 566,467 ​ 2025 ​ ​ 493,790 ​ ​ — ​ ​ 493,790 ​ 2026 ​ ​ 442,971 ​ ​ — ​ ​ 442,971 ​ Thereafter ​ ​ 1,115,499 ​ ​ — ​ ​ 1,115,499 ​ Total lease payments ​ ​ 4,230,113 ​ ​ 987 ​ ​ 4,231,100 ​ Less: imputed interest ​ ​ (1,680,816) ​ ​ (53) ​ ​ (1,680,869) ​ Total ​ $ 2,549,297 ​ ​ 934 ​ ​ 2,550,231 ​
Summary of weighted-average remaining lease term and discount rate	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ March 31, 2021 ​ ​ ​ ​ Operating Leases ​ Finance Leases ​ Operating Leases ​ Finance Leases ​ ​ Weighted-average remaining lease term ​ 8.0 years ​ 1.5 years ​ 7.7 years ​ 1.3 years ​ ​ Weighted-average discount rate ​ 13.7 % 6.2 % 13.8 % 6.2 % ​

Commitments (Tables)

Commitments (Tables)	3 Months Ended
	Mar. 31, 2021
Commitments
Schedule of future minimum payments for firm transportation, drilling rig and completion services, gas processing, gathering and compression, office and equipment agreements, and 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 remaining lease terms in excess of one year as of March 31, 2021 (in thousands). ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Processing, ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Firm ​ Gathering and ​ Land Payment ​ Operating and ​ Imputed Interest ​ ​ ​ ​ ​ Transportation ​ Compression ​ Obligations ​ Financing Leases ​ for Leases ​ ​ ​ ​ (a) (b) (c) (d) (d) Total Remainder of 2021 ​ $ 816,349 ​ ​ 41,199 ​ ​ 2,576 ​ ​ 201,248 ​ ​ 256,429 ​ ​ 1,317,801 ​ 2022 ​ ​ 1,042,065 ​ ​ 52,265 ​ ​ 400 ​ ​ 267,895 ​ ​ 311,557 ​ ​ 1,674,182 ​ 2023 ​ ​ 1,072,312 ​ ​ 59,140 ​ ​ — ​ ​ 300,977 ​ ​ 274,267 ​ ​ 1,706,696 ​ 2024 ​ ​ 1,045,230 ​ ​ 59,262 ​ ​ — ​ ​ 334,699 ​ ​ 231,768 ​ ​ 1,670,959 ​ 2025 ​ ​ 1,024,573 ​ ​ 47,960 ​ ​ — ​ ​ 306,925 ​ ​ 186,865 ​ ​ 1,566,323 ​ 2026 ​ ​ 1,018,610 ​ ​ 14,783 ​ ​ — ​ ​ 299,354 ​ ​ 143,617 ​ ​ 1,476,364 ​ Thereafter ​ ​ 6,027,905 ​ ​ 98,596 ​ ​ — ​ ​ 839,133 ​ ​ 276,366 ​ ​ 7,242,000 ​ Total ​ $ 12,047,044 ​ ​ 373,205 ​ ​ 2,976 ​ ​ 2,550,231 ​ ​ 1,680,869 ​ ​ 16,654,325 ​

Reportable Segments (Tables)

Reportable Segments (Tables)	3 Months Ended
	Mar. 31, 2021
Reportable Segments
Schedule of operating results and assets of reportable segments	The operating results and assets of the Company’s reportable segments were as follows for the three months ended March 31, 2020 and 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, 2020 ​ ​ ​ ​ ​ ​ ​ Equity Method ​ Elimination of ​ ​ ​ ​ ​ ​ ​ ​ ​ Investment in ​ Intersegment ​ ​ ​ ​ ​ Exploration ​ ​ ​ Antero ​ Transactions and ​ ​ ​ ​ ​ and ​ ​ ​ Midstream ​ Unconsolidated ​ Consolidated ​ ​ Production Marketing Corporation Affiliates Total ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,270,234 ​ ​ 46,073 ​ ​ — ​ ​ — ​ ​ 1,316,307 ​ Intersegment ​ 798 ​ ​ — ​ ​ 243,708 ​ ​ (243,708) ​ ​ 798 ​ Total ​ $ 1,271,032 ​ ​ 46,073 ​ ​ 243,708 ​ ​ (243,708) ​ ​ 1,317,105 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 25,644 ​ ​ — ​ ​ — ​ ​ — ​ ​ 25,644 ​ Gathering, compression, processing, and transportation ​ ​ 588,624 ​ ​ — ​ ​ 55,908 ​ ​ (55,908) ​ ​ 588,624 ​ Impairment of oil and gas properties ​ ​ 89,220 ​ ​ — ​ ​ — ​ ​ — ​ ​ 89,220 ​ Impairment of midstream assets ​ ​ — ​ ​ — ​ ​ 664,544 ​ ​ (664,544) ​ ​ — ​ Depletion, depreciation, and amortization ​ ​ 199,677 ​ ​ — ​ ​ 27,343 ​ ​ (27,343) ​ ​ 199,677 ​ General and administrative ​ ​ 31,221 ​ ​ — ​ ​ 13,537 ​ ​ (13,537) ​ ​ 31,221 ​ Other ​ ​ 27,013 ​ ​ 93,273 ​ ​ 4,836 ​ ​ (4,836) ​ ​ 120,286 ​ Total ​ ​ 961,399 ​ ​ 93,273 ​ ​ 766,168 ​ ​ (766,168) ​ ​ 1,054,672 ​ Operating income (loss) ​ $ 309,633 ​ ​ (47,200) ​ ​ (522,460) ​ ​ 522,460 ​ ​ 262,433 ​ Equity in earnings (loss) of unconsolidated affiliates ​ $ (128,055) ​ ​ — ​ ​ 19,077 ​ ​ (19,077) ​ ​ (128,055) ​ Investments in unconsolidated affiliates ​ $ 291,989 ​ ​ — ​ ​ 716,778 ​ ​ (716,778) ​ ​ 291,989 ​ Segment assets ​ $ 14,516,150 ​ ​ 9,639 ​ ​ 5,781,359 ​ ​ (5,781,359) ​ ​ 14,525,789 ​ Capital expenditures for segment assets ​ $ 311,611 ​ ​ — ​ ​ 67,983 ​ ​ (67,983) ​ ​ 311,611 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, 2021 ​ ​ ​ ​ ​ ​ ​ Equity Method ​ Elimination of ​ ​ ​ ​ ​ ​ ​ ​ ​ Investment in ​ Intersegment ​ ​ ​ ​ ​ Exploration ​ ​ ​ Antero ​ Transactions and ​ ​ ​ ​ ​ and ​ ​ ​ Midstream ​ Unconsolidated ​ Consolidated ​ ​ Production Marketing Corporation Affiliates Total ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,038,768 ​ ​ 164,790 ​ ​ — ​ ​ — ​ ​ 1,203,558 ​ Intersegment ​ 640 ​ ​ — ​ ​ 224,121 ​ ​ (224,121) ​ ​ 640 ​ Total ​ $ 1,039,408 ​ ​ 164,790 ​ ​ 224,121 ​ ​ (224,121) ​ ​ 1,204,198 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 24,547 ​ ​ — ​ ​ — ​ ​ — ​ ​ 24,547 ​ Gathering, compression, processing, and transportation ​ ​ 605,077 ​ ​ — ​ ​ 39,314 ​ ​ (39,314) ​ ​ 605,077 ​ Impairment of oil and gas properties ​ ​ 34,062 ​ ​ — ​ ​ — ​ ​ — ​ ​ 34,062 ​ Impairment of midstream assets ​ ​ — ​ ​ — ​ ​ 1,379 ​ ​ (1,379) ​ ​ — ​ Depletion, depreciation, and amortization ​ ​ 194,026 ​ ​ — ​ ​ 26,850 ​ ​ (26,850) ​ ​ 194,026 ​ General and administrative ​ ​ 44,074 ​ ​ — ​ ​ 17,930 ​ ​ (17,930) ​ ​ 44,074 ​ Other ​ ​ 45,795 ​ ​ 162,077 ​ ​ 5,061 ​ ​ (5,061) ​ ​ 207,872 ​ Total ​ ​ 947,581 ​ ​ 162,077 ​ ​ 90,534 ​ ​ (90,534) ​ ​ 1,109,658 ​ Operating income ​ $ 91,827 ​ ​ 2,713 ​ ​ 133,587 ​ ​ (133,587) ​ ​ 94,540 ​ Equity in earnings of unconsolidated affiliates ​ $ 18,694 ​ ​ — ​ ​ 20,744 ​ ​ (20,744) ​ ​ 18,694 ​ Investments in unconsolidated affiliates ​ $ 241,158 ​ ​ — ​ ​ 712,069 ​ ​ (712,069) ​ ​ 241,158 ​ Segment assets ​ $ 13,000,382 ​ ​ — ​ ​ 5,546,760 ​ ​ (5,546,760) ​ ​ 13,000,382 ​ Capital expenditures for segment assets ​ $ 123,158 ​ ​ — ​ ​ 28,389 ​ ​ (28,389) ​ ​ 123,158 ​

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	3 Months Ended
	Mar. 31, 2021
Subsidiary Guarantors
Schedule of condensed consolidating statement of operations	​ ​ ​ ​ ​ ​ Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ March 31, 2021 ​ ​ ​ Parent (Antero) ​ ​ and Guarantor Subsidiaries ​ Accounts receivable, non-guarantor subsidiaries ​ $ 51,000 ​ Accounts receivable, related parties ​ ​ — ​ Other current assets ​ ​ 505,539 ​ Total current assets ​ ​ 556,539 ​ Noncurrent assets ​ ​ 11,636,099 ​ Total assets ​ $ 12,192,638 ​ ​ ​ ​ ​ ​ Accounts payable, non-guarantor subsidiaries ​ $ — ​ Accounts payable, related parties ​ ​ 85,846 ​ Other current liabilities ​ ​ 1,121,886 ​ Total current liabilities ​ ​ 1,207,732 ​ Noncurrent liabilities ​ ​ 5,540,027 ​ Total liabilities ​ $ 6,747,759 ​ ​ ​ ​ ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended March 31, 2021 ​ ​ ​ Parent (Antero) ​ ​ and Guarantor Subsidiaries ​ Revenues ​ $ 1,189,088 ​ Operating expenses ​ ​ 1,098,943 ​ Income from operations ​ ​ 90,145 ​ Net loss and comprehensive loss including noncontrolling interests ​ ​ (15,499) ​ Net loss and comprehensive loss attributable to Antero Resources Corporation ​ $ (15,499) ​

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Accounts Payable
Basis of Presentation
Book overdrafts	$ 12	$ 11
Revenue distributions payable
Basis of Presentation
Book overdrafts	$ 23	$ 15

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - EPS and New Accounting Principle (Details) - USD ($) shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Jan. 01, 2022
Earnings per share and New Accounting Principle
Basic weighted average number of shares outstanding	296,746	284,227
Diluted weighted average number of shares outstanding	296,746	284,227
Accounting Standards Update 2020-06
Earnings per share and New Accounting Principle
Diluted weighted average number of shares outstanding	15,000
Accounting Standards Update 2020-06 | Adjustment Effect
Earnings per share and New Accounting Principle
Diluted weighted average number of shares outstanding	32,000
Effective interest rate	4.80%
Interest rate during the period	15.10%
Accounting Standards Update 2020-06 | Adjustment Effect | Forecast
Earnings per share and New Accounting Principle
Noncurrent liabilities			$ 15
RSUs
Earnings per share and New Accounting Principle
Weighted Average Anti-dilutive Awards	6,455	5,952
Stock options
Earnings per share and New Accounting Principle
Weighted Average Anti-dilutive Awards	427	459
PSUs
Earnings per share and New Accounting Principle
Weighted Average Anti-dilutive Awards	1,863	1,621
4.25% convertible senior notes due 2026
Earnings per share and New Accounting Principle
Weighted Average Anti-dilutive Awards	15,307

Transactions (Details)

Transactions (Details) ft in Thousands, $ in Millions	Aug. 10, 2020USD ($)	Jul. 01, 2020MMBTU	Jun. 15, 2020USD ($)ft	Jun. 30, 2021USD ($)	Mar. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Feb. 17, 2021
Transactions
Initial PDP Override (as a percent)			1.25%
Development Override (as a percent)			3.75%
Horizontal wells turned to sales, threshold one (in lateral feet) | ft			2,200
Horizontal wells turned to sales, threshold two (in lateral feet) | ft			3,820
Incremental override (percentage)			2.00%
Percentage of distributions received			85.00%
Proceeds from sale of interest in VPP properties	$ 216
Sixth Street
Transactions
Cash contribution			$ 300
Additional contribution upon achievement of production target			$ 102
Amount of cash distribution received						$ 51
Internal rate of return threshold			13.00%
Cash on cash return threshold			150.00%
Sixth Street | Forecast
Transactions
Amount of cash distribution received				$ 51
JPM -VEC
Transactions
Overriding royalty interest , production volume, threshold one (in MMBtu) | MMBTU		136,589,000
VPP agreement term for overriding royalty interest (in years)		7 years
QL
Transactions
Percent of total development capital spending in current year to be funded by drilling partner							20.00%
Gain (loss) on interests conveyed					$ 0
QL | Minimum
Transactions
Percent of total development capital spending in years 2-4 to be funded by drilling partner							15.00%
QL | Maximum
Transactions
Percent of total development capital spending in years 2-4 to be funded by drilling partner							20.00%

Revenue (Details)

Revenue (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Disaggregation of Revenue
Revenue	$ 1,370,164	$ 750,474
Income from derivatives, deferred revenue and other sources	(165,966)	566,631
Total revenue	1,204,198	1,317,105
Natural gas sales
Disaggregation of Revenue
Revenue	720,369	411,082
Oil sales
Disaggregation of Revenue
Revenue	44,686	35,646
Marketing
Disaggregation of Revenue
Revenue	164,790	46,073
Exploration and production | Natural gas sales
Disaggregation of Revenue
Revenue	720,369	411,082
Exploration and production | Natural gas liquids sales (ethane)
Disaggregation of Revenue
Revenue	36,110	26,796
Exploration and production | Natural gas liquids sales (C3+ NGLs)
Disaggregation of Revenue
Revenue	404,209	230,877
Exploration and production | Oil sales
Disaggregation of Revenue
Revenue	44,686	35,646
Marketing | Marketing
Disaggregation of Revenue
Revenue	$ 164,790	$ 46,073

Revenue - Transaction Price All

Revenue - Transaction Price Allocation and Contract Balances (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Revenue
Original expected duration	true
Receivables from contracts with customers	$ 447	$ 425

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
Investments in unconsolidated affiliates
Equity in earnings (loss) of unconsolidated affiliates	$ 18,694	$ (128,055)
Dividends from unconsolidated affiliates	(42,756)	(42,756)
Impairment		(610,632)
Balance Sheet
Current assets	586,307		$ 574,139
Total assets	13,000,382	14,525,789	13,150,845
Current liabilities	1,221,328		983,054
Total equity	6,227,949	6,592,540	6,090,271	$ 6,970,743
Total liabilities and equity	13,000,382		13,150,845
Revenues	1,204,198	1,317,105
Operating expenses	1,109,658	1,054,672
Income (loss) from operations	94,540	262,433
Net loss including noncontrolling interests	$ (11,104)	(338,810)
Antero Midstream Corporation
Equity Method Investments
Ownership percentage	29.20%
Antero Midstream Corporation
Investments in unconsolidated affiliates
Fair value of investment	$ 1,300,000		1,100,000
Equity Method Investment, Nonconsolidated Investee or Group of Investees | Antero Midstream Corporation
Investments in unconsolidated affiliates
Balance at beginning of period	255,082
Equity in earnings (loss) of unconsolidated affiliates	18,694
Dividends from unconsolidated affiliates	(42,756)
Elimination of intercompany profit	10,138
Balance at end of period	241,158
Balance Sheet
Current assets	91,167		93,931
Noncurrent assets	5,455,593		5,516,981
Total assets	5,546,760		5,610,912
Current liabilities	79,750		94,005
Noncurrent liabilities	3,110,144		3,098,621
Total equity	2,356,866		2,418,286
Total liabilities and equity	5,546,760		$ 5,610,912
Revenues	224,121	243,708
Operating expenses	90,534	762,872
Income (loss) from operations	133,587	(519,164)
Net loss including noncontrolling interests	$ 83,441	$ (392,933)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Accrued Liabilities
Capital expenditures	$ 44,476	$ 32,372
Gathering, compression, processing, and transportation expenses	149,266	152,724
Marketing expenses	59,396	68,193
Interest expense, net	39,049	25,645
Accrued taxes	24,386	40,796
Other	34,190	23,794
Total accrued liabilities	$ 350,763	$ 343,524

Long-Term Debt (Details)

Long-Term Debt (Details) $ / shares in Units, $ in Thousands	Jan. 26, 2021USD ($)	Jan. 12, 2021USD ($)$ / sharesshares	Jan. 04, 2021USD ($)	Aug. 21, 2020USD ($)Dshares	Mar. 31, 2021USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2020USD ($)	Sep. 02, 2020USD ($)	Dec. 21, 2016USD ($)	Mar. 17, 2015USD ($)	Sep. 18, 2014USD ($)	May 06, 2014USD ($)
Long- term Debt
Total principal					$ 2,644,882		$ 3,129,198
Unamortized premium (discount), net					(51,669)		(111,886)
Unamortized debt issuance costs					(24,527)		(15,719)
Long-term debt					2,568,686		3,001,593
Payments of deferred financing costs					15,370
Equity component of 2026 Convertible Notes, net					(116,381)
Gain (loss) on extinguishment of debt repurchased					(43,204)	$ 80,561
Debt Repurchase Program
Long- term Debt
Notional amount debt repurchased						$ 383,000
Weighted average percentage discount on repurchases of debt						21.00%
Gain (loss) on extinguishment of debt repurchased						$ 81,000
Credit Facility
Long- term Debt
Total principal					143,200		$ 1,017,000
Current borrowing base					2,850,000
Lender commitments					$ 2,640,000
Weighted average interest rate (as a percent)					3.13%		3.26%
Outstanding letters of credit					$ 742,000		$ 730,000
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)					0.30%
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)					0.375%
5.375% senior notes due 2021
Long- term Debt
Interest rate (as a percent)					5.375%
5.125 senior notes due 2022
Long- term Debt
Total principal							$ 660,516
Interest rate (as a percent)					5.125%		5.125%					5.125%
Senior notes issued											$ 500,000	$ 600,000
Issue price as percentage of par value											100.50%	100.00%
5.125 senior notes due 2022 | Debt Repurchase Program
Long- term Debt
Notional amount debt repurchased					$ 661,000
5.625% senior notes due 2023
Long- term Debt
Total principal					$ 574,182		$ 574,182
Interest rate (as a percent)					5.625%					5.625%
Senior notes issued										$ 750,000
Issue price as percentage of par value										100.00%
Redemption price					101.406%
Redemption price at which notes may be required to be repurchased in event of change of control					101.00%
Notional amount debt repurchased							176,000
5.625% senior notes due 2023 | On Or After June 1, 2021
Long- term Debt
Redemption price					100.00%
5.00% senior notes due 2025
Long- term Debt
Total principal					$ 590,000		590,000
Interest rate (as a percent)					5.00%				5.00%
Senior notes issued									$ 600,000
Issue price as percentage of par value									100.00%
Redemption price					102.50%
Redemption price at which notes may be required to be repurchased in event of change of control					101.00%
Notional amount debt repurchased							10,000
5.00% senior notes due 2025 | On or after March1, 2023
Long- term Debt
Redemption price					100.00%
8.375% Senior Notes Due 2026
Long- term Debt
Total principal					$ 500,000
Interest rate (as a percent)			8.375%		8.375%
Senior notes issued			$ 500,000
Issue price as percentage of par value			100.00%
Redemption price of the debt instrument in the event of change of control (as a percent)			101.00%
8.375% Senior Notes Due 2026 | On or after 15 January, 2024
Long- term Debt
Redemption price			104.188%
8.375% Senior Notes Due 2026 | On or after 15 January, 2026
Long- term Debt
Redemption price			100.00%
8.375% Senior Notes Due 2026 | On or before 15 January, 2024
Long- term Debt
Percentage of the principal amount of the debt instrument which the entity may redeem with the proceeds from certain equity offerings			35.00%
Redemption price of the debt instrument if redeemed with the proceeds of certain equity offerings (as a percent)			108.375%
8.375% Senior Notes Due 2026 | Prior to 15 January 2024
Long- term Debt
Redemption price			100.00%
7.625% Senior Notes Due 2029
Long- term Debt
Total principal					$ 700,000
Interest rate (as a percent)	7.625%				7.625%
Senior notes issued	$ 700,000
Issue price as percentage of par value	100.00%
Redemption price of the debt instrument in the event of change of control (as a percent)	101.00%
7.625% Senior Notes Due 2029 | On or after 01 February, 2024
Long- term Debt
Redemption price	103.813%
7.625% Senior Notes Due 2029 | On or after 01 February, 2027
Long- term Debt
Redemption price	100.00%
7.625% Senior Notes Due 2029 | On or before 01 February, 2024
Long- term Debt
Percentage of the principal amount of the debt instrument which the entity may redeem with the proceeds from certain equity offerings	35.00%
Redemption price of the debt instrument if redeemed with the proceeds of certain equity offerings (as a percent)	107.625%
7.625% Senior Notes Due 2029 | Prior to 01 February 2024
Long- term Debt
Redemption price	100.00%
4.25% convertible senior notes due 2026
Long- term Debt
Total principal					$ 137,500		287,500
Unamortized premium (discount), net				$ 116,000	(51,669)		(112,265)
Unamortized debt issuance costs					(3,029)		(5,852)
Long-term debt					$ 82,802		169,383
Interest rate (as a percent)				4.25%	4.25%
Issuance of convertible notes				$ 278,500
Payments of deferred financing costs				$ 9,000
Equity component					$ (14,755)		115,601
Conversion rate in shares of Antero Resources' common stock per $1,000 principal amount | shares				230.2026
If-converted value					323,000
If-converted value above principal amount					185,000
Effective interest rate				15.10%
Debt issuance cost							3,000
Deferred taxes							$ 28,000
Interest expenses					4,400
Senior notes issued				$ 250,000				$ 37,500
Number of shares of common stock issued (in shares) | shares		31,400,000
Share price | $ / shares		$ 6.35
4.25% convertible senior notes due 2026 | Equitization Transaction
Long- term Debt
Conversion rate in shares of Antero Resources' common stock per $1,000 principal amount | shares		275.3525
Repurchase of equity component					116,000
Deferred taxes					14,000
Notional amount debt repurchased		$ 150,000
Loss on convertible note equitization					(39,000)
Gain (loss) on extinguishment of debt repurchased					$ (43,000)
Proceeds from Issuance or Sale of Equity		$ 63,000
4.25% convertible senior notes due 2026 | Convertible debt threshold minimum percentage
Long- term Debt
Stock price trigger				98.00%
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				130.00%
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) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Asset Retirement Obligations
Asset retirement obligations - beginning of period	$ 54,452
Obligations incurred	70
Accretion expense	788	$ 1,104
Asset retirement obligations - end of period	$ 55,310

Equity-Based Compensation and_3

Equity-Based Compensation and Cash Awards (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Jun. 17, 2020
Stock-based compensation expense
Common stock, par value (in dollars per share)	$ 0.01		$ 0.01
Equity based compensation expense recognized	$ 5,642	$ 3,329
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	7,928,770
Midstream Plan
Stock-based compensation expense
Number of stock-based compensation awards authorized	10,000,000
RSUs
Stock-based compensation expense
Equity based compensation expense recognized	$ 3,238	1,878
PSUs
Stock-based compensation expense
Equity based compensation expense recognized	1,536	922
Antero Midstream Partners Phantom Unit Awards
Stock-based compensation expense
Equity based compensation expense recognized	518	160
Equity awards issued to directors
Stock-based compensation expense
Equity based compensation expense recognized	$ 350	$ 369
Antero Midstream Corporation | Midstream Plan | Common Stock
Stock-based compensation expense
Conversion rate of units converted into restricted stock	1
Antero Midstream Corporation | RSUs
Stock-based compensation expense
Conversion rate of units converted into restricted stock	1.8926

Equity-Based Compensation and_4

Equity-Based Compensation and Cash Awards - Restricted Stock and RSU Awards (Details) - RSUs $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2021USD ($)$ / sharesshares
Number of shares
Total awarded and unvested at the beginning of the period (in shares) | shares	8,432,397
Granted (in shares) | shares	14,738
Vested (in shares) | shares	(1,906,286)
Forfeited (in shares) | shares	(83,359)
Total awarded and unvested at the end of the period (in shares) | shares	6,457,490
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares	$ 4.06
Granted (in dollars per share) | $ / shares	7.26
Vested (in dollars per share) | $ / shares	2.70
Forfeited (in dollars per share) | $ / shares	4.82
Total awarded and unvested at the end of the period (in dollars per share) | $ / shares	$ 4.46
Additional equity compensation to be recognized over the remaining period | $	$ 20
Weighted average period for recognizing unrecognized stock-based compensation expense	2 years 1 month 6 days

Equity-Based Compensation and_5

Equity-Based Compensation and Cash Awards - Stock Options (Details) - Stock options - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Stock options
Outstanding at the beginning of the period (in shares)	432,461
Options expired (in shares)	(5,000)
Outstanding at the end of the period (in shares)	427,461	432,461
Vested (in shares)	427,461
Exercisable (in shares)	427,461
Weighted average exercise price
Outstanding at the beginning of the period (in dollars per share)	$ 50.64
Options expired (in dollars per share)	50
Outstanding at the end of the period (in dollars per share)	50.65	$ 50.64
Vested (in dollars per share)	50.65
Exercisable (in dollars per share)	$ 50.65
Weighted average remaining contractual life
Outstanding	3 years 9 months 18 days	4 years 1 month 6 days
Vested	3 years 9 months 18 days
Exercisable	3 years 9 months 18 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
	Jul. 31, 2020	Jan. 31, 2020USD ($)tranche	Mar. 31, 2021USD ($)$ / sharesshares	Jul. 01, 2020USD ($)
PSUs
Number of units
Total awarded and unvested at the beginning of the period (in shares) | shares			2,547,798
Forfeited (in shares) | shares			(23,283)
Cancelled (unearned) | shares			(133,334)
Total awarded and unvested at the end of the period (in shares) | shares			2,391,181
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares			$ 12.66
Forfeited (in dollars per share) | $ / shares			9.26
Cancelled (unearned) (in dollars per share) | $ / shares			25.64
Total awarded and unvested at the end of the period (in dollars per share) | $ / shares			$ 11.97
Additional disclosures
Additional equity compensation to be recognized over the remaining period | $			$ 6
Weighted average period for recognizing unrecognized stock-based compensation expense			1 year 2 months 12 days
Cash Awards
Vesting period	4 years
Additional disclosures
Cash awards granted | $		$ 3.3		$ 2.6
Number of tranches | tranche		3
Cash awards accrued in other liabilities | $			$ 2.4

Equity-Based Compensation and_7

Equity-Based Compensation and Cash Awards - Phantom and Restricted Stock Unit Awards (Details) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2021USD ($)$ / sharesshares
Antero Midstream Partners Phantom Unit Awards
Weighted average grant date fair value
Additional equity compensation to be recognized over the remaining period | $	$ 1.6
Antero Midstream Partners Phantom Unit Awards | Maximum
Weighted average grant date fair value
Weighted average period for recognizing unrecognized stock-based compensation expense	1 year
Antero Midstream Corporation | RSUs
Number of units
Total awarded and unvested at the beginning of the period (in shares) | shares	296,390
Vested (in shares) | shares	(10,122)
Total awarded and unvested at the end of the period (in shares) | shares	286,268
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares	$ 15.06
Vested (in dollars per share) | $ / shares	15.81
Total awarded and unvested at the end of the period (in dollars per share) | $ / shares	$ 15.04

Fair Value (Details)

Fair Value (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Jan. 26, 2021	Jan. 04, 2021	Dec. 31, 2020	Aug. 21, 2020	Dec. 21, 2016	Mar. 17, 2015	May 06, 2014
5.125 senior notes due 2022
Financial Instruments
Interest rate (as a percent)	5.125%			5.125%				5.125%
5.625% senior notes due 2023
Financial Instruments
Interest rate (as a percent)	5.625%						5.625%
5.00% senior notes due 2025
Financial Instruments
Interest rate (as a percent)	5.00%					5.00%
8.375% Senior Notes Due 2026
Financial Instruments
Interest rate (as a percent)	8.375%		8.375%
7.625% Senior Notes Due 2029
Financial Instruments
Interest rate (as a percent)	7.625%	7.625%
4.25% convertible senior notes due 2026
Financial Instruments
Interest rate (as a percent)	4.25%				4.25%
Fair value | Level 2 market data
Financial Instruments
Value	$ 2,808,579			$ 2,212,629
Fair value | Level 2 market data | 5.125 senior notes due 2022
Financial Instruments
Value				658,468
Fair value | Level 2 market data | 5.625% senior notes due 2023
Financial Instruments
Value	576,077			562,698
Fair value | Level 2 market data | 5.00% senior notes due 2025
Financial Instruments
Value	590,413			560,500
Fair value | Level 2 market data | 8.375% Senior Notes Due 2026
Financial Instruments
Value	551,250
Fair value | Level 2 market data | 7.625% Senior Notes Due 2029
Financial Instruments
Value	742,840
Fair value | Level 2 market data | 4.25% convertible senior notes due 2026
Financial Instruments
Value	347,999			430,963
Carrying value
Financial Instruments
Value	2,425,486			1,984,593
Carrying value | 5.125 senior notes due 2022
Financial Instruments
Value				658,400
Carrying value | 5.625% senior notes due 2023
Financial Instruments
Value	571,644			571,370
Carrying value | 5.00% senior notes due 2025
Financial Instruments
Value	585,687			585,440
Carrying value | 8.375% Senior Notes Due 2026
Financial Instruments
Value	494,209
Carrying value | 7.625% Senior Notes Due 2029
Financial Instruments
Value	691,144
Carrying value | 4.25% convertible senior notes due 2026
Financial Instruments
Value	$ 82,802			$ 169,383

Derivative Instruments - Commod

Derivative Instruments - Commodity derivatives (Details)	3 Months Ended
	Mar. 31, 2021MMBTU / d$ / bbl$ / MMBTU$ / galMMBblsbbl
Natural gas | April-December 2021
Derivative Instruments
Notional amount | MMBbls	47,385
Weighted average index price | $ / MMBTU	2.61
Natural gas | January-December 2022
Derivative Instruments
Notional amount | MMBbls	38,356
Weighted average index price | $ / MMBTU	2.39
Natural gas | January-December 2023
Derivative Instruments
Notional amount | MMBbls	35,615
Weighted average index price | $ / MMBTU	2.35
Natural gas | January-December 2024
Derivative Instruments
Notional amount | MMBbls	23,885
Weighted average index price | $ / MMBTU	2.33
Natural gas | January-March 2025
Derivative Instruments
Notional amount | MMBbls	18,021
Weighted average index price | $ / MMBTU	2.53
Natural gas | NYMEX to TCO | April-December 2021
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	40,000
Natural gas | NYMEX to TCO | January-December 2022
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	60,000
Natural gas | NYMEX to TCO | January-December 2023
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	50,000
Natural gas | NYMEX to TCO | January-December 2024
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	50,000
Ethane | April-December 2021
Derivative Instruments
Notional amount	1,033
Weighted average index price | $ / bbl	7.01
Ethane | January-March 2022
Derivative Instruments
Notional amount	521
Weighted average index price | $ / bbl	6.68
Propane | April-December 2021
Derivative Instruments
Notional amount	1,149
Weighted average index price | $ / bbl	18.71
Propane | January-December 2022
Derivative Instruments
Notional amount	934
Weighted average index price | $ / bbl	19.20
Natural Gasoline | April-December 2021
Derivative Instruments
Notional amount	354
Weighted average index price | $ / bbl	31.61
Natural Gasoline | January-December 2022
Derivative Instruments
Notional amount	282
Weighted average index price | $ / bbl	34.37
Natural Gasoline | January-December 2023
Derivative Instruments
Notional amount	247
Weighted average index price | $ / bbl	40.74
Oil | April-December 2021
Derivative Instruments
Notional amount	129
Weighted average index price | $ / bbl	40.86
Oil | January-December 2022
Derivative Instruments
Notional amount	112
Weighted average index price | $ / bbl	43.51
Oil | January-December 2023
Derivative Instruments
Notional amount	99
Weighted average index price | $ / bbl	44.88
Oil | January-December 2024
Derivative Instruments
Notional amount	43
Weighted average index price | $ / bbl	44.02
Oil | January-March 2025
Derivative Instruments
Notional amount	39
Weighted average index price | $ / bbl	45.06
Swaps | Natural gas | April-December 2021
Derivative Instruments
Notional amount | MMBbls	2,160,000
Weighted average index price | $ / MMBTU	2.76
Swaps | Natural gas | January-December 2022
Derivative Instruments
Notional amount | MMBbls	1,155,486
Weighted average index price | $ / MMBTU	2.50
Swaps | Natural gas | January-December 2023
Derivative Instruments
Notional amount	43,000
Weighted average index price | $ / gal	2.37
Swaps | Propane | April-December 2021
Derivative Instruments
Notional amount	16,655
Weighted average index price | $ / MMBTU	30.64
Swaps | Butane | OPIS Butane Mt Belv Non-TET | April-December 2021
Derivative Instruments
Notional amount	3,331
Weighted average index price | $ / bbl	33.42
Swaps | Butane | OPIS Butane Mt Belv TET | April-December 2021
Derivative Instruments
Notional amount	1,415
Weighted average index price | $ / bbl	31.36
Swaps | Natural Gasoline | April-December 2021
Derivative Instruments
Notional amount	8,617
Weighted average index price | $ / bbl	51.19
Swaps | Isobutane | April-June 2021
Derivative Instruments
Notional amount	662
Weighted average index price | $ / bbl	33.30
Swaps | Oil | April-December 2021
Derivative Instruments
Notional amount	3,000
Weighted average index price | $ / MMBTU	55.16
Fixed price swap agreement
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	427,500
Fixed price ($/MMBtu) | $ / MMBTU	2.77

Derivative Instruments (Details

Derivative Instruments (Details)	3 Months Ended
	Mar. 31, 2021MMBTU / d$ / bbl$ / MMBTU$ / galbblMMBbls
Put option | Year ending December 31, 2026
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	106,073,000
Weighted average strike price	2.59
Natural gas | April-December 2021
Derivative Instruments
Notional amount | MMBbls	47,385
Weighted average hedged differential	2.61
Natural gas | January-December 2022
Derivative Instruments
Notional amount | MMBbls	38,356
Weighted average hedged differential	2.39
Natural gas | January-December 2023
Derivative Instruments
Notional amount | MMBbls	35,615
Weighted average hedged differential	2.35
Natural gas | January-December 2024
Derivative Instruments
Notional amount | MMBbls	23,885
Weighted average hedged differential	2.33
Natural gas | NYMEX to TCO | April-December 2021
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	40,000
Weighted average payout ratio	0.414
Natural gas | NYMEX to TCO | January-December 2022
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	60,000
Weighted average payout ratio	0.515
Natural gas | NYMEX to TCO | January-December 2023
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	50,000
Weighted average payout ratio	0.525
Natural gas | NYMEX to TCO | January-December 2024
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	50,000
Weighted average payout ratio	0.530
Natural gas | Swaps | April-December 2021
Derivative Instruments
Notional amount | MMBbls	2,160,000
Weighted average hedged differential	2.76
Natural gas | Swaps | January-December 2022
Derivative Instruments
Notional amount | MMBbls	1,155,486
Weighted average hedged differential	2.50
Natural gas | Swaps | January-December 2023
Derivative Instruments
Notional amount | bbl	43,000
Weighted average hedged differential | $ / gal	2.37
Oil | April-December 2021
Derivative Instruments
Notional amount | bbl	129
Weighted average hedged differential | $ / bbl	40.86
Oil | January-December 2022
Derivative Instruments
Notional amount | bbl	112
Weighted average hedged differential | $ / bbl	43.51
Oil | January-December 2023
Derivative Instruments
Notional amount | bbl	99
Weighted average hedged differential | $ / bbl	44.88
Oil | January-December 2024
Derivative Instruments
Notional amount | bbl	43
Weighted average hedged differential | $ / bbl	44.02
Oil | Swaps | April-December 2021
Derivative Instruments
Notional amount | bbl	3,000
Weighted average hedged differential	55.16
Natural gas liquids | Swaps | Mont Belvieu Natural Gasoline to WTI | April-December 2021
Derivative Instruments
Notional amount | bbl	9,325
Weighted average payout ratio	78

Derivative Instruments - Fair v

Derivative Instruments - Fair value (Details) $ in Thousands	Mar. 31, 2021USD ($)item	Dec. 31, 2020USD ($)item
Fair value of derivative instruments
Current portion of fair value of derivative assets	$ 41,356	$ 105,130
Noncurrent portion of fair value of derivative assets	43,240	47,293
Current portion of fair value of derivative liabilities	146,720	31,242
Noncurrent portion of fair value of derivative liabilities	98,944	99,172
Commodity derivative
Fair value of derivative instruments
Total asset derivatives	52,314	111,833
Total liability derivatives	245,664	130,414
Embedded derivatives
Fair value of derivative instruments
Total asset derivatives	32,282	40,590
Derivatives not designated as hedges for accounting purposes
Fair value of derivative instruments
Total asset derivatives	84,596	152,423
Total liability derivatives	245,664	130,414
Derivatives not designated as hedges for accounting purposes | Commodity derivative
Fair value of derivative instruments
Current portion of fair value of derivative assets	36,633	97,144
Noncurrent portion of fair value of derivative assets	15,681	14,689
Current portion of fair value of derivative liabilities	146,720	31,242
Noncurrent portion of fair value of derivative liabilities	98,944	99,172
Derivatives not designated as hedges for accounting purposes | Commodity derivative | VIE, Martica
Fair value of derivative instruments
Current portion of fair value of derivative liabilities	13,000	7,000
Noncurrent portion of fair value of derivative liabilities	10,000	7,000
Total liability derivatives	23,000	14,000
Derivatives not designated as hedges for accounting purposes | Embedded derivatives
Fair value of derivative instruments
Current portion of fair value of derivative assets	4,723	7,986
Noncurrent portion of fair value of derivative assets	$ 27,559	$ 32,604
Derivatives designated as hedges for accounting purposes
Fair value of derivative instruments
Number of derivative instruments held designated as hedges | item	0	0
Net derivatives assets (liabilities)	$ (161,068)	$ 22,009

Derivative Instruments - Assets

Derivative Instruments - Assets and liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Commodity derivative
Commodity derivative assets
Gross amounts on balance sheet	$ 90,891	$ 181,375
Gross amounts offset on balance sheet	(38,577)	(69,542)
Total asset derivatives	52,314	111,833
Commodity derivative liabilities
Gross amounts on balance sheet	(284,241)	(199,956)
Gross amounts offset on balance sheet	38,577	69,542
Total liability derivatives	(245,664)	(130,414)
Embedded derivatives
Commodity derivative assets
Gross amounts on balance sheet	32,282	40,590
Total asset derivatives	$ 32,282	$ 40,590

Derivative Instruments - Fair_2

Derivative Instruments - Fair value gains (losses) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Summary of realized and unrealized gains (losses) on derivative instruments
Derivative fair value (gains) losses	$ (177,756)	$ 565,833
Commodity derivative | Revenue
Summary of realized and unrealized gains (losses) on derivative instruments
Derivative fair value (gains) losses	(169,967)	$ 565,833
Embedded derivatives | Revenue
Summary of realized and unrealized gains (losses) on derivative instruments
Derivative fair value (gains) losses	$ (7,789)

Leases (Details)

Leases (Details)	3 Months Ended
	Mar. 31, 2021
Leases
Options to renew - Operating lease	true
Options to renew - Finance lease	true
Minimum
Leases
Renewal terms - Operating lease	1 year
Renewal terms - Finance lease	1 year
Maximum
Leases
Renewal terms - Operating lease	20 years
Renewal terms - Finance lease	20 years

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information Related to Leases (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Lease Assets
Operating lease right-of-use assets	$ 2,549,297	$ 2,613,603
Short-term operating lease obligation	$ 264,858	$ 265,178
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Short-term operating lease obligation	Short-term operating lease obligation
Long-term operating lease obligation	$ 2,284,439	$ 2,348,425
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Long-term operating lease obligation	Long-term operating lease obligation
Total operating lease obligation	$ 2,549,297	$ 2,613,603
Finance leases, right of use assets	934	1,206
Short-term lease liabilities, finance leases	$ 693	$ 845
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	Short-term lease liabilities, finance leases	Short-term lease liabilities, finance leases
Long-term lease liabilities, finance leases	$ 241	$ 361
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Long-term lease liabilities, finance leases	Long-term lease liabilities, finance leases
Total	$ 934	$ 1,206
Finance leases, accumulated amortization	3,000	3,000
Vehicles
Lease Assets
Operating lease right-of-use assets	$ 2,024	$ 2,704
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating lease right-of-use assets	Operating lease right-of-use assets
Finance leases, right of use assets	$ 934	$ 1,206
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 lease right-of-use assets	$ 675	$ 746
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating lease right-of-use assets	Operating lease right-of-use assets
Processing plants
Lease Assets
Operating lease right-of-use assets	$ 1,279,755	$ 1,302,290
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating lease right-of-use assets	Operating lease right-of-use assets
Drilling and completion rigs
Lease Assets
Operating lease right-of-use assets	$ 22,632	$ 29,894
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating lease right-of-use assets	Operating lease right-of-use assets
Gas gathering lines and compressor stations
Lease Assets
Operating lease right-of-use assets	$ 1,208,252	$ 1,241,090
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating lease right-of-use assets	Operating lease right-of-use assets
Gas gathering lines and compressor stations | Antero Midstream Corporation
Lease Assets
Operating lease right-of-use assets	$ 1,100,000	$ 1,100,000
Office space
Lease Assets
Operating lease right-of-use assets	$ 35,959	$ 36,879
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Operating lease right-of-use assets	Operating lease right-of-use assets

Leases - Supplemental Informati

Leases - Supplemental Information Related to Leases (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Leases
Total lease expense	$ 408,199	$ 388,518
Total finance lease cost	155	181
Short-term lease payments	16,842	62,717
Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases	388,983	358,039
Cash paid for amounts included in the measurement of lease liabilities: Investing cash flows from operating leases	24,027	27,534
Cash paid for amounts included in the measurement of lease liabilities: Financing cash flows from finance leases	265	439
ROU assets obtained in exchange for new operating lease obligations	28	9,382
Proved properties
Leases
Total lease expense	28,759	32,994
Gathering, compression, water handling and treatment
Leases
Total lease expense	376,930	352,643
General and administrative
Leases
Total lease expense	2,488	2,881
Lease operating
Leases
Total lease expense	22
Depletion, Depreciation, And Amortization
Leases
Amortization of right-of-use assets	127	145
Interest expense
Leases
Interest on lease liabilities	$ 28	$ 36

Leases - Maturities of Lease Li

Leases - Maturities of Lease Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Future minimum payments for operating lease liabilities
Remainder of 2021	$ 457,065
2022	579,086
2023	575,235
2024	566,467
2025	493,790
2026	442,971
Thereafter	1,115,499
Total lease payments	4,230,113
Less: imputed interest	(1,680,816)
Total operating lease obligation	2,549,297	$ 2,613,603
Future minimum payments for financing lease liabilities
Remainder of 2021	612
2022	366
2023	9
Total lease payments	987
Less: imputed interest	(53)
Total	934	$ 1,206
Future minimum payments for total lease liabilities
Remainder of 2021	457,677
2022	579,452
2023	575,244
2024	566,467
2025	493,790
2026	442,971
Thereafter	1,115,499
Total lease payments	4,231,100
Less: imputed interest	(1,680,869)
Total	$ 2,550,231

Leases - Lease Term and Discoun

Leases - Lease Term and Discount Rate (Details)	Mar. 31, 2021	Dec. 31, 2020
Leases
Weighted-average remaining lease term: Operating lease	7 years 8 months 12 days	8 years
Weighted-average discount rate: Operating lease	13.80%	13.70%
Weighted-average remaining lease term: Finance lease	1 year 3 months 18 days	1 year 6 months
Weighted-average discount rate: Finance lease	6.20%	6.20%

Leases - Related party disclosu

Leases - Related party disclosure (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Leases
Accounts payable, related parties	$ 85,846		$ 69,860
Antero Midstream Corporation
Leases
Utilizing capacity (as a percent)	75.00%
Payment of capacity (as a percent)	70.00%
Term of lease	10 years
Notice period	180 days
Rebate received	$ 0	$ 12,000
Gathering and compression fees paid	177,000	$ 156,000
Accounts payable, related parties	$ 63,000		$ 55,000

Commitments (Details)

Commitments (Details) $ in Thousands	Mar. 31, 2021USD ($)
Future minimum payments
Remainder of 2021	$ 1,317,801
2022	1,674,182
2023	1,706,696
2024	1,670,959
2025	1,566,323
2026	1,476,364
Thereafter	7,242,000
Total	16,654,325
Firm transportation
Future minimum payments
Remainder of 2021	816,349
2022	1,042,065
2023	1,072,312
2024	1,045,230
2025	1,024,573
2026	1,018,610
Thereafter	6,027,905
Total	12,047,044
Gas processing, gathering and compression
Future minimum payments
Remainder of 2021	41,199
2022	52,265
2023	59,140
2024	59,262
2025	47,960
2026	14,783
Thereafter	98,596
Total	373,205
Land payment obligations
Future minimum payments
Remainder of 2021	2,576
2022	400
Total	2,976
Operating and Financing Leases
Future minimum payments
Remainder of 2021	201,248
2022	267,895
2023	300,977
2024	334,699
2025	306,925
2026	299,354
Thereafter	839,133
Total	2,550,231
Imputed Interest for Leases
Future minimum payments
Remainder of 2021	256,429
2022	311,557
2023	274,267
2024	231,768
2025	186,865
2026	143,617
Thereafter	276,366
Total	$ 1,680,869

Contingencies (Details)

Contingencies (Details) - WGL $ in Millions	Jun. 20, 2019USD ($)	Feb. 28, 2021USD ($)	Jun. 30, 2019lawsuit	Mar. 31, 2017USD ($)
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) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Sales and revenues:
Sales and revenues - Third-party	$ 1,203,558	$ 1,316,307
Sales and revenues - Intersegment	640	798
Revenues	1,204,198	1,317,105
Operating expenses:
Impairment of oil and gas properties	34,062	89,220
Depletion, depreciation, and amortization	194,026	199,677
General and administrative	44,074	31,221
Other	207,872	120,286
Total operating expenses	1,109,658	1,054,672
Operating income (loss)	94,540	262,433
Equity in earnings (loss) of unconsolidated affiliates	18,694	(128,055)
Investment in unconsolidated affiliate	241,158	291,989	$ 255,082
Segment assets	13,000,382	14,525,789	$ 13,150,845
Capital expenditures for segment assets	123,158	311,611
Lease operating
Operating expenses:
Cost of goods and services sold	24,547	25,644
Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	605,077	588,624
Operating segments | Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold		588,624
Operating segments | Exploration and production
Sales and revenues:
Sales and revenues - Third-party	1,038,768	1,270,234
Sales and revenues - Intersegment	640	798
Revenues	1,039,408	1,271,032
Operating expenses:
Impairment of oil and gas properties	34,062	89,220
Depletion, depreciation, and amortization	194,026	199,677
General and administrative	44,074	31,221
Other	45,795	27,013
Total operating expenses	947,581	961,399
Operating income (loss)	91,827	309,633
Equity in earnings (loss) of unconsolidated affiliates	18,694	(128,055)
Investment in unconsolidated affiliate	241,158	291,989
Segment assets	13,000,382	14,516,150
Capital expenditures for segment assets	123,158	311,611
Operating segments | Exploration and production | Lease operating
Operating expenses:
Cost of goods and services sold	24,547
Operating segments | Exploration and production | Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	605,077	588,624
Operating segments | Marketing
Sales and revenues:
Sales and revenues - Third-party	164,790	46,073
Revenues	164,790	46,073
Operating expenses:
Other	162,077	93,273
Total operating expenses	162,077	93,273
Operating income (loss)	2,713	(47,200)
Segment assets		9,639
Operating segments | Antero Midstream Corporation
Sales and revenues:
Sales and revenues - Intersegment	224,121	243,708
Revenues	224,121	243,708
Operating expenses:
Impairment of midstream assets	1,379	664,544
Depletion, depreciation, and amortization	26,850	27,343
General and administrative	17,930	13,537
Other	5,061	4,836
Total operating expenses	90,534	766,168
Operating income (loss)	133,587	(522,460)
Equity in earnings (loss) of unconsolidated affiliates	20,744	19,077
Investment in unconsolidated affiliate	712,069	716,778
Segment assets	5,546,760	5,781,359
Capital expenditures for segment assets	28,389	67,983
Operating segments | Antero Midstream Corporation | Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	39,314	55,908
Elimination of intersegment transaction
Sales and revenues:
Sales and revenues - Intersegment	(224,121)	(243,708)
Revenues	(224,121)	(243,708)
Operating expenses:
Impairment of midstream assets	(1,379)	(664,544)
Depletion, depreciation, and amortization	(26,850)	(27,343)
General and administrative	(17,930)	(13,537)
Other	(5,061)	(4,836)
Total operating expenses	(90,534)	(766,168)
Operating income (loss)	(133,587)	522,460
Equity in earnings (loss) of unconsolidated affiliates	(20,744)	(19,077)
Investment in unconsolidated affiliate	(712,069)	(716,778)
Segment assets	(5,546,760)	(5,781,359)
Capital expenditures for segment assets	(28,389)	(67,983)
Elimination of intersegment transaction | Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	$ (39,314)	(55,908)
Elimination of intersegment transaction | Exploration and production | Lease operating
Operating expenses:
Cost of goods and services sold		$ 25,644

Subsidiary Guarantors - Balance

Subsidiary Guarantors - Balance Sheets (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020
Current assets:
Accounts receivable, non-guarantor subsidiaries	$ 86,657	$ 28,457
Other current assets	11,781	15,238
Total current assets	586,307	574,139
Total assets	13,000,382	13,150,845	$ 14,525,789
Liabilities and Stockholders' Equity
Accounts payable, non-guarantor subsidiaries	41,990	26,728
Accounts payable, related parties	85,846	69,860
Other current liabilities	4,688	2,302
Total current liabilities	1,221,328	983,054
Total liabilities	6,772,433	7,060,574
Noncontrolling interests	353,262	$ 322,566
Parent (Antero) And Guarantor Subsidiaries
Current assets:
Accounts receivable, non-guarantor subsidiaries	51,000
Other current assets	505,539
Total current assets	556,539
Noncurrent assets	11,636,099
Total assets	12,192,638
Liabilities and Stockholders' Equity
Accounts payable, related parties	85,846
Other current liabilities	1,121,886
Total current liabilities	1,207,732
Noncurrent liabilities	5,540,027
Total liabilities	$ 6,747,759

Subsidiary Guarantors - Stateme

Subsidiary Guarantors - Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Condensed consolidated statement of operations and comprehensive income (loss)
Revenue	$ 1,370,164	$ 750,474
Operating expenses	1,109,658	1,054,672
Income (loss) from operations	94,540	262,433
Net income (loss) and comprehensive income (loss) including noncontrolling interests	(11,104)	(338,810)
Net income (loss) attributable to Antero Resources Corporation	(15,499)	$ (338,810)
Parent (Antero) And Guarantor Subsidiaries
Condensed consolidated statement of operations and comprehensive income (loss)
Revenue	1,189,088
Operating expenses	1,098,943
Income (loss) from operations	90,145
Net income (loss) and comprehensive income (loss) including noncontrolling interests	(15,499)
Net income (loss) attributable to Antero Resources Corporation	$ (15,499)