Antero Resources (AR) 10-Q 30 Oct 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 25, 2019
Document and Entity Information
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Document Period End Date	Sep. 30, 2019
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		304,270,444
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Entity Central Index Key	0001433270
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current assets:
Accounts receivable	$ 29,207	$ 51,073
Accrued revenue	281,177	474,827
Derivative instruments	411,774	245,263
Other current assets	7,342	35,450
Total current assets	729,500	806,613
Oil and gas properties, at cost (successful efforts method):
Unproved properties	1,406,464	1,767,600
Proved properties	11,568,285	12,705,672
Water handling and treatment systems		1,013,818
Gathering systems and facilities	5,802	2,470,708
Other property and equipment	70,965	65,842
Property and equipment, gross	13,051,516	18,023,640
Less accumulated depletion, depreciation, and amortization	(3,136,767)	(4,153,725)
Property and equipment, net	9,914,749	13,869,915
Operating leases right-of-use assets	3,230,148
Derivative instruments	405,180	362,169
Investments in unconsolidated affiliates	1,819,323	433,642
Other assets	21,388	47,125
Total assets	16,120,288	15,519,464
Current liabilities:
Accounts payable	32,496	66,289
Accounts payable, related parties	100,437
Accrued liabilities	392,726	465,070
Revenue distributions payable	231,152	310,827
Derivative instruments		532
Short-term lease liabilities	409,990	2,459
Other current liabilities	4,367	8,363
Total current liabilities	1,171,168	853,540
Long-term liabilities:
Long-term debt	3,703,828	5,461,688
Deferred income tax liability	916,031	650,788
Long-term lease liabilities	2,823,197	2,873
Other liabilities	59,366	63,098
Total liabilities	8,673,590	7,031,987
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; 308,594 shares and 304,161 shares issued and outstanding at December 31, 2018 and September 30, 2019, respectively	3,041	3,086
Additional paid-in capital	6,124,042	6,485,174
Accumulated earnings	1,319,615	1,177,548
Total stockholders' equity	7,446,698	7,665,808
Noncontrolling interests in consolidated subsidiary		821,669
Total equity	7,446,698	8,487,477
Total liabilities and equity	$ 16,120,288	$ 15,519,464

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2019	Dec. 31, 2018
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	304,161,000	308,594,000
Common stock, shares outstanding	304,161,000	308,594,000

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenue and other:
Revenues from contracts with customers	$ 896,612	$ 1,019,555	$ 2,980,757	$ 2,865,104
Commodity derivative fair value gains	220,788	57,019	471,847	134,793
Marketing derivative fair value gains (losses)	0	(42)	0	94,081
Total revenue	1,118,881	1,076,532	3,455,952	3,093,978
Operating expenses:
Production and ad valorem taxes	28,863	30,518	95,509	82,232
Impairment of oil and gas properties	1,041,469	221,094	1,253,712	406,068
Impairment of midstream assets	7,800	1,157	14,782	9,658
Depletion, depreciation, and amortization	241,503	243,186	724,006	709,480
Loss on sale of assets			951
Accretion of asset retirement obligations	927	710	2,821	2,101
General and administrative	35,923	59,860	146,507	181,576
Contract termination and rig stacking	62		14,026
Total operating expenses	2,104,759	1,071,728	4,375,541	2,975,444
Operating income (loss)	(985,878)	4,804	(919,589)	118,534
Other income (expenses):
Equity in earnings (loss) of unconsolidated affiliates	(117,859)	10,705	(90,193)	27,832
Interest expense, net	(47,754)	(74,528)	(173,868)	(208,303)
Gain on deconsolidation of Antero Midstream Partners LP			1,406,042
Total other income (expenses)	(165,613)	(63,823)	1,141,981	(180,471)
Income (loss) before income taxes	(1,151,491)	(59,019)	222,392	(61,937)
Provision for income tax (expense) benefit	272,627	(18,953)	(33,332)	(2,500)
Net income (loss) and comprehensive income (loss) including noncontrolling interests	(878,864)	(77,972)	189,060	(64,437)
Net income and comprehensive income attributable to noncontrolling interests		76,447	46,993	211,534
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	$ (878,864)	$ (154,419)	$ 142,067	$ (275,971)
Earnings (loss) per common share-basic (in dollars per share)
Earnings (loss) per common share-basic (in dollars per share)	$ (2.86)	$ (0.49)	$ 0.46	$ (0.87)
Earnings (loss) per common share-assuming dilution (in dollars per share)
Earnings (loss) per common share-assuming dilution (in dollars per share)	$ (2.19)	$ (0.49)	$ 0.46	$ (0.87)
Weighted average number of shares outstanding
Basic (in shares)	307,781	317,082	308,509	316,850
Diluted (in shares)	307,781	317,082	308,646	316,850
Natural gas sales
Revenue and other:
Revenues from contracts with customers	$ 524,448	$ 527,122	$ 1,735,086	$ 1,498,324
Natural gas liquids sales
Revenue and other:
Revenues from contracts with customers	284,958	338,269	902,606	828,424
Oil sales
Revenue and other:
Revenues from contracts with customers	40,561	59,722	137,675	128,869
Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers		4,844	4,479	15,298
Operating expenses:
Cost of goods and services sold	603,860	326,504	1,595,223	926,228
Marketing
Revenue and other:
Revenues from contracts with customers	46,645	89,598	200,911	394,189
Operating expenses:
Cost of goods and services sold	108,216	151,764	408,839	560,924
Other income
Revenue and other:
Revenues from contracts with customers	1,481		3,348
Lease operating
Operating expenses:
Cost of goods and services sold	35,928	36,269	118,517	93,155
Exploration
Operating expenses:
Cost of goods and services sold	$ 208	$ 666	$ 648	$ 4,022

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)
Equity-based compensation expense	$ 3,875	$ 16,202	$ 19,327	$ 56,429

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Equity - USD ($) shares in Thousands, $ in Thousands	Common Stock	Additional paid-in capital	Accumulated earnings	Noncontrolling Interests	Total
Balance at Dec. 31, 2017	$ 3,164	$ 6,570,952	$ 1,575,065	$ 726,955	$ 8,876,136
Balance (in shares) at Dec. 31, 2017	316,379
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings	$ 1	(1,067)			(1,066)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings (in shares)	145
Issuance of common units in Antero Midstream Partners LP upon vesting of equity-based compensation awards, net of units withheld for income taxes		(50)		32	(18)
Equity-based compensation		18,802		2,354	21,156
Net income (loss) and comprehensive income (loss)			14,833	65,977	80,810
Effects of changes in ownership interests in consolidated subsidiaries		(555)		555
Distributions to non-controlling interests				(55,915)	(55,915)
Other				(5)	(5)
Balance at Mar. 31, 2018	$ 3,165	6,588,082	1,589,898	739,953	8,921,098
Balance (in shares) at Mar. 31, 2018	316,524
Balance at Dec. 31, 2017	$ 3,164	6,570,952	1,575,065	726,955	8,876,136
Balance (in shares) at Dec. 31, 2017	316,379
Increase (Decrease) in Stockholders' Equity
Net income (loss) and comprehensive income (loss)					(64,437)
Balance at Sep. 30, 2018	$ 3,171	6,611,348	1,299,094	757,539	8,671,152
Balance (in shares) at Sep. 30, 2018	317,086
Balance at Mar. 31, 2018	$ 3,165	6,588,082	1,589,898	739,953	8,921,098
Balance (in shares) at Mar. 31, 2018	316,524
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings	$ 6	(5,589)			(5,583)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings (in shares)	528
Issuance of common units in Antero Midstream Partners LP upon vesting of equity-based compensation awards, net of units withheld for income taxes		(4,007)		2,707	(1,300)
Equity-based compensation		16,930		2,141	19,071
Net income (loss) and comprehensive income (loss)			(136,385)	69,110	(67,275)
Effects of changes in ownership interests in consolidated subsidiaries		2,121		(2,121)
Distributions to non-controlling interests				(63,108)	(63,108)
Other				8	8
Balance at Jun. 30, 2018	$ 3,171	6,597,537	1,453,513	748,690	8,802,911
Balance (in shares) at Jun. 30, 2018	317,052
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings		(157)			(157)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings (in shares)	34
Issuance of common units in Antero Midstream Partners LP upon vesting of equity-based compensation awards, net of units withheld for income taxes		(306)		226	(80)
Equity-based compensation		14,646		1,556	16,202
Net income (loss) and comprehensive income (loss)			(154,419)	76,447	(77,972)
Effects of changes in ownership interests in consolidated subsidiaries		(372)		372
Distributions to non-controlling interests				(69,752)	(69,752)
Balance at Sep. 30, 2018	$ 3,171	6,611,348	1,299,094	757,539	8,671,152
Balance (in shares) at Sep. 30, 2018	317,086
Balance at Dec. 31, 2018	$ 3,086	6,485,174	1,177,548	821,669	8,487,477
Balance (in shares) at Dec. 31, 2018	308,594
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings	$ 1	(451)			(450)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings (in shares)	147
Issuance of common units in Antero Midstream Partners LP upon vesting of equity-based compensation awards, net of units withheld for income taxes		(85)		56	(29)
Equity-based compensation		7,801		1,102	8,903
Net income (loss) and comprehensive income (loss)			978,763	46,993	1,025,756
Distributions to non-controlling interests		(359,039)		(784,744)	(1,143,783)
Effect of deconsolidation of Antero Midstream Partners LP				(85,076)	(85,076)
Balance at Mar. 31, 2019	$ 3,087	6,133,400	2,156,311		8,292,798
Balance (in shares) at Mar. 31, 2019	308,741
Balance at Dec. 31, 2018	$ 3,086	6,485,174	1,177,548	$ 821,669	8,487,477
Balance (in shares) at Dec. 31, 2018	308,594
Increase (Decrease) in Stockholders' Equity
Net income (loss) and comprehensive income (loss)					189,060
Balance at Sep. 30, 2019	$ 3,041	6,124,042	1,319,615		7,446,698
Balance (in shares) at Sep. 30, 2019	304,161
Balance at Mar. 31, 2019	$ 3,087	6,133,400	2,156,311		8,292,798
Balance (in shares) at Mar. 31, 2019	308,741
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings	$ 4	(1,819)			(1,815)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings (in shares)	382
Equity-based compensation		6,549			6,549
Net income (loss) and comprehensive income (loss)			42,168		42,168
Balance at Jun. 30, 2019	$ 3,091	6,138,130	2,198,479		8,339,700
Balance (in shares) at Jun. 30, 2019	309,123
Increase (Decrease) in Stockholders' Equity
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings	$ 1	(86)			(85)
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income tax withholdings (in shares)	99
Repurchases and retirements of common stock	$ (51)	(17,877)			(17,928)
Repurchases and retirements of common stock (in shares)	(5,061)
Equity-based compensation		3,875			3,875
Net income (loss) and comprehensive income (loss)			(878,864)		(878,864)
Balance at Sep. 30, 2019	$ 3,041	$ 6,124,042	$ 1,319,615		$ 7,446,698
Balance (in shares) at Sep. 30, 2019	304,161

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests	$ 189,060	$ (64,437)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion	726,827	711,581
Impairment of oil and gas properties	1,253,712	406,068
Impairment of midstream assets	14,782	9,658
Commodity derivative fair value gains	(471,847)	(134,793)
Gains on settled commodity derivatives	261,794	268,369
Marketing derivative fair value gains	0	(94,081)
Gains on settled marketing derivatives		78,098
Deferred income tax expense	32,019	2,500
Loss on sale of assets	951
Equity-based compensation expense	19,327	56,429
Equity in earnings (loss) of unconsolidated affiliates	90,193	(27,832)
Distributions/dividends of earnings from unconsolidated affiliates	109,241	29,660
Gain on deconsolidation of Antero Midstream Partners LP	(1,406,042)
Other	8,179	2,945
Changes in current assets and liabilities:
Accounts receivable	14,236	4,653
Accrued revenue	193,650	(53,888)
Other current assets	2,365	(3,721)
Accounts payable including related parties	(971)	8,177
Accrued liabilities	(11,169)	27,446
Revenue distributions payable	(72,176)	36,215
Other current liabilities	1,387	(2,649)
Net cash provided by operating activities	955,518	1,260,398
Cash flows provided by (used in) investing activities:
Additions to unproved properties	(69,796)	(130,381)
Drilling and completion costs	(957,931)	(1,125,660)
Additions to water handling and treatment systems	(24,416)	(77,385)
Additions to gathering systems and facilities	(48,239)	(337,448)
Additions to other property and equipment	(5,980)	(5,371)
Investments in unconsolidated affiliates	(25,020)	(91,419)
Proceeds from the Antero Midstream Partners LP Transactions	296,611
Change in other assets	7,461	(2,675)
Proceeds from asset sales	1,983
Net cash used in investing activities	(825,327)	(1,770,339)
Cash flows provided by (used in) financing activities:
Repurchases of common stock	(17,924)
Issuance of senior notes	650,000
Borrowings (repayments) on bank credit facilities, net	(45,000)	682,000
Payments of deferred financing costs	(8,259)
Distributions to noncontrolling interests in Antero Midstream Partners LP	(85,076)	(188,775)
Employee tax withholding for settlement of equity compensation awards	(2,379)	(8,205)
Other	(2,021)	(3,520)
Net cash provided by financing activities	489,341	481,500
Effect of deconsolidation of Antero Midstream Partners LP	(619,532)
Net decrease in cash and cash equivalents		(28,441)
Cash and cash equivalents, beginning of period		28,441
Supplemental disclosure of cash flow information:
Cash paid during the period for interest	142,288	179,489
Increase (decrease) in accounts payable and accrued liabilities for additions to property and equipment	$ (22,103)	$ 7,325

Organization

Organization	9 Months Ended
	Sep. 30, 2019
Organization
Organization	(1) Organization ​ Antero Resources Corporation (individually referred to as “Antero”) and its consolidated subsidiaries (collectively referred to as the “Company,” “we,” “us” or “our”) are engaged in the exploration, development, 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	9 Months Ended
	Sep. 30, 2019
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 SEC applicable to interim financial information and should be read in the context of the December 31, 2018 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position, and accounting policies. The December 31, 2018 consolidated financial statements have been filed with the Securities and Exchange Commission (“SEC”) in Antero’s 2018 Form 10-K. The accompanying 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, the accompanying 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, 2018 and September 30, 2019, and the results of its operations and its cash flows for the three and nine months ended September 30, 2018 and 2019. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss. Operating results for the period ended September 30, 2019 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, and other factors. As of the date these financial statements were filed with the SEC, the Company completed its evaluation of potential subsequent events for disclosure and no items requiring disclosure were identified. (b) Principles of Consolidation The accompanying unaudited condensed consolidated financial statements include the accounts of Antero, 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. Through March 12, 2019, Antero Midstream Partners LP (“Antero Midstream Partners”), a publicly traded limited partnership, was included in the consolidated financial statements of Antero. Prior to the Closing (defined in Note 3 to the unaudited condensed consolidated financial statements), our ownership of Antero Midstream Partners common units represented approximately a 53 % limited partner interest in Antero Midstream Partners, and we consolidated Antero Midstream Partners’ financial position and results of operations into our consolidated financial statements. The Transactions (defined in Note 3 to the unaudited condensed consolidated financial statements) resulted in the exchange of the limited partner interest we owned in Antero Midstream Partners for common stock of Antero Midstream Corporation representing an approximate 31 % interest. As a result, we no longer hold a controlling interest in Antero Midstream Partners and we now have an interest in Antero Midstream Corporation that provides significant influence, but not control, over Antero Midstream Corporation. Thus, effective March 13, 2019, Antero no longer consolidates Antero Midstream Partners in its consolidated financial statements and accounts for its interest in Antero Midstream Corporation using the equity method of accounting. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. All significant intercompany accounts and transactions have been eliminated in the Company’s unaudited condensed consolidated financial statements. The noncontrolling interest in the Company’s unaudited condensed consolidated financial statements represents the interests in Antero Midstream Partners, which were owned by the public prior to the Transactions, and the incentive distribution rights in Antero Midstream Partners, in both cases during the periods prior to the Transactions. Noncontrolling interests in consolidated subsidiaries is included as a component of equity in the Company’s unaudited condensed consolidated balance sheets. Investments in entities for which the Company exercises significant influence, but not control, are accounted for under the equity method. The Company’s judgment regarding the level of influence over its equity investments includes considering key factors such as Antero’s ownership interest, representation on the board of directors, and participation in the policy-making decisions of equity method investees. Such investments are included in Investments in unconsolidated affiliates on the Company’s unaudited condensed consolidated balance sheets. Income from investees that are accounted for under the equity method is included in Equity in earnings of unconsolidated affiliates on the Company’s unaudited condensed consolidated statements of operations and cash flows. When Antero records its proportionate share of net income, it increases equity income in the statements of operations and comprehensive income (loss) and the carrying value of that investment on the Company’s balance sheet. When a distribution is received, it is recorded as a reduction to the carrying value of that investment on the balance sheet. Our equity in earnings of unconsolidated affiliates is adjusted for intercompany transactions and the basis differences recognized due to the difference between the cost of the equity investment in Antero The Company accounts for distributions received from equity method investees under the “nature of the distribution” approach. Under this approach, distributions received from equity method investees are classified on the basis of the nature of the activity or activities of the investee that generated the distribution as either a return on investment (classified as cash inflows from operating activities) or a return of investment (classified as cash inflows from investing activities). (c) Use of Estimates The preparation of the unaudited condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect revenues, expenses, assets, and liabilities, as well as the disclosure of contingent assets and liabilities. Changes in facts and circumstances or discovery of new information may result in revised estimates, and actual results could differ from those estimates. The Company’s unaudited condensed consolidated financial statements are based on a number of significant estimates including estimates of natural gas, NGLs, and oil reserve quantities, which are the basis for the calculation of depletion and impairment of oil and gas properties. Reserve estimates, by their nature, are inherently imprecise. Other items in the Company’s unaudited condensed consolidated financial statements that involve the use of significant estimates include derivative assets and liabilities, accrued revenue, deferred and current income taxes, equity-based compensation, asset retirement obligations, depreciation, amortization, and commitments and contingencies. (d) Risks and Uncertainties The markets for natural gas, NGLs, and oil have, and continue to, experience significant price fluctuations. Price fluctuations can result from variations in weather, levels of production, availability of transportation capacity to other regions of the country, the level of imports to and exports from the United States, and various other factors. Increases or decreases in the prices the Company receives for its production could have a significant impact on the Company’s future results of operations and reserve quantities. (e) 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 and revenue distributions payable associated with book overdrafts as an operating activity within its unaudited condensed consolidated statements of cash flows. As of September 30, 2019, the book overdraft included within accounts payable and revenue distributions payable were $8 million and $34 million, respectively. As of December 31, 2018, the book overdraft included within accounts payable and revenue distributions payable were $10 million and $28 million, respectively. (f) Oil and Gas Properties The Company accounts for its natural gas, NGLs, and oil exploration and development activities under the successful efforts method of accounting. Under the successful efforts method, the costs incurred to acquire, drill, and complete productive wells, development wells, and undeveloped leases are capitalized. Oil and gas lease acquisition costs are also capitalized. Exploration costs, including personnel and other internal costs, geological and geophysical expenses, delay rentals for gas and oil leases, and costs associated with unsuccessful lease acquisitions are charged to expense as incurred. Exploratory drilling costs are initially capitalized, but charged to expense if the Company determines that the well does not contain reserves in commercially viable quantities. The Company reviews exploration costs related to wells-in- progress at the end of each quarter and makes a determination, based on known results of drilling at that time, whether the costs should continue to be capitalized pending further well testing and results, or charged to expense. The Company incurred no such charges to expense during the nine months ended September 30, 2018 and 2019. During the nine months ended September 30, 2019, we recorded an impairment charge of $26 million for design and initial costs related to pads that are no longer planned to be placed into service. The sale of a partial interest in a proved property is accounted for as a cost recovery, and no gain or loss is recognized as long as this treatment does not significantly affect the units-of- production amortization rate. A gain or loss is recognized for all other sales of producing properties. Unproved properties are assessed for impairment on a property-by- property basis, and any impairment in value is charged to expense. Impairment is assessed based on remaining lease terms, commodity price outlooks, and future plans to develop acreage, as well as drilling results, and reservoir performance of wells in the area. Unproved properties and the related costs are transferred to proved properties when reserves are discovered on, or otherwise attributed to, the property. Proceeds from sales of partial interests in unproved properties are accounted for as a recovery of cost without recognition of any gain or loss until the cost has been recovered. Impairment of unproved properties was $406 million and $347 million for the nine months ended September 30, 2018 and 2019, respectively. The Company evaluates the carrying amount of its proved natural gas, NGLs, and oil properties for impairment on a geological reservoir basis whenever events or changes in circumstances indicate that a property’s carrying amount may not be recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company would estimate the fair value of its properties and record an impairment charge for any excess of the carrying amount of the properties over the estimated fair value of the properties. Factors used to estimate fair value may include estimates of proved reserves, estimated future commodity prices, future production estimates, and anticipated capital expenditures, using a commensurate discount rate. As estimated undiscounted future net cash flows based on future commodity prices at September 30, 2019 exceeded the carrying amount of our proved properties in the Marcellus Shale at September 30, 2019, we did not further evaluate our Marcellus proved properties for impairment. However, the carrying amount of the Utica Shale exceeded the estimated undiscounted future cash flows based on future commodity prices at September 30, 2019. We estimated the fair value of the Utica Shale assets based on sales of other properties, estimates of proved reserves, estimated future commodity prices, and future production estimates. As a result, the Company recorded an impairment charge of $881 million related to proved properties in the Utica Shale during the three months ended September 30, 2019. The Company did not record any impairment expenses associated with its proved properties in the Marcellus Shale during the nine months ended September 30, 2018 and 2019. During the three months ended September 30, 2019, Antero completed a non-cash exchange of acreage and ownership interest in certain properties in West Virginia whereby the Company received 20,770 net acres primarily in Tyler and Wetzel Counties and delivered 18,857 net acres primarily in Wetzel and Marion Counties. In conjunction with the non-cash exchange, the Company also assumed certain gas gathering and processing obligations related to a portion of some of the properties. This exchange did not have a material impact on the timing and amount of future cash flows and no gain or loss was recorded related to this transaction. (g) Derivative Financial Instruments In order to manage its exposure to natural gas, NGLs, and oil price volatility, the Company enters into derivative transactions from time to time, which may include commodity swap agreements, basis swap agreements, collar agreements, and other similar agreements related to the price risk associated with the Company’s production. To the extent legal right of offset exists with a counterparty, the Company reports derivative assets and liabilities on a net basis. The Company has exposure to credit risk to the extent that the counterparty is unable to satisfy its settlement obligations. The Company actively monitors the creditworthiness of counterparties and assesses the impact, if any, on its derivative positions. The Company records derivative instruments on the unaudited condensed consolidated balance sheets as either assets or liabilities measured at fair value and records changes in the fair value of derivatives in current earnings as they occur. Changes in the fair value of commodity derivatives, including gains or losses on settled derivatives, are classified as revenues on the Company’s unaudited condensed consolidated statements of operations. The Company’s derivatives have not been designated as hedges for accounting purposes. (h) Asset Retirement Obligations The Company is obligated to dispose of certain long- lived assets upon their abandonment. The Company’s asset retirement obligations (“AROs”) relate primarily to its obligation to plug and abandon oil and gas wells at the end of their lives. AROs are recorded at estimated fair value, measured by reference to the expected future cash outflows required to satisfy the retirement obligations, which is then discounted at the Company’s credit-adjusted, risk- free interest rate. Revisions to estimated AROs often result from changes in retirement cost estimates or changes in the estimated timing of abandonment. The fair value of the liability is added to the carrying amount of the associated asset, and this additional carrying amount is depreciated over the life of the asset. The liability is accreted at the end of each period through charges to operating expense. (i) Industry Segments and Geographic Information Management has evaluated how the Company is organized and managed and has identified the following segments: (1) the exploration, development, and production of natural gas, NGLs, and oil; (2) marketing and utilization of excess firm transportation capacity and (3) our equity method investment in Antero Midstream Corporation. Through March 12, 2019, the results of Antero Midstream Partners were included in the consolidated financial statements of Antero. Effective March 13, 2019, the results of Antero Midstream Partners are no longer consolidated in Antero’s results; however, the Company’s segment disclosures include our equity method investment in Antero Midstream Corporation due to its significance to the Company’s operations. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions and Note 17 to the unaudited condensed consolidated financial statements for disclosures on the Company’s reportable segments. ​ 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. Our revenues received from these customers are denominated in U.S. dollars and are based on pricing in foreign markets. (j) 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—assuming dilution for each period is computed after giving consideration to the potential dilution from outstanding equity awards, calculated using the treasury stock method. The Company includes performance share unit awards 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 September 30, ​ Nine months ended September 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Basic weighted average number of shares outstanding ​ 317,082 ​ 307,781 ​ 316,850 ​ 308,509 ​ Add: Dilutive effect of restricted stock units ​ — ​ — ​ — ​ 27 ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ — ​ — ​ Add: Dilutive effect of performance stock units ​ — ​ — ​ — ​ 110 ​ Diluted weighted average number of shares outstanding ​ 317,082 ​ 307,781 ​ 316,850 ​ 308,646 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding equity awards excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ ​ ​ ​ ​ Restricted stock units ​ 2,813 ​ 2,356 ​ 2,996 ​ 2,008 ​ Outstanding stock options ​ 619 ​ 514 ​ 637 ​ 541 ​ Performance stock units ​ 1,880 ​ 2,676 ​ 1,665 ​ 2,141 ​ (1) The potential dilutive effects of these awards were excluded from the computation of earnings (loss) per common share—assuming dilution because the inclusion of these awards would have been anti-dilutive. (k) Treasury Share Retirement The Company retires treasury shares acquired through share repurchases and returns those shares to the status of authorized but unissued. When treasury shares are retired, the Company’s policy is to allocate the excess of the repurchase price over the par value of shares acquired first, to additional paid-in capital, and then to accumulated earnings. The portion allocable to additional paid-in capital is determined by applying a percentage, determined by dividing the number of shares to be retired by the number of shares outstanding, to the balance of additional paid-in capital as of retirement. (l) Adoption of New Accounting Principle The Company adopted ASU No. 2016-02, Leases , (“Topic 842”) as of January 1, 2019, using the effective date method. The effective date method allows the Company to report its leases under Topic 842 prospectively as of the date of adoption, and no retrospective adjustments were required for prior periods. ​ The Company elected the available practical expedients and updated internal controls to enable the preparation of financial information on adoption. ​ The standard had a material impact on our consolidated balance sheets, but did not have a material impact on our consolidated statements of operations. The most significant impact was the recognition of operating leases right-of-use assets and short-term and long-term lease liabilities for operating leases, while our accounting for finance leases remained substantially unchanged. See Note 12 to the unaudited condensed consolidated financial statements for a description of the Company’s leases.

Deconsolidation of Antero Midst

Deconsolidation of Antero Midstream Partners LP	9 Months Ended
	Sep. 30, 2019
Deconsolidation of Antero Midstream Partners LP
Deconsolidation of Antero Midstream Partners LP	(3) Deconsolidation of Antero Midstream Partners LP In 2014, the Company formed Antero Midstream Partners to own, operate, and develop midstream energy assets that service Antero’s production. Antero Midstream Partners’ assets consist of gathering systems and compression facilities, water handling and treatment facilities, and interests in processing and fractionation plants, through which it provides services to Antero under long-term, fixed-fee contracts. On March 12, 2019, Antero Midstream GP LP and Antero Midstream Partners completed (the “Closing”) the transactions contemplated by the Simplification Agreement (the “Simplification Agreement”), dated as of October 9, 2018, by and among Antero Midstream GP LP, Antero “Transactions”). In connection with the Closing, Antero received ​ Prior to the Closing, the Company’s ownership of Antero Midstream Partners common units represented approximately a 53% limited partner interest in Antero Midstream Partners, and the Company consolidated Antero Midstream Partners’ financial position and results of operations into its consolidated financial statements. The Transactions resulted in the exchange of limited partner interests in Antero interest. As a result, the Company no longer holds a controlling interest in Antero Partners and the Company now has an interest in Antero Midstream Corporation that provides significant influence, but not control, over Antero Midstream Corporation. Thus, effective March 13, 2019, the Company no longer consolidates Antero Partners in our consolidated financial statements and accounts for its interest in Antero Midstream Corporation using the equity method of accounting. In addition, the Company recorded a gain on deconsolidation of Partners. The fair value of Antero’s retained equity method investment on March 13, 2019 in Antero Midstream Corporation was billion based on the market price of the shares received on March 12, 2019. See Note 5 to the unaudited condensed consolidated financial statements for further discussion on equity method investments. ​ Antero Midstream Partners’ results of operations are no longer consolidated in the Company’s consolidated statement of operations and comprehensive income (loss) beginning March 13, 2019. Because Antero Partners’ results of operations continue to be included in the Company’s consolidated statement of operations and comprehensive income (loss) through March 12, 2019. ​ Summarized Financial Information of Antero Midstream Partners ​ The following table presents a summary of assets and liabilities of Antero Midstream Partners as of March 12, 2019, the date of deconsolidation. ​ ​ ​ ​ ​ ​ (in thousands) ​ March 12, 2019 ​ Current assets ​ $ 763,109 ​ Property and equipment, net ​ ​ 3,003,693 ​ Other noncurrent assets ​ ​ 501,208 ​ Total assets ​ $ 4,268,010 ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 123,473 ​ Long-term debt ​ ​ 2,359,084 ​ Other noncurrent liabilities ​ ​ 123,523 ​ Total liabilities ​ $ 2,606,080 ​ ​ ​ ​ ​ ​ Net assets ​ $ 1,661,930 ​ ​

Revenue

Revenue	9 Months Ended
	Sep. 30, 2019
Revenue
Revenue	(4) Revenue ​ (a) Revenue from Contracts with Customers ​ Product revenue Our revenues are primarily derived from the sale of natural gas and oil production, as well as the sale of NGLs that are extracted from our natural gas. Sales of natural gas, NGLs, and oil are recognized when we satisfy a performance obligation by transferring control of a product to a customer. Payment is generally received in the month following the sale. Under our natural gas sales contracts, we deliver natural gas to the purchaser at an agreed upon delivery point. Natural gas is transported from our wellheads to delivery points specified under sales contracts. To deliver natural gas to these points, Antero Midstream or third parties gather, compress, process and transport our natural gas. We maintain control of the natural gas during gathering, compression, processing, and transportation. Our sales contracts provide that we receive a specific index price adjusted for pricing differentials. We transfer control of the product at the delivery point and recognize revenue based on the contract price. The costs to gather, compress, process and transport the natural gas are recorded as Gathering, compression, processing and transportation expenses. NGLs, which are extracted from natural gas through processing, are either sold by us directly or by the processor under processing contracts. For NGLs sold by us directly, our sales contracts provide that we deliver the product to the purchaser at an agreed upon delivery point and that we receive a specific index price adjusted for pricing differentials. We transfer control of the product to the purchaser at the delivery point and recognize revenue based on the contract price. The costs to process and transport NGLs are recorded as Gathering, compression, processing, and transportation expenses. For NGLs sold by the processor, our processing contracts provide that we transfer control to the processor at the tailgate of the processing plant and we recognize revenue based on the price received from the processor. Under our oil sales contracts, we generally sell oil to purchasers and collect a contractually agreed upon index price, net of pricing differentials. We recognize revenue based on the contract price when we transfer control of the product to a purchaser. Gathering, compression, water handling and treatment revenue Substantially all revenues from the gathering, compression, water handling and treatment operations were derived from transactions for services Antero Midstream Partners provided to our exploration and production operations through March 12, 2019 and were eliminated in consolidation. no longer consolidated in Antero’s results. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions and Note 17 to the unaudited condensed consolidated financial statements for disclosures on the Company’s reportable segments . The portion of such fees shown in our consolidated financial statements prior to March 13, 2019 represent amounts charged to interest owners in Antero-operated wells, as well as fees charged to other third parties for water handling and treatment services provided by Antero Midstream gathering and compression systems. For gathering and compression revenue, Antero Midstream satisfies its performance obligations and recognizes revenue when low pressure volumes are delivered to a compressor station, high pressure volumes are delivered to a processing plant or transmission pipeline, and compression volumes are delivered to a high pressure line. Revenue is recognized based on the per Mcf gathering or compression fee charged by Antero Midstream in accordance with the gathering and compression agreement. For water handling and treatment revenue, Antero Midstream satisfies its performance obligations and recognizes revenue when the fresh water volumes have been delivered to the hydration unit of a specified well pad and the wastewater volumes have been delivered to its wastewater treatment facility. For services contracted through third-party providers, Antero Midstream performance obligation is satisfied when the service performed by the third-party provider has been completed. Revenue is recognized based on the per barrel fresh water delivery or wastewater treatment fee charged by Antero Midstream Marketing revenue Marketing revenues are derived from activities to purchase and sell third-party natural gas and NGLs and to market excess firm transportation capacity to third parties. We retain control of the purchased natural gas and NGLs prior to delivery to the purchaser. We have concluded that we are the principal in these arrangements and therefore we recognize revenue on a gross basis, with costs to purchase and transport natural gas and NGLs presented as marketing expenses. Contracts to sell third-party gas and NGLs are generally subject to similar terms as contracts to sell our produced natural gas and NGLs. We satisfy performance obligations to the purchaser by transferring control of the product at the delivery point and recognize revenue based on the price received from the purchaser. Fees generated from the sale of excess firm transportation marketed to third parties are included in revenue. ​ (b) Disaggregation of Revenue In the following table, revenue is disaggregated by type (in thousands). The table also identifies the reportable segment to which the disaggregated revenues relate. For more information on reportable segments, see Note 17— Segment Information. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, ​ Nine months ended September 30, ​ Segment to which ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ revenues relate ​ Revenues from contracts with customers: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 527,122 ​ ​ 524,448 ​ $ 1,498,324 ​ ​ 1,735,086 ​ Exploration and production ​ Natural gas liquids sales (ethane) ​ ​ 56,185 ​ ​ 26,488 ​ ​ 115,947 ​ ​ 92,378 ​ Exploration and production ​ Natural gas liquids sales (C3+ NGLs) ​ ​ 282,084 ​ ​ 258,470 ​ ​ 712,477 ​ ​ 810,228 ​ Exploration and production ​ Oil sales ​ ​ 59,722 ​ ​ 40,561 ​ ​ 128,869 ​ ​ 137,675 ​ Exploration and production ​ Gathering and compression (1) ​ 4,439 ​ — ​ ​ 12,848 ​ 3,972 ​ Equity method investment in AMC ​ Water handling and treatment (1) ​ ​ 405 ​ ​ — ​ ​ 2,450 ​ ​ 507 ​ Equity method investment in AMC ​ Marketing ​ ​ 89,598 ​ ​ 46,645 ​ ​ 394,189 ​ ​ 200,911 ​ Marketing ​ Total ​ 1,019,555 ​ 896,612 ​ ​ 2,865,104 ​ 2,980,757 ​ ​ ​ Income from derivatives and other sources ​ ​ 56,977 ​ ​ 222,269 ​ ​ 228,874 ​ ​ 475,195 ​ ​ ​ Total revenue and other ​ $ 1,076,532 ​ ​ 1,118,881 ​ $ 3,093,978 ​ ​ 3,455,952 ​ ​ ​ (1) Gathering and compression and water handling and treatment revenues were included through March 12, 2019. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. ​ (c) Transaction Price Allocated to Remaining Performance Obligations For our product sales that have a contract term greater than one year, we have utilized the practical expedient in 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 our 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 our product sales that have a contract term of one year or less, we have 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. (d) Contract Balances Under our sales contracts, we invoice customers after our performance obligations have been satisfied, at which point payment is unconditional. Accordingly, our contracts do not give rise to contract assets or liabilities under ASC 606. At December 31, 2018 and September 30, 2019, our receivables from contracts with customers were $475 million and $281 million, respectively.

Equity Method Investments

Equity Method Investments	9 Months Ended
	Sep. 30, 2019
Equity Method Investments.
Equity Method Investments	(5) Equity Method Investments At September 30, 2019, Antero owned approximately 31.5 % of Antero Midstream Corporation’s common stock, which is reflected in Antero’s consolidated financial statements using the equity method of accounting. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. Prior to March 13, 2019, our consolidated results included two equity method investments held by Antero Midstream Partners: a 15% equity interest in Stonewall Gas Gathering LLC (“Stonewall”), which operates a regional gathering pipeline on which Antero is an anchor shipper, and a 50 % interest in the joint venture entered into on February 6, 2017 between Antero Midstream Partners and MarkWest Energy Partners, L.P. (“MarkWest”), a wholly owned subsidiary of MPLX, LP, to develop processing and fractionation assets in Appalachia (the “Joint Venture”). Effective March 13, 2019, the equity in earnings of these investments are accounted for in the equity in earnings of Antero Midstream Corporation. The following table is a reconciliation of investments in unconsolidated affiliates for the nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stonewall (1) ​ MarkWest ​ Antero Midstream Corporation (2) ​ Total ​ Balance at December 31, 2018 ​ $ 68,103 ​ ​ 365,539 ​ ​ — ​ ​ 433,642 ​ Investments (3) ​ — ​ ​ 25,020 ​ ​ — ​ ​ 25,020 ​ Equity in net income of unconsolidated affiliates ​ ​ 1,894 ​ ​ 10,370 ​ ​ (102,457) ​ ​ (90,193) ​ Distributions/dividends from unconsolidated affiliates ​ (3,000) ​ ​ (9,605) ​ ​ (96,636) ​ ​ (109,241) ​ Elimination of intercompany profit ​ ​ — ​ ​ — ​ ​ 30,621 ​ ​ 30,621 ​ Effects of deconsolidation (4) ​ (66,997) ​ ​ (391,324) ​ ​ 1,987,795 ​ ​ 1,529,474 ​ Balance at September 30, 2019 ​ $ — ​ ​ — ​ ​ 1,819,323 ​ ​ 1,819,323 ​ (1) Distributions are net of operating and capital requirements retained by Stonewall. (2) As adjusted for the amortization of the difference between the cost of the equity investment in Antero Midstream Corporation and the amount of underlying equity in the net assets of Antero Midstream Partners as of the date of deconsolidation. (3) Investments in the Joint Venture during the nine months ended September 30, 2019 relate to capital contributions for construction of additional processing facilities. (4) Effective March 13, 2019, the equity in earnings of Stonewall and the Joint Venture are accounted for in the equity in earnings of Antero Midstream Corporation. Summarized Financial Information of Antero Midstream Corporation ​ The following tables present summarized financial information of Antero Midstream Corporation. Summarized financial information is presented from March 13, 2019. ​ Balance Sheet ​ ​ ​ ​ ​ ​ (in thousands) ​ September 30, 2019 ​ Current assets ​ $ 109,224 ​ Noncurrent assets ​ ​ 6,336,280 ​ Total assets ​ $ 6,445,504 ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 259,628 ​ Noncurrent liabilities ​ ​ 2,662,846 ​ Stockholders' equity ​ ​ 3,523,030 ​ Total liabilities and equity ​ $ 6,445,504 ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ For the period ​ ​ ​ ​ March 13, 2019 through ​ (in thousands) ​ September 30, 2019 ​ Revenues ​ $ 553,521 ​ Operating expenses ​ ​ 745,940 ​ Loss from operations ​ $ (192,419) ​ Net loss attributable to the equity method investments ​ $ (197,006) ​ ​

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2019
Accrued Liabilities
Accrued Liabilities	(6) Accrued Liabilities Accrued liabilities as of December 31, 2018 and September 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 September 30, 2019 ​ Capital expenditures ​ $ 113,237 ​ 83,963 ​ Gathering, compression, processing, and transportation expenses ​ ​ 148,032 ​ ​ 141,036 ​ Marketing expenses ​ ​ 67,082 ​ ​ 47,763 ​ Interest expense, net ​ 43,444 ​ 62,255 ​ Other ​ 93,275 ​ 57,709 ​ ​ ​ $ 465,070 ​ 392,726 ​ ​

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2019
Long-Term Debt.
Long-Term Debt	(7) Long-Term Debt ​ Long-term debt was as follows at December 31, 2018 and September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 September 30, 2019 ​ Antero Resources: ​ ​ ​ ​ ​ ​ ​ Credit Facility (a) ​ $ 405,000 ​ 275,000 ​ 5.375% senior notes due 2021 (b) ​ 1,000,000 ​ 1,000,000 ​ 5.125% senior notes due 2022 (c) ​ ​ 1,100,000 ​ ​ 1,100,000 ​ 5.625% senior notes due 2023 (d) ​ ​ 750,000 ​ ​ 750,000 ​ 5.00% senior notes due 2025 (e) ​ ​ 600,000 ​ ​ 600,000 ​ Net unamortized premium ​ 1,241 ​ 1,021 ​ Net unamortized debt issuance costs ​ ​ (26,700) ​ ​ (22,193) ​ Long-term debt ​ ​ 3,829,541 ​ ​ 3,703,828 ​ Antero Midstream Partners: ​ ​ ​ ​ ​ ​ ​ Midstream Credit Facility (1) ​ ​ 990,000 ​ ​ — ​ 5.375% senior notes due 2024 (1) ​ ​ 650,000 ​ ​ — ​ Net unamortized debt issuance costs (1) ​ ​ (7,853) ​ ​ — ​ Long-term debt ​ ​ 1,632,147 ​ ​ — ​ Consolidated long-term debt ​ $ 5,461,688 ​ 3,703,828 ​ (1) At December 31, 2018, Antero Midstream Partners’ indebtedness was included in the consolidated financial statements of Antero. At September 30, 2019, following the deconsolidation, Antero Midstream Partners’ outstanding indebtedness is no longer reflected in Antero’s consolidated financial statements. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. ​ (a) Senior Secured Revolving Credit Facility Antero 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’s assets and are subject to regular annual redeterminations. At September 30, 2019, the borrowing base under the Credit Facility was $4.5 billion and lender commitments were $2.5 billion. Each of these amounts were reaffirmed in the annual redetermination in April 2019. The next redetermination of the borrowing base is scheduled to occur in April 2020. The maturity date of the Credit Facility is the earlier of (i) October 26, 2022 and (ii) the date that is 91 days prior to the earliest stated redemption date of any series of Antero’s senior notes, unless such series of notes is refinanced. Under the Credit Facility, “Investment Grade Period” is a period that, as long as no event of default has occurred, commences when Antero elects to give notice to the Administrative Agent that Antero has received at least one of (i) a BBB- or better rating from Standard and Poor’s and (ii) a Baa3 or better rating from Moody’s (an “Investment Grade Rating”). An Investment Grade Period can end at Antero’s election. During any period that is not an Investment Grade Period, the Credit Facility is ratably secured by mortgages on substantially all of Antero’s properties, Antero’s and Antero Subsidiary Holdings LLC’s ownership interests in Antero Midstream Corporation, and guarantees from Antero’s restricted subsidiaries, as applicable. During an Investment Grade Period, the liens securing the obligations under the Credit Facility shall be automatically released (subject to the provisions of the Credit Facility). The Credit Facility contains certain covenants, including restrictions on indebtedness and dividends, and requirements with respect to working capital and interest coverage ratios. During any period that is not an Investment Grade Period, interest is payable at a variable rate based on LIBOR or the prime rate determined by Antero’s election at the time of borrowing, plus an applicable rate based on Antero’s borrowing base utilization which ranges from 25 basis points to 225 basis points. During an Investment Grade Period, interest is payable at a variable rate based on LIBOR or the prime rate determined by Antero’s election at the time of borrowing, plus an applicable rate based on Antero’s credit rating which ranges from 12.5 basis points to 175 basis points. Antero was in compliance with all of the financial covenants under the Credit Facility as of December 31, 2018 and September 30, 2019. At September 30, 2019, Antero had an outstanding balance under the Credit Facility of $275 million and outstanding letters of credit of $703 million. At December 31, 2018, Antero had an outstanding balance under the Credit Facility of $405 million and outstanding letters of credit of $685 million. The average annualized interest rate incurred on the Credit Facility during the nine months ended September 30, 2019 was approximately 4.39 %. Commitment fees on the unused portion of the Credit Facility are due quarterly at rates ranging from (i) 0.300% to 0.375% (during any period that is not an Investment Grade Period) of the unused portion based on utilization and (ii) 0.150% to 0.300% (during an Investment Grade Period) of the unused portion based on Antero’s credit rating. (b) 5.375% Senior Notes Due 2021 On November 5, 2013, Antero issued $1 billion of 5.375% senior notes due November 1, 2021 (the “2021 notes”) at par. The 2021 notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2021 notes rank pari passu to Antero’s other outstanding senior notes. The 2021 notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero’s wholly owned subsidiaries and certain of its future restricted subsidiaries. Interest on the 2021 notes is payable on May 1 and November 1 of each year. Antero may redeem all or part of the 2021 notes at any time at redemption prices ranging from 101.344% currently to 100.00% on or after November 1, 2019. If Antero undergoes a change of control followed by a rating decline, the holders of the 2021 notes will have the right to require Antero to repurchase all or a portion of the notes at a price equal to 101% of the principal amount of the 2021 notes, plus accrued and unpaid interest. (c) 5.125% Senior Notes Due 2022 On May 6, 2014, Antero issued $600 million of 5.125% senior notes due December 1, 2022 (the “2022 notes”) at par. On September 18, 2014, Antero issued an additional $500 million of the 2022 notes at 100.5 % of par. The 2022 notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2022 notes rank pari passu to Antero’s other outstanding senior notes. The 2022 notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero’s wholly owned subsidiaries and certain of its future restricted subsidiaries. Interest on the 2022 notes is payable on June 1 and December 1 of each year. Antero may redeem all or part of the 2022 notes at any time at redemption prices ranging from 101.281% currently to 100.00% on or after June 1, 2020. If Antero undergoes a change of control followed by a rating decline, the holders of the 2022 notes will have the right to require Antero to repurchase all or a portion of the notes at a price equal to 101% of the principal amount of the 2022 notes, plus accrued and unpaid interest. (d) 5.625% Senior Notes Due 2023 On March 17, 2015, Antero issued $750 million of 5.625% senior notes due June 1, 2023 (the “2023 notes”) at par. 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’s other outstanding senior notes. The 2023 notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero’s wholly owned subsidiaries and certain of its future restricted subsidiaries. Interest on the 2023 notes is payable on June 1 and December 1 of each year. Antero may redeem all or part of the 2023 notes at any time at redemption prices ranging from 102.813% to 100.00% on or after June 1, 2021. If Antero undergoes a change of control followed by a rating decline, the holders of the 2023 notes will have the right to require Antero 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. (e)  5.00% Senior Notes Due 2025 On December 21, 2016, Antero issued $600 million of 5.00 % senior notes due March 1, 2025 (the “2025 notes”) at par. 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’s other outstanding senior notes. The 2025 notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero’s wholly owned subsidiaries and certain of its future restricted subsidiaries. Interest on the 2025 notes is payable on March 1 and September 1 of each year. Antero may redeem all or part of the 2025 notes at any time on or after March 1, 2020 at redemption prices ranging from 103.750% on or after March 1, 2020 to 100.00 % on or after March 1, 2023. In addition, on or before March 1, 2020, Antero may redeem up to 35% of the aggregate principal amount of the 2025 notes with the net cash proceeds of certain equity offerings, if certain conditions are met, at a redemption price of 105.00 % of the principal amount of the 2025 notes, plus accrued and unpaid interest. At any time prior to March 1, 2020, Antero may also redeem the 2025 notes, in whole or in part, at a price equal to 100 % of the principal amount of the 2025 notes plus a “make-whole” premium and accrued and unpaid interest. If Antero undergoes a change of control followed by a rating decline, the holders of the 2025 notes will have the right to require Antero 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. (f) Treasury Management Facility Antero has a stand-alone revolving note with a lender that is also part of the Credit Facility lending consortium that provides for up to $25 million of cash management obligations in order to facilitate Antero’s daily treasury management. Borrowings under the revolving note are secured by the collateral for the Credit Facility. Borrowings under the revolving note bear interest at the lender’s prime rate plus 1.0 %. The note matures on June 1, 2020. At December 31, 2018, there was $5.4 million in outstanding borrowings under the revolving note included in “Other current liabilities” on the Company’s Consolidated Balance Sheet. At September 30, 2019, there were no outstanding borrowings under the revolving note.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligations
Asset Retirement Obligations	(8) Asset Retirement Obligations The following is a reconciliation of the Company’s asset retirement obligations for the nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ Asset retirement obligations—December 31, 2018 ​ $ 58,979 ​ Obligations settled ​ ​ (153) ​ Obligations incurred ​ 1,361 ​ Revisions to prior estimates ​ ​ — ​ Accretion expense ​ 2,821 ​ Effect of deconsolidation of Antero Midstream Partners LP (1) ​ (7,518) ​ Asset retirement obligations—September 30, 2019 ​ $ 55,490 ​ (1) ​ Asset retirement obligations are included in other liabilities on the Company’s unaudited condensed consolidated balance sheets.

Equity-Based Compensation

Equity-Based Compensation	9 Months Ended
	Sep. 30, 2019
Equity-Based Compensation
Equity-Based Compensation	(9) Equity-Based Compensation Antero is authorized to grant up to 16,906,500 shares of common stock to employees and directors of the Company under the Antero Resources Corporation Long-Term Incentive Plan (the “Plan”). The Plan allows equity-based compensation awards to be granted in a variety of forms, including stock options, stock appreciation rights, restricted stock awards, restricted stock unit awards, dividend equivalent awards, and other types of awards. The terms and conditions of the awards granted are established by the Compensation Committee of Antero’s Board of Directors. A total of 6,046,007 shares were available for future grant under the Plan as of September 30, 2019. 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). As part of the Transactions, each of the outstanding phantom units in the AMP Plan, whether vested or unvested, were assumed by Antero Midstream Corporation and converted into restricted stock units under the Antero Midstream Corporation Long Term Incentive Plan (the “AMC Plan”) representing a right to receive 1.8926 shares of Antero Midstream Corporation’s Common Stock, par value $0.01 per share (“Antero Midstream Corporation Common Stock”), for each converted phantom unit. On March 12, 2019, the Board of Antero Midstream Corporation adopted the AMC Plan under which awards may be granted to employees, directors and other service providers of Antero and its affiliates. The AMC Plan provides for the grant of stock options, stock appreciation rights, restricted stock, restricted stock units, dividend equivalents, other stock-based awards, cash awards and substitute awards. ​ The Company’s equity-based compensation expense, by type of award, was as follows for the three and nine months ended September 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, ​ Nine months ended September 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Restricted stock unit awards ​ $ 10,001 ​ ​ 2,229 ​ $ 33,676 ​ ​ 8,829 ​ Stock options ​ ​ 452 ​ ​ — ​ ​ 1,428 ​ ​ 389 ​ Performance share unit awards ​ ​ 1,017 ​ ​ 399 ​ ​ 7,018 ​ ​ 6,027 ​ Antero Midstream Partners phantom unit awards (1) ​ ​ 4,193 ​ ​ 867 ​ ​ 12,752 ​ ​ 2,942 ​ Equity awards issued to directors ​ ​ 539 ​ ​ 380 ​ ​ 1,555 ​ ​ 1,140 ​ Total expense ​ $ 16,202 ​ ​ 3,875 ​ $ 56,429 ​ ​ 19,327 ​ (1) Partners to Antero. Antero allocates a portion of equity-based compensation expense related to grants prior to the Transactions to Antero Partners based on its proportionate share of Antero’s labor costs. Through March 12, 2019, the total amount of equity-based compensation is included in the consolidated financial statements of Antero; and effective March 13, 2019 (date of deconsolidation), the amount allocated to Antero Partners is no longer reflected in Antero’s consolidated financial statements. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. ​ Restricted Stock Unit Awards Restricted stock unit awards vest subject to the satisfaction of service requirements. Expense related to each restricted stock unit award is recognized on a straight-line basis over the requisite service period of the entire award. Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. The grant date fair values of these awards are determined based on the closing price of Antero’s common stock on the date of the grant. A summary of restricted stock unit award activity for the nine months ended September 30, 2019 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ Aggregate ​ ​ Number of grant date intrinsic value ​ Total awarded and unvested—December 31, 2018 1,712,485 ​ $ 24.57 ​ $ 16,080 ​ Granted 1,610,690 ​ $ 8.60 ​ ​ ​ ​ Vested (718,192) ​ $ 27.70 ​ ​ ​ ​ Forfeited (307,938) ​ $ 16.56 ​ ​ ​ ​ Total awarded and unvested—September 30, 2019 2,297,045 ​ $ 13.47 ​ $ 6,937 ​ ​ Intrinsic values are based on the closing price of Antero’s common stock on the referenced dates. As of September 30, 2019, there was $25 million of unamortized equity-based compensation expense related to unvested restricted stock units. That expense is expected to be recognized over a weighted average period of approximately 2.6 years. Stock Options Stock options granted under the Plan have a maximum contractual life of 10 years . Expense related to stock options is recognized on a straight-line basis over the requisite service period of the entire award. Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. Stock options were granted with an exercise price equal to or greater than the market price of Antero’s common stock on the dates of grant. A summary of stock option activity for the nine months ended September 30, 2019 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ average ​ Intrinsic ​ ​ Stock exercise ​ contractual value Outstanding at December 31, 2018 579,617 ​ $ 50.55 ​ 5.81 ​ $ — ​ Granted — ​ $ — ​ ​ ​ ​ ​ ​ ​ Exercised — ​ $ — ​ ​ ​ ​ ​ ​ ​ Forfeited (79,484) ​ $ 50.25 ​ ​ ​ ​ ​ ​ ​ Expired — ​ $ — ​ ​ ​ ​ ​ ​ ​ Outstanding at September 30, 2019 500,133 ​ $ 50.60 ​ 4.98 ​ $ — ​ Vested or expected to vest as of September 30, 2019 500,133 ​ $ 50.60 ​ 4.98 ​ $ — ​ Exercisable at September 30, 2019 500,133 ​ $ 50.60 ​ ​ 4.98 ​ $ — ​ ​ Intrinsic values are based on the exercise price of the options and the closing price of Antero’s common stock on the referenced dates. A Black Scholes option pricing model is used to determine the grant-date fair value of stock options. Expected volatility was derived from the volatility of the historical stock prices of a peer group of similar publicly traded companies’ stock prices as Antero’s common stock had traded for a relatively short period of time at the dates the options were granted. The risk free interest rate was determined using the implied yield available for zero coupon U.S. government issues with a remaining term approximating the expected life of the options. A dividend yield of zero was assumed. As of September 30, 2019, there was no unamortized equity-based compensation expense because all stock options were fully vested. Performance Share Unit Awards Performance Share Unit Awards Based on Stock Price Targets In 2016, the Company granted performance share unit awards (“PSUs”) to certain of its executive officers that are based on stock price targets. The vesting of these PSUs is conditioned on the closing price of Antero’s common stock achieving specific price thresholds over 10 -day periods, subject to the following vesting restrictions: no PSUs may vest before the first anniversary of the grant date; no more than one-third of the PSUs may vest before the second anniversary of the grant date; and no more than two-thirds of the PSUs may vest before the third anniversary of the grant date. Any PSUs which have not vested by the fifth anniversary of the grant date will expire. Expense related to these PSUs is recognized on a graded basis over three years . Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. Performance Share Unit Awards Based on Total Shareholder Return (“TSR”) In 2016 and 2017, the Company granted PSUs to certain of its employees and executive officers that vest based on the TSR of Antero’s common stock relative to the TSR of a peer group of companies over a three-year performance period. The number of shares of common stock which may ultimately be earned ranges from zero to 200 % of the PSUs granted. Expense related to these PSUs is recognized on a straight-line basis over three years . Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. In 2019, the Company granted PSUs to certain of its employees and executive officers that vest based on Antero’s absolute TSR, with target payout achieved if the price per share of Antero’s common stock reaches 125% of the beginning price (as defined in the award agreement) at the end of a three-year performance period. The number of shares of common stock which may ultimately be earned ranges from zero to 200 % of the PSUs granted. Expense related to these PSUs is recognized on a straight-line basis over three years . Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. ​ Performance Share Unit Awards Based on TSR and Return on Capital Employed (“ROCE”) In 2018, the Company granted PSUs to certain of its employees and executive officers, a portion of which vest based on the Company’s absolute TSR, with target payout achieved if the price per share of Antero’s common stock reaches 125% of the beginning price (as defined in the award agreement) at the end of a three-year performance period (“TSR PSUs”). The number of awards actually earned with respect to the TSR PSUs will be subject to further adjustment based on the TSR of Antero’s common stock relative to the TSR of a peer group of companies over the same period. The number of shares of common stock that may ultimately be earned with respect to the TSR PSUs ranges from zero to 200 % of the target number of TSR PSUs originally granted. Expense related to the TSR PSUs is recognized on a straight-line basis over three years . Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. The other portion of the PSUs granted in 2018 vest based on the Company’s actual ROCE (as defined in the award agreement) over a three-year period as compared to a targeted ROCE (“ROCE PSUs”). The number of shares of common stock that may ultimately be earned with respect to the ROCE PSUs ranges from zero to 200 % of the target number of ROCE PSUs originally granted. Expense related to the ROCE PSUs is recognized based on the number of shares of common stock that are expected to be issued at the end of the measurement period, and is reversed if the likelihood of achieving the performance condition decreases. Summary Information for Performance Share Unit Awards A summary of PSU activity for the nine months ended September 30, 2019 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Number of ​ Weighted ​ Total awarded and unvested—December 31, 2018 1,767,299 ​ $ 26.36 ​ Granted 1,416,378 ​ $ 9.26 ​ Vested (31,944) ​ $ 27.38 ​ Forfeited (614,450) ​ $ 26.61 ​ Total awarded and unvested—September 30, 2019 2,537,283 ​ $ 16.74 ​ ​ The grant-date fair values of market-based PSUs were determined using Monte Carlo simulations, which use a probabilistic approach for estimating the fair values of the awards. Expected volatilities were derived from the volatility of the historical stock prices of a peer group of similar publicly-traded companies. The risk-free interest rate was determined using the yield available for zero-coupon U.S. government issues with remaining terms corresponding to the service periods of the PSUs. A dividend yield of zero was assumed. The grant-date fair value for the ROCE-based PSUs is based on the closing price of Antero’s common stock on the date of the grant, assuming the achievement of the performance condition. The following table presents information regarding the weighted average fair values for market-based PSUs granted during the nine months ended September 30, 2018 and 2019, and the assumptions used to determine the fair values: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, ​ ​ ​ ​ 2018 ​ ​ 2019 ​ ​ Dividend yield ​ ​ — % ​ ​ — % ​ Volatility ​ ​ 41 % ​ ​ 36 % ​ Risk-free interest rate ​ ​ 2.49 % ​ ​ 2.35 % ​ Weighted average fair value of awards granted ​ $ 24.85 ​ ​ $ 9.26 ​ ​ ​ As of September 30, 2019, there was $20 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 1.9 years. Antero Midstream Partners Phantom Unit Awards and Antero Midstream Corporation Restricted Stock Unit Awards Phantom units granted by Antero Midstream Partners vested subject to the satisfaction of service requirements, upon the completion of which common units in Antero Midstream Partners were delivered to the holder of the phantom units. Phantom units also contained distribution equivalent rights which entitled the holder of vested common units to receive a “catch up” payment equal to common unit distributions paid by Antero Partners during the vesting period of the phantom unit award. These phantom units were treated, for accounting purposes, as if Antero Partners distributed the units to Antero. Antero recognized compensation expense as the units were granted to its employees, and a portion of the expense was allocated to Antero Partners. Expense related to each phantom unit award was recognized on a straight-line basis over the requisite service period of the entire award. Forfeitures were accounted for as they occurred by reversing the expense previously recognized for awards that were forfeited during the period. The grant date fair values of these awards was determined based on the closing price of Antero In connection with the closing of the Transactions, the Board of Antero Midstream Corporation adopted the AMC Plan. In accordance with the terms of the Transactions, each of the outstanding units in the AMP Plan, whether vested or unvested, was assumed by Antero Midstream Corporation and converted into restricted stock units under the AMC Plan at 1.8926 shares of Antero Midstream Corporation Common Stock LTIP for each converted phantom unit. ​ A summary of phantom unit awards activity for the nine months ended September 30, 2019 is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Number of ​ Weighted ​ Aggregate ​ Total awarded and unvested—December 31, 2018 583,000 ​ $ 27.63 ​ $ 12,470 ​ Granted 5,972 ​ $ 23.44 ​ ​ ​ ​ Vested (3,853) ​ $ 32.44 ​ ​ ​ ​ Forfeited (20,338) ​ $ 26.73 ​ ​ ​ ​ AMP Plan Units awarded and unvested—March 12, 2019 ​ 564,781 ​ $ 27.59 ​ $ 13,476 ​ Effect of conversion (1) 504,119 ​ $ 14.58 ​ ​ ​ ​ Vested (358,831) ​ $ 14.34 ​ ​ ​ ​ Forfeited (45,803) ​ $ 14.58 ​ ​ ​ ​ Total awarded and unvested—September 30, 2019 664,266 ​ $ 14.70 ​ $ 4,916 ​ (1) ​ Intrinsic values are based on the closing price of shares of Antero Midstream Corporation’s common stock or Antero Midstream Partners’ common units, as applicable, on the referenced dates. As of September 30, 2019, there was $7.6 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 1.9 years.

Financial Instruments

Financial Instruments	9 Months Ended
	Sep. 30, 2019
Financial Instruments
Financial Instruments	(10) Financial Instruments The carrying values of accounts receivable and accounts payable at December 31, 2018 and September 30, 2019 approximated market values because of their short-term nature. The carrying values of the amounts outstanding under the Credit Facility and Antero Midstream Partners’ credit facility at December 31, 2018 and the Credit Facility at September 30, 2019 approximated fair value because the variable interest rates are reflective of current market conditions. Based on Level 2 market data inputs, the fair value of senior notes was approximately $3.9 billion and $3.1 billion at December 31, 2018 and September 30, 2019, respectively. See Note 11 to the unaudited condensed consolidated financial statements for information regarding the fair value of derivative financial instruments.

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2019
Derivative Instruments.
Derivative Instruments	(11) Derivative Instruments (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 nine months ended September 30, 2018 and 2019. 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 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. ​ In addition, the Company has entered into natural gas collar contracts, which establish ceiling and floor prices for the sale of notional volumes of natural gas as specified in the collar contracts. Under these contracts, the Company pays the difference between the ceiling price and the published index price in the event the published index price is above the ceiling price. When the published index price is below the floor price, the Company receives the difference between the floor price and the published index price. No amounts are paid or received if the index price is between the floor and the ceiling prices. The index prices in our collars are consistent with the index prices used to sell our production. The Company’s derivative contracts have not been designated as hedges for accounting purposes; therefore, all gains and losses are recognized in the Company’s statements of operations. As of September 30, 2019, the Company’s fixed price natural gas, oil and NGL swap positions from October 1, 2019 through December 31, 2023 were as follows (abbreviations in the table refer to the index to which the swap position is tied, as follows: NYMEX=Henry Hub; NYMEX-WTI=West Texas Intermediate; ARA Butane =European Butane CIF ARA; FEI Butane = Butane Far East Asia Index; ARA Propane =European Propane CIF ARA; FEI Propane = Propane Far East Asia Index; Mont Belvieu Propane Non-TET=Mont Belvieu Propane; Mont Belvieu Butane Non-TET=Mont Belvieu Butane; Mont Belvieu Natural Gasoline Non-TET=Mont Belvieu Natural Gasoline): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas ​ ​ Natural Gas ​ ​ Oil ​ Weighted ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 996,766 ​ ​ — ​ ​ — ​ $ 3.23 ​ ARA Propane ($/Gal) ​ — ​ ​ 10,113 ​ ​ — ​ ​ 0.68 ​ FEI Propane ($/Gal) ​ — ​ ​ 9,809 ​ ​ — ​ ​ 0.81 ​ Mont Belvieu Propane Non-TET ($/Gal) ​ — ​ ​ 8,000 ​ ​ — ​ ​ 0.50 ​ Mont Belvieu Butane Non-TET ($/Gal) ​ — ​ ​ 4,000 ​ ​ — ​ ​ 0.59 ​ Mont Belvieu Natural Gasoline Non-TET ($/Gal) ​ — ​ ​ 3,500 ​ ​ — ​ ​ 1.14 ​ NYMEX-WTI ($/Bbl) ​ — ​ ​ — ​ ​ 18,000 ​ ​ 59.05 ​ Total ​ 996,766 ​ ​ 35,422 ​ ​ 18,000 ​ ​ ​ ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 2,227,500 ​ ​ ​ ​ ​ — ​ $ 2.87 ​ ARA Propane ($/Gal) ​ — ​ ​ 9,761 ​ ​ — ​ ​ 0.65 ​ FEI Propane ($/Gal) ​ — ​ ​ 2,045 ​ ​ — ​ ​ 0.81 ​ Mont Belvieu Butane Non-TET ($/Gal) ​ — ​ ​ 2,000 ​ ​ — ​ ​ 0.57 ​ NYMEX-WTI ($/Bbl) ​ — ​ ​ ​ ​ ​ 12,000 ​ ​ 56.60 ​ Total ​ 2,227,500 ​ ​ 13,806 ​ ​ 12,000 ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 2,110,000 ​ ​ ​ ​ ​ ​ ​ $ 2.79 ​ Year ending December 31, 2022: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 290,000 ​ ​ ​ ​ ​ ​ ​ $ 2.96 ​ Year ending December 31, 2023: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 90,000 ​ ​ ​ ​ ​ ​ ​ $ 2.91 ​ ​ ​ As of September 30, 2019, the Company’s natural gas basis swap positions, which settle on the pricing index to basis differential of TCO to the NYMEX Henry Hub natural gas price, and NGL basis swap positions, which settle on the pricing index to basis differential of Mont Belvieu Butane to the European Butane CIF ARA natural gas liquids price, were as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas MMBtu/day ​ ​ Natural Gas ​ Weighted average hedged differential ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ARA to Mont Belvieu Non-TET ($/Gal) ​ — ​ ​ 4,050 ​ $ 0.25 ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 60,000 ​ ​ — ​ ​ 0.353 ​ ARA to Mont Belvieu Non-TET ($/Gal) ​ — ​ ​ 4,273 ​ $ 0.23 ​ Total ​ 60,000 ​ ​ 4,273 ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 40,000 ​ ​ — ​ $ 0.414 ​ Year ending December 31, 2022: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 60,000 ​ ​ — ​ $ 0.515 ​ Year ending December 31, 2023: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 50,000 ​ ​ — ​ $ 0.525 ​ Year ending December 31, 2024: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 50,000 ​ ​ — ​ $ 0.530 ​ ​ As of September 30, 2019, the Company had natural gas and NGL contracts for October 1, 2019 through December 31, 2021 that fix the Mont Belvieu index price to percentages of WTI as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural Gas Liquids Bbls/day ​ Weighted average payout ratio ​ ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ Mont Belvieu Propane to NYMEX-WTI ​ 500 ​ ​ 50 % ​ Mont Belvieu Natural Gasoline to NYMEX-WTI ​ 13,900 ​ ​ 81 % ​ Total ​ 14,400 ​ ​ ​ ​ ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ Mont Belvieu Propane to NYMEX-WTI ​ 500 ​ ​ 50 % ​ Mont Belvieu Natural Gasoline to NYMEX-WTI ​ 15,000 ​ ​ 79 % ​ Total ​ 15,500 ​ ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ Mont Belvieu Natural Gasoline to NYMEX-WTI ​ 13,000 ​ ​ 78 % ​ ​ As of September 30, 2019, the Company’s fixed price natural gas collar positions from October 1, 2019 through December 31, 2019 were as follows (abbreviations in the table refer to the index to which the collar position is tied, as follows (NYMEX=Henry Hub): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas (MMBtu/day) ​ Weighted average index price ​ ​ Ceiling ​ Floor ​ Ceiling price ​ Floor price ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,575,000 ​ ​ 1,333,234 ​ $ 3.52 ​ $ 2.50 ​ ​ An initial premium of $13 million was paid at the inception of natural gas collar contracts with one counterparty, and is recorded as a derivative asset measured at fair value. As of September 30, 2019, the unamortized portion of the premium was $4.5 million. ​ (b) Marketing Derivatives In 2017, due to delay of the in-service date for a pipeline on which the Company is an anchor shipper, the Company realized it would not be able to fulfill its delivery obligations under a 2018 natural gas sales contract. In order to acquire gas to fulfill its delivery obligations, the Company entered into several natural gas purchase agreements with index-based pricing to purchase gas for resale under this sales contract. Subsequently, the Company and the counterparty to the sales contract came to an agreement that the Company’s delivery obligations under the contract would not begin until the earlier of (1) the in-service date of the pipeline and (2) January 1, 2019. Consequently, in December 2017, the Company entered into natural gas sales agreements with index-based pricing to resell the purchased gas for delivery during the period from February to October 2018. The natural gas that it had purchased for January was sold on the spot market during January. The Company determined that these gas purchase and sales agreements should be accounted for as derivatives and measured at fair value at the end of each period. For the three and nine months ended September 30, 2018, the Company recognized a fair value loss of less than $1 million and a gain of $94 million, respectively. There were no marketing derivative fair value gains or losses during the three or nine months ended September 30, 2019. (c) Summary The following table presents a summary of the fair values of the Company’s derivative instruments and where such values are recorded in the consolidated balance sheets as of December 31, 2018 and September 30, 2019. None of the Company’s derivative instruments are designated as hedges for accounting purposes. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ September 30, 2019 ​ ​ ​ Balance sheet ​ Fair value ​ Balance sheet ​ Fair value ​ ​ ​ ​ ​ (In thousands) ​ ​ ​ (In thousands) ​ Asset derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives - current ​ Derivative instruments ​ $ 245,263 ​ Derivative instruments ​ $ 411,774 ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ 362,169 ​ Derivative instruments ​ ​ 405,180 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total asset derivatives ​ ​ ​ ​ 607,432 ​ ​ ​ ​ 816,954 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liability derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives - current ​ Derivative instruments ​ ​ 532 ​ Derivative instruments ​ ​ — ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ — ​ Derivative instruments ​ ​ — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total liability derivatives ​ ​ ​ ​ 532 ​ ​ ​ ​ — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net derivatives ​ ​ ​ $ 606,900 ​ ​ ​ $ 816,954 ​ ​ 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 consolidated balance sheets as of the dates presented, all at fair value (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ September 30, 2019 ​ ​ ​ Gross ​ Gross amounts ​ Net amounts ​ Gross ​ Gross amounts ​ Net amounts Commodity derivative assets ​ $ 658,830 ​ (51,398) ​ 607,432 ​ $ 838,795 ​ (21,841) ​ 816,954 ​ Commodity derivative liabilities ​ $ (51,930) ​ 51,398 ​ (532) ​ $ (21,841) ​ 21,841 ​ — ​ ​ 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 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Statement of ​ Three months ended September 30, ​ Nine months ended September 30, ​ ​ ​ location ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Commodity derivative fair value gains ​ Revenue ​ $ 57,019 ​ ​ 220,788 ​ ​ 134,793 ​ ​ 471,847 ​ Marketing derivative fair value gains (losses) ​ Revenue ​ $ (42) ​ ​ — ​ ​ 94,081 ​ ​ — ​ ​ The fair value of derivative instruments was determined using Level 2 inputs.

Leases

Leases	9 Months Ended
	Sep. 30, 2019
Leases
Leases	(12) Leases ​ On February 25, 2016, the FASB issued Accounting Standard Update (“ASU”) No. 2016-02, Leases The Company is a lessee to both operating and finance lease arrangements. The standard resulted in an increased in assets and liabilities related to our operating leases. ​ The Company leases certain office space, processing plants, drilling rigs and completion services, gas gathering lines, compressor stations, and other office and field equipment. Leases with an initial term of 12 months or less are considered short-term and are not recorded on the balance sheet. Instead, the short-term leases are recognized in expense on a straight-line basis over the lease term. ​ Most leases include one or more options to renew, with renewal terms that can extend the lease from one to 20 years or more. The exercise of the lease renewal options are 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 has elected the effective date method for adoption of the new leasing standard under Topic 842. This method allows the Company to not make retrospective adjustments for leases that were in effect prior to the adoption date of January 1, 2019 when disclosing comparable prior periods, but instead, account for the prior period leases under Topic 840, which was the guidance in place at the time of the original reporting. ​ 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 under Topic 842. 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. The Company used the collateralized incremental borrowing rate, adjusted for length of lease term, for all of its present value calculations at the initial adoption of Topic 842. ​ 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. ​ Supplemental Balance Sheet Information Related to Leases ​ The Company’s lease assets as of September 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Right-of-use Assets: ​ ​ ​ ​ ​ ​ ​ Processing plants ​ $ 1,554,601 ​ ​ — ​ Drilling rigs and completion services ​ ​ 93,846 ​ ​ — ​ Gas gathering lines and compressor stations (1) ​ ​ 1,535,146 ​ ​ — ​ Office space ​ ​ 41,285 ​ ​ — ​ Vehicles ​ ​ 4,971 ​ ​ 2,591 ​ Other office and field equipment ​ ​ 299 ​ ​ 448 ​ Total right-of-use assets ​ $ 3,230,148 ​ ​ 3,039 (2) (1) Gas gathering lines and compressor stations leases includes $1.3 billion related to Antero Midstream Corporation. (2) Financing lease assets are recorded net of accumulated amortization of $9 million as of September 30, 2019. ​ The Company’s lease liabilities as of September 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Location on the balance sheet: ​ ​ ​ ​ ​ ​ ​ Short-term lease liabilities ​ $ 408,814 ​ ​ 1,176 ​ Long-term lease liabilities ​ ​ 2,821,334 ​ ​ 1,863 ​ Total lease liabilities ​ $ 3,230,148 ​ ​ 3,039 ​ ​ The processing plants, gathering lines and compressor stations that are classified as lease liabilities are classified as such under ASC 842 because Antero is the sole customer of the assets and because Antero makes the decisions that most impact the economic performance of the assets. ​ Supplemental Information Related to Leases ​ Costs associated with operating leases were included in the statement of operations and comprehensive income (loss) for the three and nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ Statement of Operations Location ​ Three months ended September 30, 2019 ​ Nine months ended September 30, 2019 Gathering, compression, processing, and transportation ​ $ 237,618 ​ $ 644,007 General and administrative ​ ​ 2,859 ​ ​ 8,395 Contract termination and rig stacking ​ ​ — ​ ​ 10,692 Total Lease Expense ​ $ 240,477 ​ $ 663,094 ​ Costs associated with finance leases of less than $1 million for each of the three and nine months ended September 30, 2019 were included in interest expense. ​ We capitalized $53 million and $161 million, respectively, of costs related to operating leases and less than $1 million of costs related to finance leases during each of the three and nine months ended September 30, 2019, respectively. ​ Short-term lease costs that are more than one month but less than 12 months are excluded from the above amounts and total $115 million at September 30, 2019. ​ Supplemental Cash Flow Information Related to Leases ​ The following is the Company’s supplemental cash flow information related to leases for the three and nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, 2019 ​ Nine months ended September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Operating Leases ​ Finance Leases ​ Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating cash out flows related to operating leases ​ $ 234,399 ​ ​ — ​ $ 591,963 ​ ​ — ​ Investing cash out flows related to operating leases ​ ​ 47,417 ​ ​ — ​ ​ 146,315 ​ ​ — ​ Financing cash out flows related to financing leases ​ ​ — ​ ​ 303 ​ ​ — ​ ​ 1,967 ​ ​ ​ ​ 281,816 ​ ​ 303 ​ ​ 738,278 ​ ​ 1,967 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Noncash activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Right of use assets obtained in exchange for operating lease liabilities ​ ​ — ​ ​ — ​ ​ 3,345,549 ​ ​ — ​ Right of use assets obtained in exchange for financing lease liabilities ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ Maturities of Lease Liabilities ​ The table below is a schedule of future minimum payments for operating and financing lease liabilities as of September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2019 ​ $ 151,345 ​ ​ 21 ​ ​ 151,366 ​ 2020 ​ ​ 578,615 ​ ​ 523 ​ ​ 579,138 ​ 2021 ​ ​ 506,402 ​ ​ 1,152 ​ ​ 507,554 ​ 2022 ​ ​ 495,694 ​ ​ 1,298 ​ ​ 496,992 ​ 2023 ​ ​ 491,513 ​ ​ 45 ​ ​ 491,558 ​ 2024 ​ ​ 482,745 ​ ​ — ​ ​ 482,745 ​ Thereafter ​ ​ 1,447,537 ​ ​ — ​ ​ 1,447,537 ​ Total lease payments ​ ​ 4,153,851 ​ ​ 3,039 ​ ​ 4,156,890 ​ Less: imputed interest ​ ​ (923,703) ​ ​ — ​ ​ (923,703) ​ Total ​ $ 3,230,148 ​ ​ 3,039 ​ ​ 3,233,187 ​ ​ As of December 31, 2018, the following future minimum payments were required for office and equipment leases: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Office Leases ​ Equipment Leases ​ Total ​ 2019 ​ $ 8,630 ​ ​ 6,042 ​ ​ 14,672 ​ 2020 ​ ​ 8,471 ​ ​ 4,517 ​ ​ 12,988 ​ 2021 ​ ​ 8,450 ​ ​ 2,410 ​ ​ 10,860 ​ 2022 ​ ​ 8,427 ​ ​ 274 ​ ​ 8,701 ​ 2023 ​ ​ 7,495 ​ ​ — ​ ​ 7,495 ​ Thereafter ​ ​ 49,367 ​ ​ — ​ ​ 49,367 ​ Total ​ $ 90,840 ​ ​ 13,243 ​ ​ 104,083 ​ ​ ​ Lease Term and Discount Rate ​ The table below is the Company’s weighted-average remaining lease term and discount rate as of September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Weighted-average remaining lease term: ​ ​ 8.4 years ​ ​ 2.1 years ​ Weighted-average discount rate: ​ ​ 6.1 % ​ 5.7 % ​ As of September 30, 2019, the Company had requested additional processing capacity which will be accounted for as lease modifications when the processing capacity becomes available in 2019 and 2020. ​ 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 we request 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 . For the three and nine months ended September 30, 2019, gathering and compression fees paid by Antero related to this agreement were million, respectively. As of September 30, 2019,

Commitments

Commitments	9 Months Ended
	Sep. 30, 2019
Commitments
Commitments	(13) Commitments ​ The table below is 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 September 30, 2019 (in thousands). ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Firm ​ Processing, ​ Land payment obligations ​ Operating and Financing Leases ​ Imputed Interest for Leases ​ ​ ​ ​ ​ (a) ​ (b) ​ (c) ​ (d) ​ (d) ​ Total ​ Remainder of 2019 ​ $ 282,571 ​ ​ 13,667 ​ ​ 4,653 ​ ​ 102,808 ​ ​ 48,558 ​ ​ 452,257 ​ 2020 ​ ​ 1,123,782 ​ ​ 54,425 ​ ​ 5,557 ​ ​ 399,881 ​ ​ 179,257 ​ ​ 1,762,902 ​ 2021 ​ ​ 1,100,079 ​ ​ 54,093 ​ ​ 3,177 ​ ​ 350,364 ​ ​ 157,190 ​ ​ 1,664,903 ​ 2022 ​ ​ 1,047,162 ​ ​ 53,606 ​ ​ 259 ​ ​ 361,057 ​ ​ 135,935 ​ ​ 1,598,019 ​ 2023 ​ ​ 1,034,641 ​ ​ 58,565 ​ ​ — ​ ​ 377,836 ​ ​ 113,722 ​ ​ 1,584,764 ​ 2024 ​ ​ 994,534 ​ ​ 58,687 ​ ​ — ​ ​ 392,323 ​ ​ 90,422 ​ ​ 1,535,966 ​ Thereafter ​ ​ 7,816,594 ​ ​ 152,523 ​ ​ — ​ ​ 1,248,918 ​ ​ 198,619 ​ ​ 9,416,654 ​ Total ​ $ 13,399,363 ​ ​ 445,566 ​ ​ 13,646 ​ ​ 3,233,187 ​ ​ 923,703 ​ ​ 18,015,465 ​ ​ (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 consolidated financial statements its proportionate share of costs based on its working interest. None of these agreements were determined to be leases. (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 consolidated financial statements its proportionate share of costs based on its working interest. The values in the table also include minimum processing fees to be paid to the Joint Venture owned by Antero Partners and MarkWest. (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 we are committed to pay; however, we will record in our financial statements our proportionate share of costs based on our working interests. Refer to Note 12 to the unaudited condensed consolidated financial statements for more information on the Company’s operating and finance leases.

Contingencies

Contingencies	9 Months Ended
	Sep. 30, 2019
Contingencies
Contingencies	​ (14) Contingencies Environmental As disclosed previously in our 2018 10-K, in June 2018, following site inspections conducted in September 2017 at certain of our facilities located in Doddridge County, Tyler County, and Ritchie County, West Virginia, we 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 relating to permitting and control requirements for emissions of regulated pollutants at several of our natural gas production facilities. The NOV alleges that combustion devices at these facilities did not meet applicable air permitting requirements. Separately, in June 2018, we received an information request from 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 facilities for the purpose of determining if the additional facilities have the same alleged compliance issues that were identified during the September 2017 inspections. We have separately received an NOV from West Virginia Department of Environmental Protection (“WVDEP”) alleging violations relating to the same issues being investigated by the EPA. We continue to negotiate with EPA and WVDEP to resolve the issues alleged in the NOVs and the information request; however we believe that there is a reasonable possibility that these actions may result in monetary sanctions exceeding $100,000. Our operations at these facilities are not suspended, and management does not expect these matters to have a material adverse effect on our financial condition, results of operations, or cash flows. ​ SJGC In March 2015, the Company filed suit against South Jersey Gas Company and South Jersey Resources Group, LLC (collectively, “SJGC”) in United States District Court in Colorado seeking relief for breach of contract and damages in the amounts that SJGC had short paid, and continued to short pay, the Company in connection with two nearly identical long term gas contracts. Under those contracts, SJGC are long term purchasers of 80,000 MMBtu/day of the Company’s natural gas production. Deliveries under the contracts began in October 2011 and the term of the contracts continues through October 2019. The price for gas was based on specified indices in the contracts. Beginning in October 2014, SJGC began short paying the Company based on price indices unilaterally selected by SJGC and not the applicable index specified in the contracts. SJGC claimed that the index price specified in the contracts, and the index at which SJGC paid for deliveries from 2011 through September 2014, was no longer appropriate under the contracts because a market disruption event (as defined by the contract) had occurred and, as a result, a new index price was required to be determined by the parties. The Company rejected SJGC’s contention that a market disruption event occurred. SJGC’s actions constituted a breach of the contracts by failing to pay the Company based on the express price terms of the contracts and paying the Company based on unilaterally selected price indices in violation of the contracts’ remedial provisions. On May 8, 2017, a jury in the United States District Court in Colorado returned a unanimous verdict finding in favor of Antero’s positions in the lawsuit against SJGC. On July 21, 2017, final judgment on the jury’s unanimous verdict was entered by the court. On August 18, 2017, SJGC filed post-judgment motions with the court. On March 23, 2018, the court denied SJGC’s post-judgment motions. On April 20, 2018, SJGC appealed the final judgment to the United States Court of Appeals for the Tenth Circuit. On August 6, 2019, the Tenth Circuit Court of Appeals affirmed the judgment of the trial court, and SJGC declined further appeal. Subsequent to the entry of judgment on July 21, 2017, SJGC continued to short pay the Company on the basis of unilaterally selected price indices and not the index specified in the contract. Accordingly, on December 21, 2017, Antero filed suit against SJGC to recover for its damages since March of 2017. After the judgment in the first lawsuit was affirmed, SJGC and Antero filed a joint motion for entry of judgment with the court on September 27, 2019 in which SJGC stipulated to liability and damages in the second lawsuit. The Company received $59 million during the quarter and $23 million subsequent to the quarter for an aggregate payment of $82 million from SJGC, which was in full satisfaction and discharge of judgments entered in favor of the Company in the above described lawsuits. Antero recognized $54 million in natural gas sales, $3 million in production taxes, and $8 million in interest in the Company’s statement of operations for the three and nine months ended September 30, 2019, related to these lawsuits. The $23 million was included in accrued revenue on the Company’s consolidated balance sheet at September 30, 2019. WGL The Company and Washington Gas Light Company and WGL Midstream, Inc. (collectively, “WGL”) were involved in a pricing dispute involving firm gas sales contracts executed June 20, 2014 (the “Contracts”) that the Company began delivering gas under in January 2016. From January 2016 through July 2017 and from December 2017 through January 2018, the aggregate daily gas volumes contracted for under the Contracts was 500,000 MMBtu/day, with the aggregate daily contracted volumes having increased to 600,000 MMBtu/day from August through November 2017. The Company invoiced WGL based on the natural gas index price specified in the Contracts and WGL paid the Company based on that invoice price. However, WGL asserted that the index price was no longer appropriate under the Contracts and claimed that an undefined alternative index was more appropriate for the delivery point of the gas. In July 2016, the matter was referred to arbitration by the Colorado district court. In January 2017, the arbitration panel ruled in the Company’s favor. As a result, the index price has remained as specified in the Contracts and there will be no adjustments to the invoices that have been paid by WGL, nor will future invoices to WGL be adjusted based on the same claim rejected by the arbitration panel. The arbitration panel’s award was confirmed by the Colorado district court on April 14, 2017. In March of 2017, WGL filed a second legal proceeding against the Company in Colorado district court alleging breach of contract and seeking damages of more than $30 million. In this lawsuit, WGL claimed that the Company breached its contractual obligations under the Contracts by failing to deliver “TCO pool” gas. In subsequent filings, WGL explained that its claims were based on an alleged obligation that the Company must deliver gas to the Columbia IPP Pool (“IPP Pool”). WGL asserted this exact same issue in the arbitration and it was rejected by the arbitration panel. The arbitration panel specifically found that the Delivery Point under the Contracts was at a specific point in Braxton, West Virginia, not the IPP Pool. On August 24, 2017, the Colorado district court dismissed with prejudice WGL’s claims against the Company in its new lawsuit and found that the Company had not breached its Contracts with WGL by allegedly failing to deliver to the IPP Pool. The Court dismissed WGL’s lawsuit because WGL had not adequately pled a claim against Antero for the alleged failure to deliver “TCO pool” gas under the Contracts. WGL has appealed this decision to the Colorado Court of Appeals and on October 11, 2018 the Colorado Court of Appeals reversed the Colorado district court’s decision finding that WGL had adequately pled a claim for relief and remanded the case back to the district court for further proceedings. The Company is also actively engaged in pursuing cover damages against WGL based on WGL’s failure to take receipt of all of the agreed quantities of gas required under the Contracts. WGL’s failure to take the gas volumes specified in the Contracts is directly related to WGL’s lack of primary firm transportation rights at the Delivery Point. The failures by WGL to take the full contracted volumes gas began in April 2017 and continued each month through December 2017 in varying quantities. In defense of its conduct, WGL asserted to the Company that their failure to receive gas is excused by (1) the Company’s failure to deliver gas to the IPP Pool or (2) alleged instances of Force Majeure under the Contracts. However, as stated above, the alleged obligation that the Company must deliver gas to the IPP Pool was already rejected by the arbitration panel. Further, the Contracts expressly prohibit a Force Majeure claim in circumstances in which the gas purchaser does not have primary firm transportation agreements in place to transport the purchased gas. In each instance that WGL failed to receive the quantity of gas required under the Contracts, the Company resold the quantities not taken and invoiced WGL for cover damages pursuant to the terms of the Contracts. WGL refused to pay for the invoiced cover damages as required by the Contracts and also short paid the Company for, among other things, certain amounts of gas received by WGL. The Company filed a lawsuit against WGL in Colorado district court on October 24, 2017 to recover its cover damages, other unpaid amounts, and interest. WGL’s claims have been consolidated with Antero’s claims in the same district court and trial began on June 10, 2019. WGL quantified its damages claim for the alleged failure to deliver TCO Pool gas and sought approximately $40 million from Antero. On June 20, 2019, the Company was awarded a jury verdict of approximately $96 million in damages after the jury found that WGL breached the Contracts with the Company. In addition, the jury rejected WGL’s claim against the Company, finding that the Company did not breach the Contracts by allegedly failing to deliver TCO Pool gas and awarding no damages in favor of WGL. On August 16, 2019, WGL filed a notice of appeal of the judgment. ​ Effective February 1, 2018, as a result of a recent amendment to its firm gas sales contract with WGL Midstream, Inc. that was executed on December 28, 2017, the total aggregate volumes to be delivered to WGL at the delivery point in Braxton, West Virginia were reduced from 500,000 MMBtu/day to 200,000 MMBtu/day and in November 2018, the total aggregate contract volumes to be delivered to WGL at a delivery point in Loudoun County, Virginia increased by 330,000 MMBtu/day. This increase of 330,000 MMBtu/day is in effect for the remaining term of our gas sale contract with WGL Midstream, which expires in 2038, and these increased volumes are subject to NYMEX-based pricing. Following this increase, the aggregate contract volumes delivered to WGL total 530,000 MMBtu/day. 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 consolidated financial position, results of operations, or cash flows.

Contract Termination and Rig St

Contract Termination and Rig Stacking	9 Months Ended
	Sep. 30, 2019
Contract Termination and Rig Stacking
Contract Termination and Rig Stacking	(15) Contract Termination and Rig Stacking During the three and nine months ended September 30, 2019, the Company incurred less than $1 million and $14 million, respectively, of costs for the delay or cancelation of drilling and completion contracts with third-party contractors.

Related Parties

Related Parties	9 Months Ended
	Sep. 30, 2019
Related Parties
Related Parties	(16) Related Parties Antero Midstream Partners’ operations comprised substantially all of the operations reflected in the gathering and processing, and water handling and treatment, results through March 12, 2019. Effective March 13, 2019, Antero accounts for Antero Midstream Corporation as an equity method investment. See Note 3 to the unaudited condensed consolidated financial statements for more discussion on the Transactions. Substantially all of the revenues for gathering and processing and water handling and treatment were derived from transactions with Antero. See Note 17 to the unaudited condensed consolidated financial statements for the operating results of the Company’s reportable segments.

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2019
Segment Information
Segment Information	(17) Segment Information See Note 2(i) to the unaudited condensed consolidated financial statements for a description of the Company’s determination of its reportable segments. Revenues from gathering and processing and water handling and treatment operations were primarily derived from intersegment transactions for services provided to the Company’s exploration and production operations prior to the closing of the Transactions. Through March 12, 2019, the results of Antero Partners were included in the consolidated financial statements of Antero. Effective March 13, 2019, the results of Antero Partners are no longer consolidated in Antero’s result; however, the Company’s segment disclosures include the results of our unconsolidated affiliates due to their significance to the Company’s operations. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. Marketing revenues are primarily derived from activities to purchase and sell third-party natural gas and NGLs and to market excess firm transportation capacity to third parties. 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 gathering and processing and water handling and treatment segments 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 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 September 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated Three months ended September 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 982,131 ​ 89,556 ​ 4,845 ​ — 1,076,532 ​ Intersegment ​ 5,197 ​ — ​ 261,360 ​ (266,557) — ​ Total ​ $ 987,328 89,556 266,205 (266,557) 1,076,532 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 35,124 ​ — ​ 67,608 ​ (66,463) ​ 36,269 ​ Gathering, compression, processing, and transportation ​ ​ 442,602 ​ — ​ 12,701 ​ (128,799) 326,504 ​ Impairment of oil and gas properties ​ ​ 221,094 ​ — ​ — ​ — ​ 221,094 ​ Impairment of midstream assets ​ ​ — ​ — ​ 1,157 ​ — ​ 1,157 ​ Depletion, depreciation, and amortization ​ ​ 204,465 ​ — ​ 38,721 ​ — 243,186 ​ General and administrative ​ ​ 45,474 ​ — ​ 15,018 ​ (632) ​ 59,860 ​ Other ​ ​ 30,695 ​ 151,764 ​ 5,219 ​ (4,020) ​ 183,658 ​ Total ​ ​ 979,454 ​ 151,764 ​ 140,424 ​ (199,914) ​ 1,071,728 ​ Operating income (loss) ​ $ 7,874 (62,208) 125,781 (66,643) ​ 4,804 ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 10,705 ​ — ​ 10,705 ​ Segment assets ​ $ 13,484,457 ​ 20,481 ​ 3,411,496 ​ (1,113,899) ​ 15,802,535 ​ Capital expenditures for segment assets ​ $ 485,219 ​ — ​ 149,953 ​ (67,951) ​ 567,221 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Three months ended September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,070,755 ​ 46,645 ​ — ​ — 1,117,400 ​ Intersegment ​ 1,481 ​ — ​ 243,795 ​ (243,795) 1,481 ​ Total ​ $ 1,072,236 46,645 243,795 (243,795) 1,118,881 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 35,928 ​ — ​ 49,050 ​ (49,050) ​ 35,928 ​ Gathering, compression, processing, and transportation ​ ​ 603,860 ​ — ​ 13,091 ​ (13,091) 603,860 ​ Impairment of oil and gas properties ​ ​ 1,041,469 ​ — ​ — ​ — ​ 1,041,469 ​ Impairment of midstream assets ​ ​ — ​ — ​ 465,278 ​ (457,478) ​ 7,800 ​ Depletion, depreciation, and amortization ​ ​ 241,503 ​ — ​ 24,460 ​ (24,460) 241,503 ​ General and administrative ​ ​ 35,923 ​ — ​ 30,595 ​ (30,595) ​ 35,923 ​ Other ​ ​ 30,060 ​ 108,216 ​ 3,210 ​ (3,210) ​ 138,276 ​ Total ​ ​ 1,988,743 ​ 108,216 ​ 585,684 ​ (577,884) ​ 2,104,759 ​ Operating loss ​ $ (916,507) (61,571) (341,889) 334,089 ​ (985,878) ​ Equity in earnings (loss) of unconsolidated affiliates ​ $ (117,859) ​ — ​ 18,478 ​ (18,478) ​ (117,859) ​ Investments in unconsolidated affiliates ​ $ 1,819,323 ​ — ​ 672,310 ​ (672,310) ​ 1,819,323 ​ Segment assets ​ $ 16,094,927 ​ 25,361 ​ 6,445,504 ​ (6,445,504) ​ 16,120,288 ​ Capital expenditures for segment assets ​ $ 292,176 ​ — ​ 120,875 ​ (120,875) ​ 292,176 ​ ​ The operating results and assets of the Company’s reportable segments were as follows for the nine months ended September 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated ​ Nine months ended September 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 2,590,409 ​ 488,270 ​ 15,299 ​ — 3,093,978 ​ Intersegment ​ 16,251 ​ — ​ 731,473 ​ (747,724) — ​ Total ​ $ 2,606,660 488,270 746,772 (747,724) 3,093,978 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 98,698 ​ — ​ 184,698 ​ (190,241) ​ 93,155 ​ Gathering, compression, processing, and transportation ​ ​ 1,236,655 ​ — ​ 36,469 ​ (346,896) 926,228 ​ Impairment of oil and gas properties ​ ​ 406,068 ​ — ​ — ​ — ​ 406,068 ​ Impairment of midstream assets ​ ​ — ​ — ​ 9,658 ​ — ​ 9,658 ​ Depletion, depreciation, and amortization ​ ​ 601,446 ​ — ​ 108,034 ​ — 709,480 ​ General and administrative ​ ​ 138,555 ​ — ​ 44,967 ​ (1,946) ​ 181,576 ​ Other ​ ​ 85,067 ​ 560,924 ​ 15,129 ​ (11,841) ​ 649,279 ​ Total ​ ​ 2,566,489 ​ 560,924 ​ 398,955 ​ (550,924) ​ 2,975,444 ​ Operating income (loss) ​ $ 40,171 (72,654) 347,817 (196,800) ​ 118,534 ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 27,832 ​ — ​ 27,832 ​ Segment assets ​ $ 13,484,457 ​ 20,481 ​ 3,411,496 ​ (1,113,899) ​ 15,802,535 ​ Capital expenditures for segment assets ​ $ 1,464,041 ​ — ​ 414,833 ​ (202,629) ​ 1,676,245 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Nine months ended September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 3,247,214 ​ 200,911 ​ 50 ​ — 3,448,175 Intersegment ​ 4,999 ​ — ​ 553,471 ​ (550,693) 7,777 Total ​ $ 3,252,213 200,911 553,521 (550,693) 3,455,952 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 119,754 ​ — ​ 111,427 ​ (112,664) ​ 118,517 Gathering, compression, processing, and transportation ​ ​ 1,705,709 ​ — ​ 28,324 ​ (138,810) 1,595,223 Impairment of oil and gas properties ​ ​ 1,253,712 ​ — ​ — ​ — ​ 1,253,712 Impairment of midstream assets ​ ​ — ​ — ​ 472,854 ​ (458,072) ​ 14,782 Depletion, depreciation, and amortization ​ ​ 702,299 ​ — ​ 68,557 ​ (46,850) 724,006 General and administrative ​ ​ 128,213 ​ — ​ 85,026 ​ (66,732) ​ 146,507 Other ​ ​ 112,952 ​ 408,839 ​ 8,005 ​ (7,002) ​ 522,794 Total ​ ​ 4,022,639 ​ 408,839 ​ 774,193 ​ (830,130) ​ 4,375,541 Operating income (loss) ​ $ (770,426) (207,928) (220,672) 279,437 ​ (919,589) Equity in earnings (loss) of unconsolidated affiliates ​ $ (102,457) ​ — ​ 34,981 ​ (22,717) ​ (90,193) Investments in unconsolidated affiliates ​ $ 1,819,323 ​ — ​ 672,310 ​ (672,310) ​ 1,819,323 Segment assets ​ $ 16,094,927 ​ 25,361 ​ 6,445,504 ​ (6,445,504) ​ 16,120,288 Capital expenditures for segment assets ​ $ 1,053,210 ​ — ​ 262,065 ​ (208,913) ​ 1,106,362 ​

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2019
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 SEC applicable to interim financial information and should be read in the context of the December 31, 2018 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position, and accounting policies. The December 31, 2018 consolidated financial statements have been filed with the Securities and Exchange Commission (“SEC”) in Antero’s 2018 Form 10-K. The accompanying 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, the accompanying 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, 2018 and September 30, 2019, and the results of its operations and its cash flows for the three and nine months ended September 30, 2018 and 2019. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss. Operating results for the period ended September 30, 2019 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, and other factors. As of the date these financial statements were filed with the SEC, the Company completed its evaluation of potential subsequent events for disclosure and no items requiring disclosure were identified.
Principles of Consolidation	(b) Principles of Consolidation The accompanying unaudited condensed consolidated financial statements include the accounts of Antero, 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. Through March 12, 2019, Antero Midstream Partners LP (“Antero Midstream Partners”), a publicly traded limited partnership, was included in the consolidated financial statements of Antero. Prior to the Closing (defined in Note 3 to the unaudited condensed consolidated financial statements), our ownership of Antero Midstream Partners common units represented approximately a 53 % limited partner interest in Antero Midstream Partners, and we consolidated Antero Midstream Partners’ financial position and results of operations into our consolidated financial statements. The Transactions (defined in Note 3 to the unaudited condensed consolidated financial statements) resulted in the exchange of the limited partner interest we owned in Antero Midstream Partners for common stock of Antero Midstream Corporation representing an approximate 31 % interest. As a result, we no longer hold a controlling interest in Antero Midstream Partners and we now have an interest in Antero Midstream Corporation that provides significant influence, but not control, over Antero Midstream Corporation. Thus, effective March 13, 2019, Antero no longer consolidates Antero Midstream Partners in its consolidated financial statements and accounts for its interest in Antero Midstream Corporation using the equity method of accounting. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. All significant intercompany accounts and transactions have been eliminated in the Company’s unaudited condensed consolidated financial statements. The noncontrolling interest in the Company’s unaudited condensed consolidated financial statements represents the interests in Antero Midstream Partners, which were owned by the public prior to the Transactions, and the incentive distribution rights in Antero Midstream Partners, in both cases during the periods prior to the Transactions. Noncontrolling interests in consolidated subsidiaries is included as a component of equity in the Company’s unaudited condensed consolidated balance sheets. Investments in entities for which the Company exercises significant influence, but not control, are accounted for under the equity method. The Company’s judgment regarding the level of influence over its equity investments includes considering key factors such as Antero’s ownership interest, representation on the board of directors, and participation in the policy-making decisions of equity method investees. Such investments are included in Investments in unconsolidated affiliates on the Company’s unaudited condensed consolidated balance sheets. Income from investees that are accounted for under the equity method is included in Equity in earnings of unconsolidated affiliates on the Company’s unaudited condensed consolidated statements of operations and cash flows. When Antero records its proportionate share of net income, it increases equity income in the statements of operations and comprehensive income (loss) and the carrying value of that investment on the Company’s balance sheet. When a distribution is received, it is recorded as a reduction to the carrying value of that investment on the balance sheet. Our equity in earnings of unconsolidated affiliates is adjusted for intercompany transactions and the basis differences recognized due to the difference between the cost of the equity investment in Antero The Company accounts for distributions received from equity method investees under the “nature of the distribution” approach. Under this approach, distributions received from equity method investees are classified on the basis of the nature of the activity or activities of the investee that generated the distribution as either a return on investment (classified as cash inflows from operating activities) or a return of investment (classified as cash inflows from investing activities).
Use of Estimates	(c) Use of Estimates The preparation of the unaudited condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect revenues, expenses, assets, and liabilities, as well as the disclosure of contingent assets and liabilities. Changes in facts and circumstances or discovery of new information may result in revised estimates, and actual results could differ from those estimates. The Company’s unaudited condensed consolidated financial statements are based on a number of significant estimates including estimates of natural gas, NGLs, and oil reserve quantities, which are the basis for the calculation of depletion and impairment of oil and gas properties. Reserve estimates, by their nature, are inherently imprecise. Other items in the Company’s unaudited condensed consolidated financial statements that involve the use of significant estimates include derivative assets and liabilities, accrued revenue, deferred and current income taxes, equity-based compensation, asset retirement obligations, depreciation, amortization, and commitments and contingencies.
Risks and Uncertainties	(d) Risks and Uncertainties The markets for natural gas, NGLs, and oil have, and continue to, experience significant price fluctuations. Price fluctuations can result from variations in weather, levels of production, availability of transportation capacity to other regions of the country, the level of imports to and exports from the United States, and various other factors. Increases or decreases in the prices the Company receives for its production could have a significant impact on the Company’s future results of operations and reserve quantities.
Cash and Cash Equivalents	(e) 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 and revenue distributions payable associated with book overdrafts as an operating activity within its unaudited condensed consolidated statements of cash flows. As of September 30, 2019, the book overdraft included within accounts payable and revenue distributions payable were $8 million and $34 million, respectively. As of December 31, 2018, the book overdraft included within accounts payable and revenue distributions payable were $10 million and $28 million, respectively.
Oil and Gas Properties	(f) Oil and Gas Properties The Company accounts for its natural gas, NGLs, and oil exploration and development activities under the successful efforts method of accounting. Under the successful efforts method, the costs incurred to acquire, drill, and complete productive wells, development wells, and undeveloped leases are capitalized. Oil and gas lease acquisition costs are also capitalized. Exploration costs, including personnel and other internal costs, geological and geophysical expenses, delay rentals for gas and oil leases, and costs associated with unsuccessful lease acquisitions are charged to expense as incurred. Exploratory drilling costs are initially capitalized, but charged to expense if the Company determines that the well does not contain reserves in commercially viable quantities. The Company reviews exploration costs related to wells-in- progress at the end of each quarter and makes a determination, based on known results of drilling at that time, whether the costs should continue to be capitalized pending further well testing and results, or charged to expense. The Company incurred no such charges to expense during the nine months ended September 30, 2018 and 2019. During the nine months ended September 30, 2019, we recorded an impairment charge of $26 million for design and initial costs related to pads that are no longer planned to be placed into service. The sale of a partial interest in a proved property is accounted for as a cost recovery, and no gain or loss is recognized as long as this treatment does not significantly affect the units-of- production amortization rate. A gain or loss is recognized for all other sales of producing properties. Unproved properties are assessed for impairment on a property-by- property basis, and any impairment in value is charged to expense. Impairment is assessed based on remaining lease terms, commodity price outlooks, and future plans to develop acreage, as well as drilling results, and reservoir performance of wells in the area. Unproved properties and the related costs are transferred to proved properties when reserves are discovered on, or otherwise attributed to, the property. Proceeds from sales of partial interests in unproved properties are accounted for as a recovery of cost without recognition of any gain or loss until the cost has been recovered. Impairment of unproved properties was $406 million and $347 million for the nine months ended September 30, 2018 and 2019, respectively. The Company evaluates the carrying amount of its proved natural gas, NGLs, and oil properties for impairment on a geological reservoir basis whenever events or changes in circumstances indicate that a property’s carrying amount may not be recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company would estimate the fair value of its properties and record an impairment charge for any excess of the carrying amount of the properties over the estimated fair value of the properties. Factors used to estimate fair value may include estimates of proved reserves, estimated future commodity prices, future production estimates, and anticipated capital expenditures, using a commensurate discount rate. As estimated undiscounted future net cash flows based on future commodity prices at September 30, 2019 exceeded the carrying amount of our proved properties in the Marcellus Shale at September 30, 2019, we did not further evaluate our Marcellus proved properties for impairment. However, the carrying amount of the Utica Shale exceeded the estimated undiscounted future cash flows based on future commodity prices at September 30, 2019. We estimated the fair value of the Utica Shale assets based on sales of other properties, estimates of proved reserves, estimated future commodity prices, and future production estimates. As a result, the Company recorded an impairment charge of $881 million related to proved properties in the Utica Shale during the three months ended September 30, 2019. The Company did not record any impairment expenses associated with its proved properties in the Marcellus Shale during the nine months ended September 30, 2018 and 2019. During the three months ended September 30, 2019, Antero completed a non-cash exchange of acreage and ownership interest in certain properties in West Virginia whereby the Company received 20,770 net acres primarily in Tyler and Wetzel Counties and delivered 18,857 net acres primarily in Wetzel and Marion Counties. In conjunction with the non-cash exchange, the Company also assumed certain gas gathering and processing obligations related to a portion of some of the properties. This exchange did not have a material impact on the timing and amount of future cash flows and no gain or loss was recorded related to this transaction.
Derivative Financial Instruments	(g) Derivative Financial Instruments In order to manage its exposure to natural gas, NGLs, and oil price volatility, the Company enters into derivative transactions from time to time, which may include commodity swap agreements, basis swap agreements, collar agreements, and other similar agreements related to the price risk associated with the Company’s production. To the extent legal right of offset exists with a counterparty, the Company reports derivative assets and liabilities on a net basis. The Company has exposure to credit risk to the extent that the counterparty is unable to satisfy its settlement obligations. The Company actively monitors the creditworthiness of counterparties and assesses the impact, if any, on its derivative positions. The Company records derivative instruments on the unaudited condensed consolidated balance sheets as either assets or liabilities measured at fair value and records changes in the fair value of derivatives in current earnings as they occur. Changes in the fair value of commodity derivatives, including gains or losses on settled derivatives, are classified as revenues on the Company’s unaudited condensed consolidated statements of operations. The Company’s derivatives have not been designated as hedges for accounting purposes.
Asset Retirement Obligations Policy	(h) Asset Retirement Obligations The Company is obligated to dispose of certain long- lived assets upon their abandonment. The Company’s asset retirement obligations (“AROs”) relate primarily to its obligation to plug and abandon oil and gas wells at the end of their lives. AROs are recorded at estimated fair value, measured by reference to the expected future cash outflows required to satisfy the retirement obligations, which is then discounted at the Company’s credit-adjusted, risk- free interest rate. Revisions to estimated AROs often result from changes in retirement cost estimates or changes in the estimated timing of abandonment. The fair value of the liability is added to the carrying amount of the associated asset, and this additional carrying amount is depreciated over the life of the asset. The liability is accreted at the end of each period through charges to operating expense.
Industry Segments and Geographic Information	(i) Industry Segments and Geographic Information Management has evaluated how the Company is organized and managed and has identified the following segments: (1) the exploration, development, and production of natural gas, NGLs, and oil; (2) marketing and utilization of excess firm transportation capacity and (3) our equity method investment in Antero Midstream Corporation. Through March 12, 2019, the results of Antero Midstream Partners were included in the consolidated financial statements of Antero. Effective March 13, 2019, the results of Antero Midstream Partners are no longer consolidated in Antero’s results; however, the Company’s segment disclosures include our equity method investment in Antero Midstream Corporation due to its significance to the Company’s operations. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions and Note 17 to the unaudited condensed consolidated financial statements for disclosures on the Company’s reportable segments. ​ 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. Our revenues received from these customers are denominated in U.S. dollars and are based on pricing in foreign markets.
Earnings (loss) Per Common Share	(j) 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—assuming dilution for each period is computed after giving consideration to the potential dilution from outstanding equity awards, calculated using the treasury stock method. The Company includes performance share unit awards 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.
Treasury Share Retirement	(k) Treasury Share Retirement The Company retires treasury shares acquired through share repurchases and returns those shares to the status of authorized but unissued. When treasury shares are retired, the Company’s policy is to allocate the excess of the repurchase price over the par value of shares acquired first, to additional paid-in capital, and then to accumulated earnings. The portion allocable to additional paid-in capital is determined by applying a percentage, determined by dividing the number of shares to be retired by the number of shares outstanding, to the balance of additional paid-in capital as of retirement.
Adoption of New Accounting Principle	(l) Adoption of New Accounting Principle The Company adopted ASU No. 2016-02, Leases , (“Topic 842”) as of January 1, 2019, using the effective date method. The effective date method allows the Company to report its leases under Topic 842 prospectively as of the date of adoption, and no retrospective adjustments were required for prior periods. ​ The Company elected the available practical expedients and updated internal controls to enable the preparation of financial information on adoption. ​ The standard had a material impact on our consolidated balance sheets, but did not have a material impact on our consolidated statements of operations. The most significant impact was the recognition of operating leases right-of-use assets and short-term and long-term lease liabilities for operating leases, while our accounting for finance leases remained substantially unchanged. See Note 12 to the unaudited condensed consolidated financial statements for a description of the Company’s leases.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2019
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 September 30, ​ Nine months ended September 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Basic weighted average number of shares outstanding ​ 317,082 ​ 307,781 ​ 316,850 ​ 308,509 ​ Add: Dilutive effect of restricted stock units ​ — ​ — ​ — ​ 27 ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ — ​ — ​ Add: Dilutive effect of performance stock units ​ — ​ — ​ — ​ 110 ​ Diluted weighted average number of shares outstanding ​ 317,082 ​ 307,781 ​ 316,850 ​ 308,646 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding equity awards excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ ​ ​ ​ ​ Restricted stock units ​ 2,813 ​ 2,356 ​ 2,996 ​ 2,008 ​ Outstanding stock options ​ 619 ​ 514 ​ 637 ​ 541 ​ Performance stock units ​ 1,880 ​ 2,676 ​ 1,665 ​ 2,141 ​ (1) The potential dilutive effects of these awards were excluded from the computation of earnings (loss) per common share—assuming dilution because the inclusion of these awards would have been anti-dilutive.

Deconsolidation of Antero Mid_2

Deconsolidation of Antero Midstream Partners LP (Tables)	9 Months Ended
	Sep. 30, 2019
Deconsolidation of Antero Midstream Partners LP
Summary of summary of assets and liabilities of Antero Midstream Partners as of March 12, 2019, the date of deconsolidation	​ ​ ​ ​ ​ ​ (in thousands) ​ March 12, 2019 ​ Current assets ​ $ 763,109 ​ Property and equipment, net ​ ​ 3,003,693 ​ Other noncurrent assets ​ ​ 501,208 ​ Total assets ​ $ 4,268,010 ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 123,473 ​ Long-term debt ​ ​ 2,359,084 ​ Other noncurrent liabilities ​ ​ 123,523 ​ Total liabilities ​ $ 2,606,080 ​ ​ ​ ​ ​ ​ Net assets ​ $ 1,661,930 ​

Revenue (Tables)

Revenue (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue
Schedule of disaggregation of revenue	In the following table, revenue is disaggregated by type (in thousands). The table also identifies the reportable segment to which the disaggregated revenues relate. For more information on reportable segments, see Note 17— Segment Information. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, ​ Nine months ended September 30, ​ Segment to which ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ revenues relate ​ Revenues from contracts with customers: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 527,122 ​ ​ 524,448 ​ $ 1,498,324 ​ ​ 1,735,086 ​ Exploration and production ​ Natural gas liquids sales (ethane) ​ ​ 56,185 ​ ​ 26,488 ​ ​ 115,947 ​ ​ 92,378 ​ Exploration and production ​ Natural gas liquids sales (C3+ NGLs) ​ ​ 282,084 ​ ​ 258,470 ​ ​ 712,477 ​ ​ 810,228 ​ Exploration and production ​ Oil sales ​ ​ 59,722 ​ ​ 40,561 ​ ​ 128,869 ​ ​ 137,675 ​ Exploration and production ​ Gathering and compression (1) ​ 4,439 ​ — ​ ​ 12,848 ​ 3,972 ​ Equity method investment in AMC ​ Water handling and treatment (1) ​ ​ 405 ​ ​ — ​ ​ 2,450 ​ ​ 507 ​ Equity method investment in AMC ​ Marketing ​ ​ 89,598 ​ ​ 46,645 ​ ​ 394,189 ​ ​ 200,911 ​ Marketing ​ Total ​ 1,019,555 ​ 896,612 ​ ​ 2,865,104 ​ 2,980,757 ​ ​ ​ Income from derivatives and other sources ​ ​ 56,977 ​ ​ 222,269 ​ ​ 228,874 ​ ​ 475,195 ​ ​ ​ Total revenue and other ​ $ 1,076,532 ​ ​ 1,118,881 ​ $ 3,093,978 ​ ​ 3,455,952 ​ ​ ​ (1) Gathering and compression and water handling and treatment revenues were included through March 12, 2019. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	9 Months Ended
	Sep. 30, 2019
Equity Method Investments.
Schedule of reconciliation of investments in unconsolidated affiliates	The following table is a reconciliation of investments in unconsolidated affiliates for the nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stonewall (1) ​ MarkWest ​ Antero Midstream Corporation (2) ​ Total ​ Balance at December 31, 2018 ​ $ 68,103 ​ ​ 365,539 ​ ​ — ​ ​ 433,642 ​ Investments (3) ​ — ​ ​ 25,020 ​ ​ — ​ ​ 25,020 ​ Equity in net income of unconsolidated affiliates ​ ​ 1,894 ​ ​ 10,370 ​ ​ (102,457) ​ ​ (90,193) ​ Distributions/dividends from unconsolidated affiliates ​ (3,000) ​ ​ (9,605) ​ ​ (96,636) ​ ​ (109,241) ​ Elimination of intercompany profit ​ ​ — ​ ​ — ​ ​ 30,621 ​ ​ 30,621 ​ Effects of deconsolidation (4) ​ (66,997) ​ ​ (391,324) ​ ​ 1,987,795 ​ ​ 1,529,474 ​ Balance at September 30, 2019 ​ $ — ​ ​ — ​ ​ 1,819,323 ​ ​ 1,819,323 ​ (1) Distributions are net of operating and capital requirements retained by Stonewall. (2) As adjusted for the amortization of the difference between the cost of the equity investment in Antero Midstream Corporation and the amount of underlying equity in the net assets of Antero Midstream Partners as of the date of deconsolidation. (3) Investments in the Joint Venture during the nine months ended September 30, 2019 relate to capital contributions for construction of additional processing facilities. (4) Effective March 13, 2019, the equity in earnings of Stonewall and the Joint Venture are accounted for in the equity in earnings of Antero Midstream Corporation.
Schedule of summarized financial information of Antero Midstream Corporation	Balance Sheet ​ ​ ​ ​ ​ ​ (in thousands) ​ September 30, 2019 ​ Current assets ​ $ 109,224 ​ Noncurrent assets ​ ​ 6,336,280 ​ Total assets ​ $ 6,445,504 ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 259,628 ​ Noncurrent liabilities ​ ​ 2,662,846 ​ Stockholders' equity ​ ​ 3,523,030 ​ Total liabilities and equity ​ $ 6,445,504 ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ For the period ​ ​ ​ ​ March 13, 2019 through ​ (in thousands) ​ September 30, 2019 ​ Revenues ​ $ 553,521 ​ Operating expenses ​ ​ 745,940 ​ Loss from operations ​ $ (192,419) ​ Net loss attributable to the equity method investments ​ $ (197,006) ​

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2019
Accrued Liabilities
Schedule of accrued liabilities	Accrued liabilities as of December 31, 2018 and September 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 September 30, 2019 ​ Capital expenditures ​ $ 113,237 ​ 83,963 ​ Gathering, compression, processing, and transportation expenses ​ ​ 148,032 ​ ​ 141,036 ​ Marketing expenses ​ ​ 67,082 ​ ​ 47,763 ​ Interest expense, net ​ 43,444 ​ 62,255 ​ Other ​ 93,275 ​ 57,709 ​ ​ ​ $ 465,070 ​ 392,726 ​

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
Long-Term Debt.
Schedule of long-term debt	Long-term debt was as follows at December 31, 2018 and September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 September 30, 2019 ​ Antero Resources: ​ ​ ​ ​ ​ ​ ​ Credit Facility (a) ​ $ 405,000 ​ 275,000 ​ 5.375% senior notes due 2021 (b) ​ 1,000,000 ​ 1,000,000 ​ 5.125% senior notes due 2022 (c) ​ ​ 1,100,000 ​ ​ 1,100,000 ​ 5.625% senior notes due 2023 (d) ​ ​ 750,000 ​ ​ 750,000 ​ 5.00% senior notes due 2025 (e) ​ ​ 600,000 ​ ​ 600,000 ​ Net unamortized premium ​ 1,241 ​ 1,021 ​ Net unamortized debt issuance costs ​ ​ (26,700) ​ ​ (22,193) ​ Long-term debt ​ ​ 3,829,541 ​ ​ 3,703,828 ​ Antero Midstream Partners: ​ ​ ​ ​ ​ ​ ​ Midstream Credit Facility (1) ​ ​ 990,000 ​ ​ — ​ 5.375% senior notes due 2024 (1) ​ ​ 650,000 ​ ​ — ​ Net unamortized debt issuance costs (1) ​ ​ (7,853) ​ ​ — ​ Long-term debt ​ ​ 1,632,147 ​ ​ — ​ Consolidated long-term debt ​ $ 5,461,688 ​ 3,703,828 ​ (1) At December 31, 2018, Antero Midstream Partners’ indebtedness was included in the consolidated financial statements of Antero. At September 30, 2019, following the deconsolidation, Antero Midstream Partners’ outstanding indebtedness is no longer reflected in Antero’s consolidated financial statements. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligations
Schedule of reconciliation of asset retirement obligations	The following is a reconciliation of the Company’s asset retirement obligations for the nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ Asset retirement obligations—December 31, 2018 ​ $ 58,979 ​ Obligations settled ​ ​ (153) ​ Obligations incurred ​ 1,361 ​ Revisions to prior estimates ​ ​ — ​ Accretion expense ​ 2,821 ​ Effect of deconsolidation of Antero Midstream Partners LP (1) ​ (7,518) ​ Asset retirement obligations—September 30, 2019 ​ $ 55,490 ​ (1)

Equity-Based Compensation (Tabl

Equity-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2019
Equity-Based Compensation
Schedule of equity-based compensation expense	The Company’s equity-based compensation expense, by type of award, was as follows for the three and nine months ended September 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, ​ Nine months ended September 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Restricted stock unit awards ​ $ 10,001 ​ ​ 2,229 ​ $ 33,676 ​ ​ 8,829 ​ Stock options ​ ​ 452 ​ ​ — ​ ​ 1,428 ​ ​ 389 ​ Performance share unit awards ​ ​ 1,017 ​ ​ 399 ​ ​ 7,018 ​ ​ 6,027 ​ Antero Midstream Partners phantom unit awards (1) ​ ​ 4,193 ​ ​ 867 ​ ​ 12,752 ​ ​ 2,942 ​ Equity awards issued to directors ​ ​ 539 ​ ​ 380 ​ ​ 1,555 ​ ​ 1,140 ​ Total expense ​ $ 16,202 ​ ​ 3,875 ​ $ 56,429 ​ ​ 19,327 ​ (1) Partners to Antero. Antero allocates a portion of equity-based compensation expense related to grants prior to the Transactions to Antero Partners based on its proportionate share of Antero’s labor costs. Through March 12, 2019, the total amount of equity-based compensation is included in the consolidated financial statements of Antero; and effective March 13, 2019 (date of deconsolidation), the amount allocated to Antero Partners is no longer reflected in Antero’s consolidated financial statements. See Note 3 to the unaudited condensed consolidated financial statements for further discussion on the Transactions. ​
Summary of restricted stock and restricted stock unit awards activity	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ Aggregate ​ ​ Number of grant date intrinsic value ​ Total awarded and unvested—December 31, 2018 1,712,485 ​ $ 24.57 ​ $ 16,080 ​ Granted 1,610,690 ​ $ 8.60 ​ ​ ​ ​ Vested (718,192) ​ $ 27.70 ​ ​ ​ ​ Forfeited (307,938) ​ $ 16.56 ​ ​ ​ ​ Total awarded and unvested—September 30, 2019 2,297,045 ​ $ 13.47 ​ $ 6,937 ​
Summary of stock option activity	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ average ​ Intrinsic ​ ​ Stock exercise ​ contractual value Outstanding at December 31, 2018 579,617 ​ $ 50.55 ​ 5.81 ​ $ — ​ Granted — ​ $ — ​ ​ ​ ​ ​ ​ ​ Exercised — ​ $ — ​ ​ ​ ​ ​ ​ ​ Forfeited (79,484) ​ $ 50.25 ​ ​ ​ ​ ​ ​ ​ Expired — ​ $ — ​ ​ ​ ​ ​ ​ ​ Outstanding at September 30, 2019 500,133 ​ $ 50.60 ​ 4.98 ​ $ — ​ Vested or expected to vest as of September 30, 2019 500,133 ​ $ 50.60 ​ 4.98 ​ $ — ​ Exercisable at September 30, 2019 500,133 ​ $ 50.60 ​ ​ 4.98 ​ $ — ​
Summary of Performance Stock Unit activity	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Number of ​ Weighted ​ Total awarded and unvested—December 31, 2018 1,767,299 ​ $ 26.36 ​ Granted 1,416,378 ​ $ 9.26 ​ Vested (31,944) ​ $ 27.38 ​ Forfeited (614,450) ​ $ 26.61 ​ Total awarded and unvested—September 30, 2019 2,537,283 ​ $ 16.74 ​
Schedule of weighted average fair value assumptions used for PSUs granted	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, ​ ​ ​ ​ 2018 ​ ​ 2019 ​ ​ Dividend yield ​ ​ — % ​ ​ — % ​ Volatility ​ ​ 41 % ​ ​ 36 % ​ Risk-free interest rate ​ ​ 2.49 % ​ ​ 2.35 % ​ Weighted average fair value of awards granted ​ $ 24.85 ​ ​ $ 9.26 ​ ​
Schedule of outstanding unvested restricted stock awards vesting schedule	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Number of ​ Weighted ​ Aggregate ​ Total awarded and unvested—December 31, 2018 583,000 ​ $ 27.63 ​ $ 12,470 ​ Granted 5,972 ​ $ 23.44 ​ ​ ​ ​ Vested (3,853) ​ $ 32.44 ​ ​ ​ ​ Forfeited (20,338) ​ $ 26.73 ​ ​ ​ ​ AMP Plan Units awarded and unvested—March 12, 2019 ​ 564,781 ​ $ 27.59 ​ $ 13,476 ​ Effect of conversion (1) 504,119 ​ $ 14.58 ​ ​ ​ ​ Vested (358,831) ​ $ 14.34 ​ ​ ​ ​ Forfeited (45,803) ​ $ 14.58 ​ ​ ​ ​ Total awarded and unvested—September 30, 2019 664,266 ​ $ 14.70 ​ $ 4,916 ​ (1) ​

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2019
Derivative Instruments.
Schedule of outstanding commodity derivatives	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas ​ ​ Natural Gas ​ ​ Oil ​ Weighted ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 996,766 ​ ​ — ​ ​ — ​ $ 3.23 ​ ARA Propane ($/Gal) ​ — ​ ​ 10,113 ​ ​ — ​ ​ 0.68 ​ FEI Propane ($/Gal) ​ — ​ ​ 9,809 ​ ​ — ​ ​ 0.81 ​ Mont Belvieu Propane Non-TET ($/Gal) ​ — ​ ​ 8,000 ​ ​ — ​ ​ 0.50 ​ Mont Belvieu Butane Non-TET ($/Gal) ​ — ​ ​ 4,000 ​ ​ — ​ ​ 0.59 ​ Mont Belvieu Natural Gasoline Non-TET ($/Gal) ​ — ​ ​ 3,500 ​ ​ — ​ ​ 1.14 ​ NYMEX-WTI ($/Bbl) ​ — ​ ​ — ​ ​ 18,000 ​ ​ 59.05 ​ Total ​ 996,766 ​ ​ 35,422 ​ ​ 18,000 ​ ​ ​ ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 2,227,500 ​ ​ ​ ​ ​ — ​ $ 2.87 ​ ARA Propane ($/Gal) ​ — ​ ​ 9,761 ​ ​ — ​ ​ 0.65 ​ FEI Propane ($/Gal) ​ — ​ ​ 2,045 ​ ​ — ​ ​ 0.81 ​ Mont Belvieu Butane Non-TET ($/Gal) ​ — ​ ​ 2,000 ​ ​ — ​ ​ 0.57 ​ NYMEX-WTI ($/Bbl) ​ — ​ ​ ​ ​ ​ 12,000 ​ ​ 56.60 ​ Total ​ 2,227,500 ​ ​ 13,806 ​ ​ 12,000 ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 2,110,000 ​ ​ ​ ​ ​ ​ ​ $ 2.79 ​ Year ending December 31, 2022: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 290,000 ​ ​ ​ ​ ​ ​ ​ $ 2.96 ​ Year ending December 31, 2023: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 90,000 ​ ​ ​ ​ ​ ​ ​ $ 2.91 ​
Schedule of natural gas basis swap positions which settle on pricing index to basis differential of NYMEX to TCO	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas MMBtu/day ​ ​ Natural Gas ​ Weighted average hedged differential ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ARA to Mont Belvieu Non-TET ($/Gal) ​ — ​ ​ 4,050 ​ $ 0.25 ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 60,000 ​ ​ — ​ ​ 0.353 ​ ARA to Mont Belvieu Non-TET ($/Gal) ​ — ​ ​ 4,273 ​ $ 0.23 ​ Total ​ 60,000 ​ ​ 4,273 ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 40,000 ​ ​ — ​ $ 0.414 ​ Year ending December 31, 2022: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 60,000 ​ ​ — ​ $ 0.515 ​ Year ending December 31, 2023: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 50,000 ​ ​ — ​ $ 0.525 ​ Year ending December 31, 2024: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX to TCO ($/MMBtu) ​ 50,000 ​ ​ — ​ $ 0.530 ​
Tabular disclosure 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.	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural Gas Liquids Bbls/day ​ Weighted average payout ratio ​ ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ Mont Belvieu Propane to NYMEX-WTI ​ 500 ​ ​ 50 % ​ Mont Belvieu Natural Gasoline to NYMEX-WTI ​ 13,900 ​ ​ 81 % ​ Total ​ 14,400 ​ ​ ​ ​ ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ Mont Belvieu Propane to NYMEX-WTI ​ 500 ​ ​ 50 % ​ Mont Belvieu Natural Gasoline to NYMEX-WTI ​ 15,000 ​ ​ 79 % ​ Total ​ 15,500 ​ ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ Mont Belvieu Natural Gasoline to NYMEX-WTI ​ 13,000 ​ ​ 78 % ​ ​ As of September 30, 2019, the Company’s fixed price natural gas collar positions from October 1, 2019 through December 31, 2019 were as follows (abbreviations in the table refer to the index to which the collar position is tied, as follows (NYMEX=Henry Hub): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas (MMBtu/day) ​ Weighted average index price ​ ​ Ceiling ​ Floor ​ Ceiling price ​ Floor price ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,575,000 ​ ​ 1,333,234 ​ $ 3.52 ​ $ 2.50 ​
Summary of the fair values of derivative instruments, which are not designated as hedges for accounting purposes	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ September 30, 2019 ​ ​ ​ Balance sheet ​ Fair value ​ Balance sheet ​ Fair value ​ ​ ​ ​ ​ (In thousands) ​ ​ ​ (In thousands) ​ Asset derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives - current ​ Derivative instruments ​ $ 245,263 ​ Derivative instruments ​ $ 411,774 ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ 362,169 ​ Derivative instruments ​ ​ 405,180 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total asset derivatives ​ ​ ​ ​ 607,432 ​ ​ ​ ​ 816,954 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liability derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives - current ​ Derivative instruments ​ ​ 532 ​ Derivative instruments ​ ​ — ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ — ​ Derivative instruments ​ ​ — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total liability derivatives ​ ​ ​ ​ 532 ​ ​ ​ ​ — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net derivatives ​ ​ ​ $ 606,900 ​ ​ ​ $ 816,954 ​
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 consolidated balance sheets as of the dates presented, all at fair value (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ September 30, 2019 ​ ​ ​ Gross ​ Gross amounts ​ Net amounts ​ Gross ​ Gross amounts ​ Net amounts Commodity derivative assets ​ $ 658,830 ​ (51,398) ​ 607,432 ​ $ 838,795 ​ (21,841) ​ 816,954 ​ Commodity derivative liabilities ​ $ (51,930) ​ 51,398 ​ (532) ​ $ (21,841) ​ 21,841 ​ — ​
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 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Statement of ​ Three months ended September 30, ​ Nine months ended September 30, ​ ​ ​ location ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Commodity derivative fair value gains ​ Revenue ​ $ 57,019 ​ ​ 220,788 ​ ​ 134,793 ​ ​ 471,847 ​ Marketing derivative fair value gains (losses) ​ Revenue ​ $ (42) ​ ​ — ​ ​ 94,081 ​ ​ — ​

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Leases
Summary of supplemental balance sheet information related to leases	The Company’s lease assets as of September 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Right-of-use Assets: ​ ​ ​ ​ ​ ​ ​ Processing plants ​ $ 1,554,601 ​ ​ — ​ Drilling rigs and completion services ​ ​ 93,846 ​ ​ — ​ Gas gathering lines and compressor stations (1) ​ ​ 1,535,146 ​ ​ — ​ Office space ​ ​ 41,285 ​ ​ — ​ Vehicles ​ ​ 4,971 ​ ​ 2,591 ​ Other office and field equipment ​ ​ 299 ​ ​ 448 ​ Total right-of-use assets ​ $ 3,230,148 ​ ​ 3,039 (2) (1) Gas gathering lines and compressor stations leases includes $1.3 billion related to Antero Midstream Corporation. (2) Financing lease assets are recorded net of accumulated amortization of $9 million as of September 30, 2019. ​ The Company’s lease liabilities as of September 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Location on the balance sheet: ​ ​ ​ ​ ​ ​ ​ Short-term lease liabilities ​ $ 408,814 ​ ​ 1,176 ​ Long-term lease liabilities ​ ​ 2,821,334 ​ ​ 1,863 ​ Total lease liabilities ​ $ 3,230,148 ​ ​ 3,039 ​
Summary of costs associated with operating leases	Costs associated with operating leases were included in the statement of operations and comprehensive income (loss) for the three and nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ Statement of Operations Location ​ Three months ended September 30, 2019 ​ Nine months ended September 30, 2019 Gathering, compression, processing, and transportation ​ $ 237,618 ​ $ 644,007 General and administrative ​ ​ 2,859 ​ ​ 8,395 Contract termination and rig stacking ​ ​ — ​ ​ 10,692 Total Lease Expense ​ $ 240,477 ​ $ 663,094
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 and nine months ended September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, 2019 ​ Nine months ended September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Operating Leases ​ Finance Leases ​ Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating cash out flows related to operating leases ​ $ 234,399 ​ ​ — ​ $ 591,963 ​ ​ — ​ Investing cash out flows related to operating leases ​ ​ 47,417 ​ ​ — ​ ​ 146,315 ​ ​ — ​ Financing cash out flows related to financing leases ​ ​ — ​ ​ 303 ​ ​ — ​ ​ 1,967 ​ ​ ​ ​ 281,816 ​ ​ 303 ​ ​ 738,278 ​ ​ 1,967 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Noncash activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Right of use assets obtained in exchange for operating lease liabilities ​ ​ — ​ ​ — ​ ​ 3,345,549 ​ ​ — ​ Right of use assets obtained in exchange for financing lease liabilities ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​
Summary of maturities of operating lease liabilities	The table below is a schedule of future minimum payments for operating and financing lease liabilities as of September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2019 ​ $ 151,345 ​ ​ 21 ​ ​ 151,366 ​ 2020 ​ ​ 578,615 ​ ​ 523 ​ ​ 579,138 ​ 2021 ​ ​ 506,402 ​ ​ 1,152 ​ ​ 507,554 ​ 2022 ​ ​ 495,694 ​ ​ 1,298 ​ ​ 496,992 ​ 2023 ​ ​ 491,513 ​ ​ 45 ​ ​ 491,558 ​ 2024 ​ ​ 482,745 ​ ​ — ​ ​ 482,745 ​ Thereafter ​ ​ 1,447,537 ​ ​ — ​ ​ 1,447,537 ​ Total lease payments ​ ​ 4,153,851 ​ ​ 3,039 ​ ​ 4,156,890 ​ Less: imputed interest ​ ​ (923,703) ​ ​ — ​ ​ (923,703) ​ Total ​ $ 3,230,148 ​ ​ 3,039 ​ ​ 3,233,187 ​ ​ As of December 31, 2018, the following future minimum payments were required for office and equipment leases: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Office Leases ​ Equipment Leases ​ Total ​ 2019 ​ $ 8,630 ​ ​ 6,042 ​ ​ 14,672 ​ 2020 ​ ​ 8,471 ​ ​ 4,517 ​ ​ 12,988 ​ 2021 ​ ​ 8,450 ​ ​ 2,410 ​ ​ 10,860 ​ 2022 ​ ​ 8,427 ​ ​ 274 ​ ​ 8,701 ​ 2023 ​ ​ 7,495 ​ ​ — ​ ​ 7,495 ​ Thereafter ​ ​ 49,367 ​ ​ — ​ ​ 49,367 ​ Total ​ $ 90,840 ​ ​ 13,243 ​ ​ 104,083 ​
Summary of maturities of financing lease liabilities	​ The table below is a schedule of future minimum payments for operating and financing lease liabilities as of September 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2019 ​ $ 151,345 ​ ​ 21 ​ ​ 151,366 ​ 2020 ​ ​ 578,615 ​ ​ 523 ​ ​ 579,138 ​ 2021 ​ ​ 506,402 ​ ​ 1,152 ​ ​ 507,554 ​ 2022 ​ ​ 495,694 ​ ​ 1,298 ​ ​ 496,992 ​ 2023 ​ ​ 491,513 ​ ​ 45 ​ ​ 491,558 ​ 2024 ​ ​ 482,745 ​ ​ — ​ ​ 482,745 ​ Thereafter ​ ​ 1,447,537 ​ ​ — ​ ​ 1,447,537 ​ Total lease payments ​ ​ 4,153,851 ​ ​ 3,039 ​ ​ 4,156,890 ​ Less: imputed interest ​ ​ (923,703) ​ ​ — ​ ​ (923,703) ​ Total ​ $ 3,230,148 ​ ​ 3,039 ​ ​ 3,233,187 ​ ​ As of December 31, 2018, the following future minimum payments were required for office and equipment leases: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Office Leases ​ Equipment Leases ​ Total ​ 2019 ​ $ 8,630 ​ ​ 6,042 ​ ​ 14,672 ​ 2020 ​ ​ 8,471 ​ ​ 4,517 ​ ​ 12,988 ​ 2021 ​ ​ 8,450 ​ ​ 2,410 ​ ​ 10,860 ​ 2022 ​ ​ 8,427 ​ ​ 274 ​ ​ 8,701 ​ 2023 ​ ​ 7,495 ​ ​ — ​ ​ 7,495 ​ Thereafter ​ ​ 49,367 ​ ​ — ​ ​ 49,367 ​ Total ​ $ 90,840 ​ ​ 13,243 ​ ​ 104,083 ​ ​
Summary of weighted-average remaining lease term and discount rate	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Weighted-average remaining lease term: ​ ​ 8.4 years ​ ​ 2.1 years ​ Weighted-average discount rate: ​ ​ 6.1 % ​ 5.7 %

Commitments (Tables)

Commitments (Tables)	9 Months Ended
	Sep. 30, 2019
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 table below is 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 September 30, 2019 (in thousands). ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Firm ​ Processing, ​ Land payment obligations ​ Operating and Financing Leases ​ Imputed Interest for Leases ​ ​ ​ ​ ​ (a) ​ (b) ​ (c) ​ (d) ​ (d) ​ Total ​ Remainder of 2019 ​ $ 282,571 ​ ​ 13,667 ​ ​ 4,653 ​ ​ 102,808 ​ ​ 48,558 ​ ​ 452,257 ​ 2020 ​ ​ 1,123,782 ​ ​ 54,425 ​ ​ 5,557 ​ ​ 399,881 ​ ​ 179,257 ​ ​ 1,762,902 ​ 2021 ​ ​ 1,100,079 ​ ​ 54,093 ​ ​ 3,177 ​ ​ 350,364 ​ ​ 157,190 ​ ​ 1,664,903 ​ 2022 ​ ​ 1,047,162 ​ ​ 53,606 ​ ​ 259 ​ ​ 361,057 ​ ​ 135,935 ​ ​ 1,598,019 ​ 2023 ​ ​ 1,034,641 ​ ​ 58,565 ​ ​ — ​ ​ 377,836 ​ ​ 113,722 ​ ​ 1,584,764 ​ 2024 ​ ​ 994,534 ​ ​ 58,687 ​ ​ — ​ ​ 392,323 ​ ​ 90,422 ​ ​ 1,535,966 ​ Thereafter ​ ​ 7,816,594 ​ ​ 152,523 ​ ​ — ​ ​ 1,248,918 ​ ​ 198,619 ​ ​ 9,416,654 ​ Total ​ $ 13,399,363 ​ ​ 445,566 ​ ​ 13,646 ​ ​ 3,233,187 ​ ​ 923,703 ​ ​ 18,015,465 ​

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Information
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 September 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated Three months ended September 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 982,131 ​ 89,556 ​ 4,845 ​ — 1,076,532 ​ Intersegment ​ 5,197 ​ — ​ 261,360 ​ (266,557) — ​ Total ​ $ 987,328 89,556 266,205 (266,557) 1,076,532 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 35,124 ​ — ​ 67,608 ​ (66,463) ​ 36,269 ​ Gathering, compression, processing, and transportation ​ ​ 442,602 ​ — ​ 12,701 ​ (128,799) 326,504 ​ Impairment of oil and gas properties ​ ​ 221,094 ​ — ​ — ​ — ​ 221,094 ​ Impairment of midstream assets ​ ​ — ​ — ​ 1,157 ​ — ​ 1,157 ​ Depletion, depreciation, and amortization ​ ​ 204,465 ​ — ​ 38,721 ​ — 243,186 ​ General and administrative ​ ​ 45,474 ​ — ​ 15,018 ​ (632) ​ 59,860 ​ Other ​ ​ 30,695 ​ 151,764 ​ 5,219 ​ (4,020) ​ 183,658 ​ Total ​ ​ 979,454 ​ 151,764 ​ 140,424 ​ (199,914) ​ 1,071,728 ​ Operating income (loss) ​ $ 7,874 (62,208) 125,781 (66,643) ​ 4,804 ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 10,705 ​ — ​ 10,705 ​ Segment assets ​ $ 13,484,457 ​ 20,481 ​ 3,411,496 ​ (1,113,899) ​ 15,802,535 ​ Capital expenditures for segment assets ​ $ 485,219 ​ — ​ 149,953 ​ (67,951) ​ 567,221 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Three months ended September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,070,755 ​ 46,645 ​ — ​ — 1,117,400 ​ Intersegment ​ 1,481 ​ — ​ 243,795 ​ (243,795) 1,481 ​ Total ​ $ 1,072,236 46,645 243,795 (243,795) 1,118,881 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 35,928 ​ — ​ 49,050 ​ (49,050) ​ 35,928 ​ Gathering, compression, processing, and transportation ​ ​ 603,860 ​ — ​ 13,091 ​ (13,091) 603,860 ​ Impairment of oil and gas properties ​ ​ 1,041,469 ​ — ​ — ​ — ​ 1,041,469 ​ Impairment of midstream assets ​ ​ — ​ — ​ 465,278 ​ (457,478) ​ 7,800 ​ Depletion, depreciation, and amortization ​ ​ 241,503 ​ — ​ 24,460 ​ (24,460) 241,503 ​ General and administrative ​ ​ 35,923 ​ — ​ 30,595 ​ (30,595) ​ 35,923 ​ Other ​ ​ 30,060 ​ 108,216 ​ 3,210 ​ (3,210) ​ 138,276 ​ Total ​ ​ 1,988,743 ​ 108,216 ​ 585,684 ​ (577,884) ​ 2,104,759 ​ Operating loss ​ $ (916,507) (61,571) (341,889) 334,089 ​ (985,878) ​ Equity in earnings (loss) of unconsolidated affiliates ​ $ (117,859) ​ — ​ 18,478 ​ (18,478) ​ (117,859) ​ Investments in unconsolidated affiliates ​ $ 1,819,323 ​ — ​ 672,310 ​ (672,310) ​ 1,819,323 ​ Segment assets ​ $ 16,094,927 ​ 25,361 ​ 6,445,504 ​ (6,445,504) ​ 16,120,288 ​ Capital expenditures for segment assets ​ $ 292,176 ​ — ​ 120,875 ​ (120,875) ​ 292,176 ​ ​ The operating results and assets of the Company’s reportable segments were as follows for the nine months ended September 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated ​ Nine months ended September 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 2,590,409 ​ 488,270 ​ 15,299 ​ — 3,093,978 ​ Intersegment ​ 16,251 ​ — ​ 731,473 ​ (747,724) — ​ Total ​ $ 2,606,660 488,270 746,772 (747,724) 3,093,978 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 98,698 ​ — ​ 184,698 ​ (190,241) ​ 93,155 ​ Gathering, compression, processing, and transportation ​ ​ 1,236,655 ​ — ​ 36,469 ​ (346,896) 926,228 ​ Impairment of oil and gas properties ​ ​ 406,068 ​ — ​ — ​ — ​ 406,068 ​ Impairment of midstream assets ​ ​ — ​ — ​ 9,658 ​ — ​ 9,658 ​ Depletion, depreciation, and amortization ​ ​ 601,446 ​ — ​ 108,034 ​ — 709,480 ​ General and administrative ​ ​ 138,555 ​ — ​ 44,967 ​ (1,946) ​ 181,576 ​ Other ​ ​ 85,067 ​ 560,924 ​ 15,129 ​ (11,841) ​ 649,279 ​ Total ​ ​ 2,566,489 ​ 560,924 ​ 398,955 ​ (550,924) ​ 2,975,444 ​ Operating income (loss) ​ $ 40,171 (72,654) 347,817 (196,800) ​ 118,534 ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 27,832 ​ — ​ 27,832 ​ Segment assets ​ $ 13,484,457 ​ 20,481 ​ 3,411,496 ​ (1,113,899) ​ 15,802,535 ​ Capital expenditures for segment assets ​ $ 1,464,041 ​ — ​ 414,833 ​ (202,629) ​ 1,676,245 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Nine months ended September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 3,247,214 ​ 200,911 ​ 50 ​ — 3,448,175 Intersegment ​ 4,999 ​ — ​ 553,471 ​ (550,693) 7,777 Total ​ $ 3,252,213 200,911 553,521 (550,693) 3,455,952 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 119,754 ​ — ​ 111,427 ​ (112,664) ​ 118,517 Gathering, compression, processing, and transportation ​ ​ 1,705,709 ​ — ​ 28,324 ​ (138,810) 1,595,223 Impairment of oil and gas properties ​ ​ 1,253,712 ​ — ​ — ​ — ​ 1,253,712 Impairment of midstream assets ​ ​ — ​ — ​ 472,854 ​ (458,072) ​ 14,782 Depletion, depreciation, and amortization ​ ​ 702,299 ​ — ​ 68,557 ​ (46,850) 724,006 General and administrative ​ ​ 128,213 ​ — ​ 85,026 ​ (66,732) ​ 146,507 Other ​ ​ 112,952 ​ 408,839 ​ 8,005 ​ (7,002) ​ 522,794 Total ​ ​ 4,022,639 ​ 408,839 ​ 774,193 ​ (830,130) ​ 4,375,541 Operating income (loss) ​ $ (770,426) (207,928) (220,672) 279,437 ​ (919,589) Equity in earnings (loss) of unconsolidated affiliates ​ $ (102,457) ​ — ​ 34,981 ​ (22,717) ​ (90,193) Investments in unconsolidated affiliates ​ $ 1,819,323 ​ — ​ 672,310 ​ (672,310) ​ 1,819,323 Segment assets ​ $ 16,094,927 ​ 25,361 ​ 6,445,504 ​ (6,445,504) ​ 16,120,288 Capital expenditures for segment assets ​ $ 1,053,210 ​ — ​ 262,065 ​ (208,913) ​ 1,106,362

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	9 Months Ended
	Sep. 30, 2019
Subsidiary Guarantors
Schedule of condensed consolidated balance sheets	Condensed Consolidating Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Assets ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts receivable, net ​ $ 49,529 ​ ​ — ​ ​ 1,544 ​ ​ — ​ ​ 51,073 ​ Intercompany receivables ​ ​ 383 ​ ​ — ​ ​ 115,378 ​ ​ (115,761) ​ ​ — ​ Accrued revenue ​ ​ 474,827 ​ ​ — ​ ​ — ​ ​ — ​ ​ 474,827 ​ Derivative instruments ​ ​ 245,263 ​ ​ — ​ ​ — ​ ​ — ​ ​ 245,263 ​ Other current assets ​ ​ 13,937 ​ ​ — ​ ​ 21,513 ​ ​ — ​ ​ 35,450 ​ Total current assets ​ ​ 783,939 ​ ​ — ​ ​ 138,435 ​ ​ (115,761) ​ ​ 806,613 ​ Property and equipment: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil and gas properties, at cost (successful efforts method): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Unproved properties ​ ​ 1,767,600 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,767,600 ​ Proved properties ​ ​ 13,306,585 ​ ​ — ​ ​ — ​ ​ (600,913) ​ ​ 12,705,672 ​ Water handling and treatment systems ​ ​ — ​ ​ — ​ ​ 1,004,793 ​ ​ 9,025 ​ ​ 1,013,818 ​ Gathering systems and facilities ​ ​ 17,825 ​ ​ — ​ ​ 2,452,883 ​ ​ — ​ ​ 2,470,708 ​ Other property and equipment ​ ​ 65,770 ​ ​ — ​ ​ 72 ​ ​ — ​ ​ 65,842 ​ ​ ​ ​ 15,157,780 ​ ​ — ​ ​ 3,457,748 ​ ​ (591,888) ​ ​ 18,023,640 ​ Less accumulated depletion, depreciation, and amortization ​ ​ (3,654,392) ​ ​ — ​ ​ (499,333) ​ ​ — ​ ​ (4,153,725) ​ Property and equipment, net ​ ​ 11,503,388 ​ ​ — ​ ​ 2,958,415 ​ ​ (591,888) ​ ​ 13,869,915 ​ Derivative instruments ​ ​ 362,169 ​ ​ — ​ ​ — ​ ​ — ​ ​ 362,169 ​ Investment in Antero Midstream Partners ​ ​ (740,031) ​ ​ — ​ ​ — ​ ​ 740,031 ​ ​ — ​ Contingent acquisition consideration ​ ​ 114,995 ​ ​ — ​ ​ — ​ ​ (114,995) ​ ​ — ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 433,642 ​ ​ — ​ ​ 433,642 ​ Other assets ​ ​ 31,200 ​ ​ — ​ ​ 15,925 ​ ​ — ​ ​ 47,125 ​ Total assets ​ $ 12,055,660 ​ ​ — ​ ​ 3,546,417 ​ ​ (82,613) ​ ​ 15,519,464 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liabilities and Equity ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts payable ​ $ 44,917 ​ ​ — ​ ​ 21,372 ​ ​ — ​ ​ 66,289 ​ Intercompany payable ​ ​ 111,620 ​ ​ — ​ ​ 4,141 ​ ​ (115,761) ​ ​ — ​ Accrued liabilities ​ ​ 392,949 ​ ​ — ​ ​ 72,121 ​ ​ — ​ ​ 465,070 ​ Revenue distributions payable ​ ​ 310,827 ​ ​ — ​ ​ — ​ ​ — ​ ​ 310,827 ​ Derivative instruments ​ ​ 532 ​ ​ — ​ ​ — ​ ​ — ​ ​ 532 ​ Short-term lease liabilities ​ ​ 2,459 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,459 ​ Other current liabilities ​ ​ 2,162 ​ ​ — ​ ​ 2,052 ​ ​ 4,149 ​ ​ 8,363 ​ Total current liabilities ​ ​ 865,466 ​ ​ — ​ ​ 99,686 ​ ​ (111,612) ​ ​ 853,540 ​ Long-term liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Long-term debt ​ ​ 3,829,541 ​ ​ — ​ ​ 1,632,147 ​ ​ — ​ ​ 5,461,688 ​ Deferred income tax liability ​ ​ 650,788 ​ ​ — ​ ​ — ​ ​ — ​ ​ 650,788 ​ Contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 114,995 ​ ​ (114,995) ​ ​ — ​ Long-term lease liabilities ​ ​ 2,873 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,873 ​ Other liabilities ​ ​ 55,017 ​ ​ — ​ ​ 8,081 ​ ​ — ​ ​ 63,098 ​ Total liabilities ​ ​ 5,403,685 ​ ​ — ​ ​ 1,854,909 ​ ​ (226,607) ​ ​ 7,031,987 ​ Equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stockholders' equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Partners' capital ​ ​ — ​ ​ — ​ ​ 1,691,508 ​ ​ (1,691,508) ​ ​ — ​ Common stock ​ ​ 3,086 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,086 ​ Additional paid-in capital ​ ​ 5,471,341 ​ ​ — ​ ​ — ​ ​ 1,013,833 ​ ​ 6,485,174 ​ Accumulated earnings ​ ​ 1,177,548 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,177,548 ​ Total stockholders' equity ​ ​ 6,651,975 ​ ​ — ​ ​ 1,691,508 ​ ​ (677,675) ​ ​ 7,665,808 ​ Noncontrolling interests in consolidated subsidiary ​ ​ — ​ ​ — ​ ​ — ​ ​ 821,669 ​ ​ 821,669 ​ Total equity ​ ​ 6,651,975 ​ ​ — ​ ​ 1,691,508 ​ ​ 143,994 ​ ​ 8,487,477 ​ Total liabilities and equity ​ $ 12,055,660 ​ ​ — ​ ​ 3,546,417 ​ ​ (82,613) ​ ​ 15,519,464 ​ ​ Condensed Consolidating Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Assets ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts receivable, net ​ ​ 29,207 ​ ​ — ​ ​ — ​ ​ — ​ ​ 29,207 ​ Intercompany receivables ​ ​ — ​ ​ 131,135 ​ ​ — ​ ​ (131,135) ​ ​ — ​ Accrued revenue ​ ​ 281,177 ​ ​ — ​ ​ — ​ ​ — ​ ​ 281,177 ​ Derivative instruments ​ ​ 411,774 ​ ​ — ​ ​ — ​ ​ — ​ ​ 411,774 ​ Other current assets ​ ​ 7,342 ​ ​ — ​ ​ — ​ ​ — ​ ​ 7,342 ​ Total current assets ​ ​ 729,500 ​ ​ 131,135 ​ ​ — ​ ​ (131,135) ​ ​ 729,500 ​ Property and equipment: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil and gas properties, at cost (successful efforts method): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Unproved properties ​ ​ 1,406,464 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,406,464 ​ Proved properties ​ ​ 11,568,285 ​ ​ — ​ ​ — ​ ​ — ​ ​ 11,568,285 ​ Gathering systems and facilities ​ ​ 5,802 ​ ​ — ​ ​ — ​ ​ — ​ ​ 5,802 ​ Other property and equipment ​ ​ 70,965 ​ ​ — ​ ​ — ​ ​ — ​ ​ 70,965 ​ ​ ​ ​ 13,051,516 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,051,516 ​ Less accumulated depletion, depreciation, and amortization ​ ​ (3,136,767) ​ ​ — ​ ​ — ​ ​ — ​ ​ (3,136,767) ​ Property and equipment, net ​ ​ 9,914,749 ​ ​ — ​ ​ — ​ ​ — ​ ​ 9,914,749 ​ Operating leases right-of-use assets ​ ​ 3,230,148 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,230,148 ​ Derivative instruments ​ ​ 405,180 ​ ​ — ​ ​ — ​ ​ — ​ ​ 405,180 ​ Investments in unconsolidated affiliates ​ ​ 481,474 ​ ​ 1,337,849 ​ ​ — ​ ​ — ​ ​ 1,819,323 ​ Investments in consolidated affiliates ​ ​ 1,337,849 ​ ​ — ​ ​ — ​ ​ (1,337,849) ​ ​ — ​ Other assets ​ ​ 21,388 ​ ​ — ​ ​ — ​ ​ — ​ ​ 21,388 ​ Total assets ​ $ 16,120,288 ​ ​ 1,468,984 ​ ​ — ​ ​ (1,468,984) ​ ​ 16,120,288 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liabilities and Equity ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts payable ​ $ 32,496 ​ ​ — ​ ​ — ​ ​ — ​ ​ 32,496 ​ Accounts payable, related parties ​ ​ 300,774 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 100,437 ​ Accrued liabilities ​ ​ 392,726 ​ ​ — ​ ​ — ​ ​ — ​ ​ 392,726 ​ Revenue distributions payable ​ ​ 231,152 ​ ​ — ​ ​ — ​ ​ — ​ ​ 231,152 ​ Short-term lease liabilities ​ ​ 409,990 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 409,990 ​ Other current liabilities ​ ​ 4,367 ​ ​ — ​ ​ — ​ ​ — ​ ​ 4,367 ​ Total current liabilities ​ ​ 1,371,505 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 1,171,168 ​ Long-term liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Long-term debt ​ ​ 3,703,828 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,703,828 ​ Deferred income tax liability ​ ​ 916,031 ​ ​ — ​ ​ — ​ ​ — ​ ​ 916,031 ​ Long-term lease liabilities ​ ​ 2,823,197 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 2,823,197 ​ Other liabilities ​ ​ 59,366 ​ ​ — ​ ​ — ​ ​ — ​ ​ 59,366 ​ Total liabilities ​ ​ 8,873,927 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 8,673,590 ​ Equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stockholders' equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Partners' capital ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Common stock ​ ​ 3,041 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,041 ​ Additional paid-in capital ​ ​ 6,124,042 ​ ​ 1,337,849 ​ ​ — ​ ​ (1,337,849) ​ ​ 6,124,042 ​ Accumulated earnings ​ ​ 1,119,278 ​ ​ 131,135 ​ ​ — ​ ​ 69,202 ​ ​ 1,319,615 ​ Total equity ​ ​ 7,246,361 ​ ​ 1,468,984 ​ ​ — ​ ​ (1,268,647) ​ ​ 7,446,698 ​ Total liabilities and equity ​ $ 16,120,288 ​ ​ 1,468,984 ​ ​ — ​ ​ (1,468,984) ​ ​ 16,120,288 ​
Schedule of condensed consolidated statement of operations and comprehensive income (loss)	Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) Three Months Ended September 30, 2018 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 527,122 ​ ​ — ​ ​ — ​ ​ — ​ ​ 527,122 ​ Natural gas liquids sales ​ 338,269 ​ — ​ — ​ — ​ 338,269 ​ Oil sales ​ ​ 59,722 ​ ​ — ​ ​ — ​ ​ — ​ ​ 59,722 ​ Commodity derivative fair value gains ​ ​ 57,019 ​ ​ — ​ ​ — ​ ​ — ​ ​ 57,019 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 266,205 ​ ​ (261,361) ​ ​ 4,844 ​ Marketing ​ ​ 89,598 ​ ​ — ​ ​ — ​ ​ — ​ ​ 89,598 ​ Marketing derivative fair value losses ​ ​ (42) ​ ​ — ​ ​ — ​ ​ — ​ ​ (42) ​ Other income ​ ​ 5,327 ​ ​ — ​ ​ — ​ ​ (5,327) ​ ​ — ​ Total revenue and other ​ ​ 1,077,015 ​ ​ — ​ ​ 266,205 ​ ​ (266,688) ​ ​ 1,076,532 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 35,124 ​ ​ — ​ ​ 67,608 ​ ​ (66,463) ​ ​ 36,269 ​ Gathering, compression, processing, and transportation ​ ​ 442,602 ​ ​ — ​ ​ 12,701 ​ ​ (128,799) ​ ​ 326,504 ​ Production and ad valorem taxes ​ ​ 29,352 ​ ​ — ​ ​ 1,166 ​ ​ — ​ ​ 30,518 ​ Marketing ​ ​ 151,764 ​ ​ — ​ ​ — ​ ​ — ​ ​ 151,764 ​ Exploration ​ ​ 666 ​ ​ — ​ ​ — ​ ​ — ​ ​ 666 ​ Impairment of oil and gas properties ​ ​ 221,094 ​ ​ — ​ ​ — ​ ​ — ​ ​ 221,094 ​ Impairment of midstream assets ​ ​ — ​ ​ — ​ ​ 1,157 ​ ​ — ​ ​ 1,157 ​ Depletion, depreciation, and amortization ​ ​ 204,730 ​ ​ — ​ ​ 38,456 ​ ​ — ​ ​ 243,186 ​ Accretion of asset retirement obligations ​ ​ 677 ​ ​ — ​ ​ 33 ​ ​ — ​ ​ 710 ​ General and administrative ​ ​ 45,477 ​ ​ — ​ ​ 15,015 ​ ​ (632) ​ ​ 59,860 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 4,020 ​ ​ (4,020) ​ ​ — ​ Total operating expenses ​ ​ 1,131,486 ​ ​ — ​ ​ 140,156 ​ ​ (199,914) ​ ​ 1,071,728 ​ Operating income (loss) ​ ​ (54,471) ​ ​ — ​ ​ 126,049 ​ ​ (66,774) ​ ​ 4,804 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 10,705 ​ ​ — ​ ​ 10,705 ​ Interest expense, net ​ ​ (57,632) ​ ​ — ​ ​ (16,989) ​ ​ 93 ​ ​ (74,528) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (23,363) ​ ​ — ​ ​ — ​ ​ 23,363 ​ ​ — ​ Total other expenses ​ ​ (80,995) ​ ​ — ​ ​ (6,284) ​ ​ 23,456 ​ ​ (63,823) ​ Income (loss) before income taxes ​ ​ (135,466) ​ ​ — ​ ​ 119,765 ​ ​ (43,318) ​ ​ (59,019) ​ Provision for income tax expense ​ ​ (18,953) ​ ​ — ​ ​ — ​ ​ — ​ ​ (18,953) ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (154,419) ​ ​ — ​ ​ 119,765 ​ ​ (43,318) ​ ​ (77,972) ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 76,447 ​ ​ 76,447 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (154,419) ​ ​ — ​ ​ 119,765 ​ ​ (119,765) ​ ​ (154,419) ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) Three Months Ended September 30, 2019 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 524,448 ​ ​ — ​ ​ — ​ ​ — ​ ​ 524,448 ​ Natural gas liquids sales ​ 284,958 ​ — ​ — ​ — ​ 284,958 ​ Oil sales ​ ​ 40,561 ​ ​ — ​ ​ — ​ ​ — ​ ​ 40,561 ​ Commodity derivative fair value gains ​ ​ 220,788 ​ ​ — ​ ​ — ​ ​ — ​ ​ 220,788 ​ Marketing ​ ​ 46,645 ​ ​ — ​ ​ — ​ ​ — ​ ​ 46,645 ​ Other income ​ ​ 1,481 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,481 ​ Total revenue and other ​ ​ 1,118,881 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,118,881 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 35,928 ​ ​ — ​ ​ — ​ ​ — ​ ​ 35,928 ​ Gathering, compression, processing, and transportation ​ ​ 603,860 ​ ​ — ​ ​ — ​ ​ — ​ ​ 603,860 ​ Production and ad valorem taxes ​ ​ 28,863 ​ ​ — ​ ​ — ​ ​ — ​ ​ 28,863 ​ Marketing ​ ​ 108,216 ​ ​ — ​ ​ — ​ ​ — ​ ​ 108,216 ​ Exploration ​ ​ 208 ​ ​ — ​ ​ — ​ ​ — ​ ​ 208 ​ Impairment of oil and gas properties ​ ​ 1,041,469 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,041,469 ​ Impairment of midstream assets ​ ​ 7,800 ​ ​ — ​ ​ — ​ ​ — ​ ​ 7,800 ​ Depletion, depreciation, and amortization ​ ​ 241,503 ​ ​ — ​ ​ — ​ ​ — ​ ​ 241,503 ​ Accretion of asset retirement obligations ​ ​ 927 ​ ​ — ​ ​ — ​ ​ — ​ ​ 927 ​ General and administrative ​ ​ 35,923 ​ ​ — ​ ​ — ​ ​ — ​ ​ 35,923 ​ Contract termination and rig stacking ​ ​ 62 ​ ​ — ​ ​ — ​ ​ — ​ ​ 62 ​ Total operating expenses ​ ​ 2,104,759 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,104,759 ​ Operating loss ​ ​ (985,878) ​ ​ — ​ ​ — ​ ​ — ​ ​ (985,878) ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ (38,255) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (117,859) ​ Interest expense, net ​ ​ (47,754) ​ ​ — ​ ​ — ​ ​ — ​ ​ (47,754) ​ Total other expenses ​ ​ (86,009) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (165,613) ​ Loss before income taxes ​ ​ (1,071,887) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (1,151,491) ​ Provision for income tax benefit ​ ​ 272,627 ​ ​ — ​ ​ — ​ ​ — ​ ​ 272,627 ​ Net loss and comprehensive loss attributable to Antero Resources Corporation ​ $ (799,260) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (878,864) ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) Nine Months Ended September 30, 2018 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 1,498,324 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,498,324 ​ Natural gas liquids sales ​ 828,424 ​ — ​ — ​ — ​ 828,424 ​ Oil sales ​ ​ 128,869 ​ ​ — ​ ​ — ​ ​ — ​ ​ 128,869 ​ Commodity derivative fair value gains ​ ​ 134,793 ​ ​ — ​ ​ — ​ ​ — ​ ​ 134,793 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 746,188 ​ ​ (730,890) ​ ​ 15,298 ​ Marketing ​ ​ 394,189 ​ ​ — ​ ​ — ​ ​ — ​ ​ 394,189 ​ Marketing derivative fair value gains ​ ​ 94,081 ​ ​ — ​ ​ — ​ ​ — ​ ​ 94,081 ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ 583 ​ ​ (583) ​ ​ — ​ Other income ​ ​ 16,381 ​ ​ — ​ ​ — ​ ​ (16,381) ​ ​ — ​ Total revenue and other ​ ​ 3,095,061 ​ ​ — ​ ​ 746,771 ​ ​ (747,854) ​ ​ 3,093,978 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 98,698 ​ ​ — ​ ​ 184,698 ​ ​ (190,241) ​ ​ 93,155 ​ Gathering, compression, processing, and transportation ​ ​ 1,236,655 ​ ​ — ​ ​ 36,469 ​ ​ (346,896) ​ ​ 926,228 ​ Production and ad valorem taxes ​ ​ 79,045 ​ ​ — ​ ​ 3,187 ​ ​ — ​ ​ 82,232 ​ Marketing ​ ​ 560,924 ​ ​ — ​ ​ — ​ ​ — ​ ​ 560,924 ​ Exploration ​ ​ 4,022 ​ ​ — ​ ​ — ​ ​ — ​ ​ 4,022 ​ Impairment of oil and gas properties ​ ​ 406,068 ​ ​ — ​ ​ — ​ ​ — ​ ​ 406,068 ​ Impairment of midstream assets ​ ​ 4,470 ​ ​ — ​ ​ 5,771 ​ ​ (583) ​ ​ 9,658 ​ Depletion, depreciation, and amortization ​ ​ 602,159 ​ ​ — ​ ​ 107,321 ​ ​ — ​ ​ 709,480 ​ Accretion of asset retirement obligations ​ ​ 2,000 ​ ​ — ​ ​ 101 ​ ​ — ​ ​ 2,101 ​ General and administrative ​ ​ 138,555 ​ ​ — ​ ​ 44,967 ​ ​ (1,946) ​ ​ 181,576 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 11,841 ​ ​ (11,841) ​ ​ — ​ Total operating expenses ​ ​ 3,132,596 ​ ​ — ​ ​ 394,355 ​ ​ (551,507) ​ ​ 2,975,444 ​ Operating income (loss) ​ ​ (37,535) ​ ​ — ​ ​ 352,416 ​ ​ (196,347) ​ ​ 118,534 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 27,832 ​ ​ — ​ ​ 27,832 ​ Interest expense, net ​ ​ (165,519) ​ ​ — ​ ​ (42,913) ​ ​ 129 ​ ​ (208,303) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (70,417) ​ ​ — ​ ​ — ​ ​ 70,417 ​ ​ — ​ Total other expenses ​ ​ (235,936) ​ ​ — ​ ​ (15,081) ​ ​ 70,546 ​ ​ (180,471) ​ Income (loss) before income taxes ​ ​ (273,471) ​ ​ — ​ ​ 337,335 ​ ​ (125,801) ​ ​ (61,937) ​ Provision for income tax expense ​ ​ (2,500) ​ ​ — ​ ​ — ​ ​ — ​ ​ (2,500) ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (275,971) ​ ​ — ​ ​ 337,335 ​ ​ (125,801) ​ ​ (64,437) ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 211,534 ​ ​ 211,534 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (275,971) ​ ​ — ​ ​ 337,335 ​ ​ (337,335) ​ ​ (275,971) ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 1,735,086 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,735,086 ​ Natural gas liquids sales ​ 902,606 ​ — ​ — ​ — ​ 902,606 ​ Oil sales ​ ​ 137,675 ​ ​ — ​ ​ — ​ ​ — ​ ​ 137,675 ​ Commodity derivative fair value gains ​ ​ 471,847 ​ ​ — ​ ​ — ​ ​ — ​ ​ 471,847 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 218,360 ​ ​ (213,881) ​ ​ 4,479 ​ Marketing ​ ​ 200,911 ​ ​ — ​ ​ — ​ ​ — ​ ​ 200,911 ​ Other income ​ ​ 4,999 ​ ​ — ​ ​ — ​ ​ (1,651) ​ ​ 3,348 ​ Total revenue and other ​ ​ 3,453,124 ​ ​ — ​ ​ 218,360 ​ ​ (215,532) ​ ​ 3,455,952 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 119,754 ​ ​ — ​ ​ 64,818 ​ ​ (66,055) ​ ​ 118,517 ​ Gathering, compression, processing, and transportation ​ ​ 1,705,709 ​ ​ — ​ ​ — ​ ​ (110,486) ​ ​ 1,595,223 ​ Production and ad valorem taxes ​ ​ 94,569 ​ ​ — ​ ​ — ​ ​ 940 ​ ​ 95,509 ​ Marketing ​ ​ 408,839 ​ ​ — ​ ​ — ​ ​ — ​ ​ 408,839 ​ Exploration ​ ​ 648 ​ ​ — ​ ​ — ​ ​ — ​ ​ 648 ​ Impairment of oil and gas properties ​ ​ 1,253,712 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,253,712 ​ Impairment of midstream assets ​ ​ 7,800 ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 14,782 ​ Depletion, depreciation, and amortization ​ ​ 702,299 ​ ​ — ​ ​ 21,707 ​ ​ — ​ ​ 724,006 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Accretion of asset retirement obligations ​ ​ 2,758 ​ ​ — ​ ​ 63 ​ ​ — ​ ​ 2,821 ​ General and administrative ​ ​ 128,213 ​ ​ — ​ ​ 18,793 ​ ​ (499) ​ ​ 146,507 ​ Contract termination and rig stacking ​ ​ 14,026 ​ ​ — ​ ​ — ​ ​ — ​ ​ 14,026 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 1,928 ​ ​ (1,928) ​ ​ — ​ Total operating expenses ​ ​ 4,439,278 ​ ​ — ​ ​ 114,291 ​ ​ (178,028) ​ ​ 4,375,541 ​ Operating income (loss) ​ ​ (986,154) ​ ​ — ​ ​ 104,069 ​ ​ (37,504) ​ ​ (919,589) ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings (loss) of unconsolidated affiliates ​ ​ (33,255) ​ ​ (69,202) ​ ​ 12,264 ​ ​ — ​ ​ (90,193) ​ Interest expense, net ​ ​ (157,053) ​ ​ — ​ ​ (16,815) ​ ​ — ​ ​ (173,868) ​ Equity in earnings of affiliates ​ ​ 15,021 ​ ​ — ​ ​ — ​ ​ (15,021) ​ ​ — ​ Gain on deconsolidation of Antero Midstream Partners LP ​ ​ 1,205,705 ​ ​ 200,337 ​ ​ — ​ ​ — ​ ​ 1,406,042 ​ Total other income (expenses) ​ ​ 1,030,418 ​ ​ 131,135 ​ ​ (4,551) ​ ​ (15,021) ​ ​ 1,141,981 ​ Income before income taxes ​ ​ 44,264 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 222,392 ​ Provision for income tax expense ​ ​ (33,332) ​ ​ — ​ ​ — ​ ​ — ​ ​ (33,332) ​ Net income and comprehensive income including noncontrolling interests ​ ​ 10,932 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 189,060 ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 46,993 ​ ​ 46,993 ​ Net income and comprehensive income attributable to Antero Resources Corporation ​ $ 10,932 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (99,518) ​ ​ 142,067 ​
Schedule of condensed consolidated statement of cash flows	​ (18) Subsidiary Guarantors Each of Antero’s wholly owned subsidiaries has fully and unconditionally guaranteed Antero’s 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 Condensed Consolidating Balance Sheets at December 31, 2018 and September 30, 2019, and the related Condensed Consolidating Statements of Operations and Comprehensive Income (Loss) for the three and nine months ended September 30, 2018 and 2019, and Condensed Consolidating Statements of Cash Flows for the nine months ended September 30, 2018 and 2019 present financial information for Antero on a stand-alone basis (carrying its investment in subsidiaries using the equity method), financial information for the subsidiary guarantors, financial information for the non-guarantor subsidiaries, and the consolidation and elimination entries necessary to arrive at the information for the Company on a consolidated basis. Antero’s wholly owned subsidiaries are not restricted from making distributions to Antero. ​ Condensed Consolidating Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Assets ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts receivable, net ​ $ 49,529 ​ ​ — ​ ​ 1,544 ​ ​ — ​ ​ 51,073 ​ Intercompany receivables ​ ​ 383 ​ ​ — ​ ​ 115,378 ​ ​ (115,761) ​ ​ — ​ Accrued revenue ​ ​ 474,827 ​ ​ — ​ ​ — ​ ​ — ​ ​ 474,827 ​ Derivative instruments ​ ​ 245,263 ​ ​ — ​ ​ — ​ ​ — ​ ​ 245,263 ​ Other current assets ​ ​ 13,937 ​ ​ — ​ ​ 21,513 ​ ​ — ​ ​ 35,450 ​ Total current assets ​ ​ 783,939 ​ ​ — ​ ​ 138,435 ​ ​ (115,761) ​ ​ 806,613 ​ Property and equipment: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil and gas properties, at cost (successful efforts method): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Unproved properties ​ ​ 1,767,600 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,767,600 ​ Proved properties ​ ​ 13,306,585 ​ ​ — ​ ​ — ​ ​ (600,913) ​ ​ 12,705,672 ​ Water handling and treatment systems ​ ​ — ​ ​ — ​ ​ 1,004,793 ​ ​ 9,025 ​ ​ 1,013,818 ​ Gathering systems and facilities ​ ​ 17,825 ​ ​ — ​ ​ 2,452,883 ​ ​ — ​ ​ 2,470,708 ​ Other property and equipment ​ ​ 65,770 ​ ​ — ​ ​ 72 ​ ​ — ​ ​ 65,842 ​ ​ ​ ​ 15,157,780 ​ ​ — ​ ​ 3,457,748 ​ ​ (591,888) ​ ​ 18,023,640 ​ Less accumulated depletion, depreciation, and amortization ​ ​ (3,654,392) ​ ​ — ​ ​ (499,333) ​ ​ — ​ ​ (4,153,725) ​ Property and equipment, net ​ ​ 11,503,388 ​ ​ — ​ ​ 2,958,415 ​ ​ (591,888) ​ ​ 13,869,915 ​ Derivative instruments ​ ​ 362,169 ​ ​ — ​ ​ — ​ ​ — ​ ​ 362,169 ​ Investment in Antero Midstream Partners ​ ​ (740,031) ​ ​ — ​ ​ — ​ ​ 740,031 ​ ​ — ​ Contingent acquisition consideration ​ ​ 114,995 ​ ​ — ​ ​ — ​ ​ (114,995) ​ ​ — ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 433,642 ​ ​ — ​ ​ 433,642 ​ Other assets ​ ​ 31,200 ​ ​ — ​ ​ 15,925 ​ ​ — ​ ​ 47,125 ​ Total assets ​ $ 12,055,660 ​ ​ — ​ ​ 3,546,417 ​ ​ (82,613) ​ ​ 15,519,464 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liabilities and Equity ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts payable ​ $ 44,917 ​ ​ — ​ ​ 21,372 ​ ​ — ​ ​ 66,289 ​ Intercompany payable ​ ​ 111,620 ​ ​ — ​ ​ 4,141 ​ ​ (115,761) ​ ​ — ​ Accrued liabilities ​ ​ 392,949 ​ ​ — ​ ​ 72,121 ​ ​ — ​ ​ 465,070 ​ Revenue distributions payable ​ ​ 310,827 ​ ​ — ​ ​ — ​ ​ — ​ ​ 310,827 ​ Derivative instruments ​ ​ 532 ​ ​ — ​ ​ — ​ ​ — ​ ​ 532 ​ Short-term lease liabilities ​ ​ 2,459 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,459 ​ Other current liabilities ​ ​ 2,162 ​ ​ — ​ ​ 2,052 ​ ​ 4,149 ​ ​ 8,363 ​ Total current liabilities ​ ​ 865,466 ​ ​ — ​ ​ 99,686 ​ ​ (111,612) ​ ​ 853,540 ​ Long-term liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Long-term debt ​ ​ 3,829,541 ​ ​ — ​ ​ 1,632,147 ​ ​ — ​ ​ 5,461,688 ​ Deferred income tax liability ​ ​ 650,788 ​ ​ — ​ ​ — ​ ​ — ​ ​ 650,788 ​ Contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 114,995 ​ ​ (114,995) ​ ​ — ​ Long-term lease liabilities ​ ​ 2,873 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,873 ​ Other liabilities ​ ​ 55,017 ​ ​ — ​ ​ 8,081 ​ ​ — ​ ​ 63,098 ​ Total liabilities ​ ​ 5,403,685 ​ ​ — ​ ​ 1,854,909 ​ ​ (226,607) ​ ​ 7,031,987 ​ Equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stockholders' equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Partners' capital ​ ​ — ​ ​ — ​ ​ 1,691,508 ​ ​ (1,691,508) ​ ​ — ​ Common stock ​ ​ 3,086 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,086 ​ Additional paid-in capital ​ ​ 5,471,341 ​ ​ — ​ ​ — ​ ​ 1,013,833 ​ ​ 6,485,174 ​ Accumulated earnings ​ ​ 1,177,548 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,177,548 ​ Total stockholders' equity ​ ​ 6,651,975 ​ ​ — ​ ​ 1,691,508 ​ ​ (677,675) ​ ​ 7,665,808 ​ Noncontrolling interests in consolidated subsidiary ​ ​ — ​ ​ — ​ ​ — ​ ​ 821,669 ​ ​ 821,669 ​ Total equity ​ ​ 6,651,975 ​ ​ — ​ ​ 1,691,508 ​ ​ 143,994 ​ ​ 8,487,477 ​ Total liabilities and equity ​ $ 12,055,660 ​ ​ — ​ ​ 3,546,417 ​ ​ (82,613) ​ ​ 15,519,464 ​ ​ Condensed Consolidating Balance Sheet ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Assets ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts receivable, net ​ ​ 29,207 ​ ​ — ​ ​ — ​ ​ — ​ ​ 29,207 ​ Intercompany receivables ​ ​ — ​ ​ 131,135 ​ ​ — ​ ​ (131,135) ​ ​ — ​ Accrued revenue ​ ​ 281,177 ​ ​ — ​ ​ — ​ ​ — ​ ​ 281,177 ​ Derivative instruments ​ ​ 411,774 ​ ​ — ​ ​ — ​ ​ — ​ ​ 411,774 ​ Other current assets ​ ​ 7,342 ​ ​ — ​ ​ — ​ ​ — ​ ​ 7,342 ​ Total current assets ​ ​ 729,500 ​ ​ 131,135 ​ ​ — ​ ​ (131,135) ​ ​ 729,500 ​ Property and equipment: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil and gas properties, at cost (successful efforts method): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Unproved properties ​ ​ 1,406,464 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,406,464 ​ Proved properties ​ ​ 11,568,285 ​ ​ — ​ ​ — ​ ​ — ​ ​ 11,568,285 ​ Gathering systems and facilities ​ ​ 5,802 ​ ​ — ​ ​ — ​ ​ — ​ ​ 5,802 ​ Other property and equipment ​ ​ 70,965 ​ ​ — ​ ​ — ​ ​ — ​ ​ 70,965 ​ ​ ​ ​ 13,051,516 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,051,516 ​ Less accumulated depletion, depreciation, and amortization ​ ​ (3,136,767) ​ ​ — ​ ​ — ​ ​ — ​ ​ (3,136,767) ​ Property and equipment, net ​ ​ 9,914,749 ​ ​ — ​ ​ — ​ ​ — ​ ​ 9,914,749 ​ Operating leases right-of-use assets ​ ​ 3,230,148 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,230,148 ​ Derivative instruments ​ ​ 405,180 ​ ​ — ​ ​ — ​ ​ — ​ ​ 405,180 ​ Investments in unconsolidated affiliates ​ ​ 481,474 ​ ​ 1,337,849 ​ ​ — ​ ​ — ​ ​ 1,819,323 ​ Investments in consolidated affiliates ​ ​ 1,337,849 ​ ​ — ​ ​ — ​ ​ (1,337,849) ​ ​ — ​ Other assets ​ ​ 21,388 ​ ​ — ​ ​ — ​ ​ — ​ ​ 21,388 ​ Total assets ​ $ 16,120,288 ​ ​ 1,468,984 ​ ​ — ​ ​ (1,468,984) ​ ​ 16,120,288 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liabilities and Equity ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts payable ​ $ 32,496 ​ ​ — ​ ​ — ​ ​ — ​ ​ 32,496 ​ Accounts payable, related parties ​ ​ 300,774 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 100,437 ​ Accrued liabilities ​ ​ 392,726 ​ ​ — ​ ​ — ​ ​ — ​ ​ 392,726 ​ Revenue distributions payable ​ ​ 231,152 ​ ​ — ​ ​ — ​ ​ — ​ ​ 231,152 ​ Short-term lease liabilities ​ ​ 409,990 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 409,990 ​ Other current liabilities ​ ​ 4,367 ​ ​ — ​ ​ — ​ ​ — ​ ​ 4,367 ​ Total current liabilities ​ ​ 1,371,505 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 1,171,168 ​ Long-term liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Long-term debt ​ ​ 3,703,828 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,703,828 ​ Deferred income tax liability ​ ​ 916,031 ​ ​ — ​ ​ — ​ ​ — ​ ​ 916,031 ​ Long-term lease liabilities ​ ​ 2,823,197 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 2,823,197 ​ Other liabilities ​ ​ 59,366 ​ ​ — ​ ​ — ​ ​ — ​ ​ 59,366 ​ Total liabilities ​ ​ 8,873,927 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 8,673,590 ​ Equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stockholders' equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Partners' capital ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Common stock ​ ​ 3,041 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,041 ​ Additional paid-in capital ​ ​ 6,124,042 ​ ​ 1,337,849 ​ ​ — ​ ​ (1,337,849) ​ ​ 6,124,042 ​ Accumulated earnings ​ ​ 1,119,278 ​ ​ 131,135 ​ ​ — ​ ​ 69,202 ​ ​ 1,319,615 ​ Total equity ​ ​ 7,246,361 ​ ​ 1,468,984 ​ ​ — ​ ​ (1,268,647) ​ ​ 7,446,698 ​ Total liabilities and equity ​ $ 16,120,288 ​ ​ 1,468,984 ​ ​ — ​ ​ (1,468,984) ​ ​ 16,120,288 ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) Three Months Ended September 30, 2018 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 527,122 ​ ​ — ​ ​ — ​ ​ — ​ ​ 527,122 ​ Natural gas liquids sales ​ 338,269 ​ — ​ — ​ — ​ 338,269 ​ Oil sales ​ ​ 59,722 ​ ​ — ​ ​ — ​ ​ — ​ ​ 59,722 ​ Commodity derivative fair value gains ​ ​ 57,019 ​ ​ — ​ ​ — ​ ​ — ​ ​ 57,019 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 266,205 ​ ​ (261,361) ​ ​ 4,844 ​ Marketing ​ ​ 89,598 ​ ​ — ​ ​ — ​ ​ — ​ ​ 89,598 ​ Marketing derivative fair value losses ​ ​ (42) ​ ​ — ​ ​ — ​ ​ — ​ ​ (42) ​ Other income ​ ​ 5,327 ​ ​ — ​ ​ — ​ ​ (5,327) ​ ​ — ​ Total revenue and other ​ ​ 1,077,015 ​ ​ — ​ ​ 266,205 ​ ​ (266,688) ​ ​ 1,076,532 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 35,124 ​ ​ — ​ ​ 67,608 ​ ​ (66,463) ​ ​ 36,269 ​ Gathering, compression, processing, and transportation ​ ​ 442,602 ​ ​ — ​ ​ 12,701 ​ ​ (128,799) ​ ​ 326,504 ​ Production and ad valorem taxes ​ ​ 29,352 ​ ​ — ​ ​ 1,166 ​ ​ — ​ ​ 30,518 ​ Marketing ​ ​ 151,764 ​ ​ — ​ ​ — ​ ​ — ​ ​ 151,764 ​ Exploration ​ ​ 666 ​ ​ — ​ ​ — ​ ​ — ​ ​ 666 ​ Impairment of oil and gas properties ​ ​ 221,094 ​ ​ — ​ ​ — ​ ​ — ​ ​ 221,094 ​ Impairment of midstream assets ​ ​ — ​ ​ — ​ ​ 1,157 ​ ​ — ​ ​ 1,157 ​ Depletion, depreciation, and amortization ​ ​ 204,730 ​ ​ — ​ ​ 38,456 ​ ​ — ​ ​ 243,186 ​ Accretion of asset retirement obligations ​ ​ 677 ​ ​ — ​ ​ 33 ​ ​ — ​ ​ 710 ​ General and administrative ​ ​ 45,477 ​ ​ — ​ ​ 15,015 ​ ​ (632) ​ ​ 59,860 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 4,020 ​ ​ (4,020) ​ ​ — ​ Total operating expenses ​ ​ 1,131,486 ​ ​ — ​ ​ 140,156 ​ ​ (199,914) ​ ​ 1,071,728 ​ Operating income (loss) ​ ​ (54,471) ​ ​ — ​ ​ 126,049 ​ ​ (66,774) ​ ​ 4,804 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 10,705 ​ ​ — ​ ​ 10,705 ​ Interest expense, net ​ ​ (57,632) ​ ​ — ​ ​ (16,989) ​ ​ 93 ​ ​ (74,528) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (23,363) ​ ​ — ​ ​ — ​ ​ 23,363 ​ ​ — ​ Total other expenses ​ ​ (80,995) ​ ​ — ​ ​ (6,284) ​ ​ 23,456 ​ ​ (63,823) ​ Income (loss) before income taxes ​ ​ (135,466) ​ ​ — ​ ​ 119,765 ​ ​ (43,318) ​ ​ (59,019) ​ Provision for income tax expense ​ ​ (18,953) ​ ​ — ​ ​ — ​ ​ — ​ ​ (18,953) ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (154,419) ​ ​ — ​ ​ 119,765 ​ ​ (43,318) ​ ​ (77,972) ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 76,447 ​ ​ 76,447 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (154,419) ​ ​ — ​ ​ 119,765 ​ ​ (119,765) ​ ​ (154,419) ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) Three Months Ended September 30, 2019 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 524,448 ​ ​ — ​ ​ — ​ ​ — ​ ​ 524,448 ​ Natural gas liquids sales ​ 284,958 ​ — ​ — ​ — ​ 284,958 ​ Oil sales ​ ​ 40,561 ​ ​ — ​ ​ — ​ ​ — ​ ​ 40,561 ​ Commodity derivative fair value gains ​ ​ 220,788 ​ ​ — ​ ​ — ​ ​ — ​ ​ 220,788 ​ Marketing ​ ​ 46,645 ​ ​ — ​ ​ — ​ ​ — ​ ​ 46,645 ​ Other income ​ ​ 1,481 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,481 ​ Total revenue and other ​ ​ 1,118,881 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,118,881 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 35,928 ​ ​ — ​ ​ — ​ ​ — ​ ​ 35,928 ​ Gathering, compression, processing, and transportation ​ ​ 603,860 ​ ​ — ​ ​ — ​ ​ — ​ ​ 603,860 ​ Production and ad valorem taxes ​ ​ 28,863 ​ ​ — ​ ​ — ​ ​ — ​ ​ 28,863 ​ Marketing ​ ​ 108,216 ​ ​ — ​ ​ — ​ ​ — ​ ​ 108,216 ​ Exploration ​ ​ 208 ​ ​ — ​ ​ — ​ ​ — ​ ​ 208 ​ Impairment of oil and gas properties ​ ​ 1,041,469 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,041,469 ​ Impairment of midstream assets ​ ​ 7,800 ​ ​ — ​ ​ — ​ ​ — ​ ​ 7,800 ​ Depletion, depreciation, and amortization ​ ​ 241,503 ​ ​ — ​ ​ — ​ ​ — ​ ​ 241,503 ​ Accretion of asset retirement obligations ​ ​ 927 ​ ​ — ​ ​ — ​ ​ — ​ ​ 927 ​ General and administrative ​ ​ 35,923 ​ ​ — ​ ​ — ​ ​ — ​ ​ 35,923 ​ Contract termination and rig stacking ​ ​ 62 ​ ​ — ​ ​ — ​ ​ — ​ ​ 62 ​ Total operating expenses ​ ​ 2,104,759 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,104,759 ​ Operating loss ​ ​ (985,878) ​ ​ — ​ ​ — ​ ​ — ​ ​ (985,878) ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ (38,255) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (117,859) ​ Interest expense, net ​ ​ (47,754) ​ ​ — ​ ​ — ​ ​ — ​ ​ (47,754) ​ Total other expenses ​ ​ (86,009) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (165,613) ​ Loss before income taxes ​ ​ (1,071,887) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (1,151,491) ​ Provision for income tax benefit ​ ​ 272,627 ​ ​ — ​ ​ — ​ ​ — ​ ​ 272,627 ​ Net loss and comprehensive loss attributable to Antero Resources Corporation ​ $ (799,260) ​ ​ (79,604) ​ ​ — ​ ​ — ​ ​ (878,864) ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) Nine Months Ended September 30, 2018 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 1,498,324 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,498,324 ​ Natural gas liquids sales ​ 828,424 ​ — ​ — ​ — ​ 828,424 ​ Oil sales ​ ​ 128,869 ​ ​ — ​ ​ — ​ ​ — ​ ​ 128,869 ​ Commodity derivative fair value gains ​ ​ 134,793 ​ ​ — ​ ​ — ​ ​ — ​ ​ 134,793 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 746,188 ​ ​ (730,890) ​ ​ 15,298 ​ Marketing ​ ​ 394,189 ​ ​ — ​ ​ — ​ ​ — ​ ​ 394,189 ​ Marketing derivative fair value gains ​ ​ 94,081 ​ ​ — ​ ​ — ​ ​ — ​ ​ 94,081 ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ 583 ​ ​ (583) ​ ​ — ​ Other income ​ ​ 16,381 ​ ​ — ​ ​ — ​ ​ (16,381) ​ ​ — ​ Total revenue and other ​ ​ 3,095,061 ​ ​ — ​ ​ 746,771 ​ ​ (747,854) ​ ​ 3,093,978 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 98,698 ​ ​ — ​ ​ 184,698 ​ ​ (190,241) ​ ​ 93,155 ​ Gathering, compression, processing, and transportation ​ ​ 1,236,655 ​ ​ — ​ ​ 36,469 ​ ​ (346,896) ​ ​ 926,228 ​ Production and ad valorem taxes ​ ​ 79,045 ​ ​ — ​ ​ 3,187 ​ ​ — ​ ​ 82,232 ​ Marketing ​ ​ 560,924 ​ ​ — ​ ​ — ​ ​ — ​ ​ 560,924 ​ Exploration ​ ​ 4,022 ​ ​ — ​ ​ — ​ ​ — ​ ​ 4,022 ​ Impairment of oil and gas properties ​ ​ 406,068 ​ ​ — ​ ​ — ​ ​ — ​ ​ 406,068 ​ Impairment of midstream assets ​ ​ 4,470 ​ ​ — ​ ​ 5,771 ​ ​ (583) ​ ​ 9,658 ​ Depletion, depreciation, and amortization ​ ​ 602,159 ​ ​ — ​ ​ 107,321 ​ ​ — ​ ​ 709,480 ​ Accretion of asset retirement obligations ​ ​ 2,000 ​ ​ — ​ ​ 101 ​ ​ — ​ ​ 2,101 ​ General and administrative ​ ​ 138,555 ​ ​ — ​ ​ 44,967 ​ ​ (1,946) ​ ​ 181,576 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 11,841 ​ ​ (11,841) ​ ​ — ​ Total operating expenses ​ ​ 3,132,596 ​ ​ — ​ ​ 394,355 ​ ​ (551,507) ​ ​ 2,975,444 ​ Operating income (loss) ​ ​ (37,535) ​ ​ — ​ ​ 352,416 ​ ​ (196,347) ​ ​ 118,534 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 27,832 ​ ​ — ​ ​ 27,832 ​ Interest expense, net ​ ​ (165,519) ​ ​ — ​ ​ (42,913) ​ ​ 129 ​ ​ (208,303) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (70,417) ​ ​ — ​ ​ — ​ ​ 70,417 ​ ​ — ​ Total other expenses ​ ​ (235,936) ​ ​ — ​ ​ (15,081) ​ ​ 70,546 ​ ​ (180,471) ​ Income (loss) before income taxes ​ ​ (273,471) ​ ​ — ​ ​ 337,335 ​ ​ (125,801) ​ ​ (61,937) ​ Provision for income tax expense ​ ​ (2,500) ​ ​ — ​ ​ — ​ ​ — ​ ​ (2,500) ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (275,971) ​ ​ — ​ ​ 337,335 ​ ​ (125,801) ​ ​ (64,437) ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 211,534 ​ ​ 211,534 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (275,971) ​ ​ — ​ ​ 337,335 ​ ​ (337,335) ​ ​ (275,971) ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 1,735,086 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,735,086 ​ Natural gas liquids sales ​ 902,606 ​ — ​ — ​ — ​ 902,606 ​ Oil sales ​ ​ 137,675 ​ ​ — ​ ​ — ​ ​ — ​ ​ 137,675 ​ Commodity derivative fair value gains ​ ​ 471,847 ​ ​ — ​ ​ — ​ ​ — ​ ​ 471,847 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 218,360 ​ ​ (213,881) ​ ​ 4,479 ​ Marketing ​ ​ 200,911 ​ ​ — ​ ​ — ​ ​ — ​ ​ 200,911 ​ Other income ​ ​ 4,999 ​ ​ — ​ ​ — ​ ​ (1,651) ​ ​ 3,348 ​ Total revenue and other ​ ​ 3,453,124 ​ ​ — ​ ​ 218,360 ​ ​ (215,532) ​ ​ 3,455,952 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 119,754 ​ ​ — ​ ​ 64,818 ​ ​ (66,055) ​ ​ 118,517 ​ Gathering, compression, processing, and transportation ​ ​ 1,705,709 ​ ​ — ​ ​ — ​ ​ (110,486) ​ ​ 1,595,223 ​ Production and ad valorem taxes ​ ​ 94,569 ​ ​ — ​ ​ — ​ ​ 940 ​ ​ 95,509 ​ Marketing ​ ​ 408,839 ​ ​ — ​ ​ — ​ ​ — ​ ​ 408,839 ​ Exploration ​ ​ 648 ​ ​ — ​ ​ — ​ ​ — ​ ​ 648 ​ Impairment of oil and gas properties ​ ​ 1,253,712 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,253,712 ​ Impairment of midstream assets ​ ​ 7,800 ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 14,782 ​ Depletion, depreciation, and amortization ​ ​ 702,299 ​ ​ — ​ ​ 21,707 ​ ​ — ​ ​ 724,006 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Accretion of asset retirement obligations ​ ​ 2,758 ​ ​ — ​ ​ 63 ​ ​ — ​ ​ 2,821 ​ General and administrative ​ ​ 128,213 ​ ​ — ​ ​ 18,793 ​ ​ (499) ​ ​ 146,507 ​ Contract termination and rig stacking ​ ​ 14,026 ​ ​ — ​ ​ — ​ ​ — ​ ​ 14,026 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 1,928 ​ ​ (1,928) ​ ​ — ​ Total operating expenses ​ ​ 4,439,278 ​ ​ — ​ ​ 114,291 ​ ​ (178,028) ​ ​ 4,375,541 ​ Operating income (loss) ​ ​ (986,154) ​ ​ — ​ ​ 104,069 ​ ​ (37,504) ​ ​ (919,589) ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings (loss) of unconsolidated affiliates ​ ​ (33,255) ​ ​ (69,202) ​ ​ 12,264 ​ ​ — ​ ​ (90,193) ​ Interest expense, net ​ ​ (157,053) ​ ​ — ​ ​ (16,815) ​ ​ — ​ ​ (173,868) ​ Equity in earnings of affiliates ​ ​ 15,021 ​ ​ — ​ ​ — ​ ​ (15,021) ​ ​ — ​ Gain on deconsolidation of Antero Midstream Partners LP ​ ​ 1,205,705 ​ ​ 200,337 ​ ​ — ​ ​ — ​ ​ 1,406,042 ​ Total other income (expenses) ​ ​ 1,030,418 ​ ​ 131,135 ​ ​ (4,551) ​ ​ (15,021) ​ ​ 1,141,981 ​ Income before income taxes ​ ​ 44,264 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 222,392 ​ Provision for income tax expense ​ ​ (33,332) ​ ​ — ​ ​ — ​ ​ — ​ ​ (33,332) ​ Net income and comprehensive income including noncontrolling interests ​ ​ 10,932 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 189,060 ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 46,993 ​ ​ 46,993 ​ Net income and comprehensive income attributable to Antero Resources Corporation ​ $ 10,932 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (99,518) ​ ​ 142,067 ​ ​ ​ Condensed Consolidating Statement of Cash Flows ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Cash flows provided by (used in) operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net income (loss) including noncontrolling interests ​ $ (275,971) ​ ​ — ​ ​ 337,335 ​ ​ (125,801) ​ ​ (64,437) ​ Adjustment to reconcile net income (loss) to net cash provided by operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depletion, depreciation, amortization, and accretion ​ ​ 604,159 ​ ​ — ​ ​ 107,422 ​ ​ — ​ ​ 711,581 ​ Accretion of contingent acquisition consideration ​ ​ (11,841) ​ ​ — ​ ​ 11,841 ​ ​ — ​ ​ — ​ Impairment of oil and gas properties ​ ​ 406,068 ​ ​ — ​ ​ — ​ ​ — ​ ​ 406,068 ​ Impairment of midstream assets ​ ​ 4,470 ​ ​ — ​ ​ 5,771 ​ ​ (583) ​ ​ 9,658 ​ Commodity derivative fair value gains ​ ​ (134,793) ​ ​ — ​ ​ — ​ ​ — ​ ​ (134,793) ​ Gains on settled commodity derivatives ​ ​ 268,369 ​ ​ — ​ ​ — ​ ​ — ​ ​ 268,369 ​ Marketing derivative fair value gains ​ ​ (94,081) ​ ​ — ​ ​ — ​ ​ — ​ ​ (94,081) ​ Gains on settled marketing derivatives ​ ​ 78,098 ​ ​ — ​ ​ — ​ ​ — ​ ​ 78,098 ​ Deferred income tax expense ​ ​ 2,500 ​ ​ — ​ ​ — ​ ​ — ​ ​ 2,500 ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ (583) ​ ​ 583 ​ ​ — ​ Equity-based compensation expense ​ ​ 39,823 ​ ​ — ​ ​ 16,606 ​ ​ — ​ ​ 56,429 ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ 70,417 ​ ​ — ​ ​ — ​ ​ (70,417) ​ ​ — ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (27,832) ​ ​ — ​ ​ (27,832) ​ Distributions of earnings from unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 29,660 ​ ​ — ​ ​ 29,660 ​ Distributions from Antero Midstream Partners LP ​ ​ 115,678 ​ ​ — ​ ​ — ​ ​ (115,678) ​ ​ — ​ Other ​ ​ 862 ​ ​ — ​ ​ 2,083 ​ ​ — ​ ​ 2,945 ​ Changes in current assets and liabilities ​ ​ 20,015 ​ ​ — ​ ​ (10,901) ​ ​ 7,119 ​ ​ 16,233 ​ Net cash provided by operating activities ​ ​ 1,093,773 ​ ​ — ​ ​ 471,402 ​ ​ (304,777) ​ ​ 1,260,398 ​ Cash flows provided by (used in) investing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Additions to unproved properties ​ ​ (130,381) ​ ​ — ​ ​ — ​ ​ — ​ ​ (130,381) ​ Drilling and completion costs ​ ​ (1,328,289) ​ ​ — ​ ​ — ​ ​ 202,629 ​ ​ (1,125,660) ​ Additions to water handling and treatment systems ​ ​ — ​ ​ — ​ ​ (68,325) ​ ​ (9,060) ​ ​ (77,385) ​ Additions to gathering systems and facilities ​ ​ 175 ​ ​ — ​ ​ (337,623) ​ ​ — ​ ​ (337,448) ​ Additions to other property and equipment ​ ​ (5,371) ​ ​ — ​ ​ — ​ ​ — ​ ​ (5,371) ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (91,419) ​ ​ — ​ ​ (91,419) ​ Change in other assets ​ ​ (1,810) ​ ​ — ​ ​ (865) ​ ​ — ​ ​ (2,675) ​ Other ​ ​ — ​ ​ — ​ ​ 4,470 ​ ​ (4,470) ​ ​ — ​ Net cash used in investing activities ​ ​ (1,465,676) ​ ​ — ​ ​ (493,762) ​ ​ 189,099 ​ ​ (1,770,339) ​ Cash flows provided by (used in) financing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Borrowings (repayments) on bank credit facility, net ​ ​ 362,000 ​ ​ — ​ ​ 320,000 ​ ​ — ​ ​ 682,000 ​ Distributions to noncontrolling interests in Antero Midstream Partners LP ​ ​ — ​ ​ — ​ ​ (304,453) ​ ​ 115,678 ​ ​ (188,775) ​ Employee tax withholding for settlement of equity compensation awards ​ ​ (6,806) ​ ​ — ​ ​ (1,399) ​ ​ — ​ ​ (8,205) ​ Other ​ ​ (3,369) ​ ​ — ​ ​ (151) ​ ​ — ​ ​ (3,520) ​ Net cash provided by financing activities ​ ​ 351,825 ​ ​ — ​ ​ 13,997 ​ ​ 115,678 ​ ​ 481,500 ​ Net decrease in cash and cash equivalents ​ ​ (20,078) ​ ​ — ​ ​ (8,363) ​ ​ — ​ ​ (28,441) ​ Cash and cash equivalents, beginning of period ​ ​ 20,078 ​ ​ — ​ ​ 8,363 ​ ​ — ​ ​ 28,441 ​ Cash and cash equivalents, end of period ​ $ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ ​ Condensed Consolidating Statement of Cash Flows Nine Months Ended September 30, 2019 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Cash flows provided by (used in) operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net income including noncontrolling interests ​ $ 10,932 ​ ​ 131,135 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 189,060 ​ Adjustment to reconcile net income to net cash provided by operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depletion, depreciation, amortization, and accretion ​ ​ 705,057 ​ ​ — ​ ​ 21,770 ​ ​ — ​ ​ 726,827 ​ Impairment of oil and gas properties ​ ​ 1,253,712 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,253,712 ​ Impairment of midstream assets ​ ​ 7,800 ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 14,782 ​ Commodity derivative fair value gains ​ ​ (471,847) ​ ​ — ​ ​ — ​ ​ — ​ ​ (471,847) ​ Gains on settled commodity derivatives ​ ​ 261,794 ​ ​ — ​ ​ — ​ ​ — ​ ​ 261,794 ​ Deferred income tax expense ​ ​ 32,019 ​ ​ — ​ ​ — ​ ​ — ​ ​ 32,019 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Equity-based compensation expense ​ ​ 16,850 ​ ​ — ​ ​ 2,477 ​ ​ — ​ ​ 19,327 ​ Equity in earnings of affiliates ​ ​ (15,021) ​ ​ — ​ ​ — ​ ​ 15,021 ​ ​ — ​ Equity in earnings (loss) of unconsolidated affiliates ​ ​ 33,255 ​ ​ 69,202 ​ ​ (12,264) ​ ​ — ​ ​ 90,193 ​ Distributions/dividends of earnings from unconsolidated affiliates ​ ​ 96,636 ​ ​ — ​ ​ 12,605 ​ ​ — ​ ​ 109,241 ​ Gain on deconsolidation of Antero Midstream Partners LP ​ ​ (1,205,705) ​ ​ (200,337) ​ ​ — ​ ​ — ​ ​ (1,406,042) ​ Distributions from Antero Midstream Partners LP ​ ​ 94,391 ​ ​ — ​ ​ — ​ ​ (94,391) ​ ​ — ​ Other ​ ​ (40,493) ​ ​ — ​ ​ 750 ​ ​ 47,922 ​ ​ 8,179 ​ Changes in current assets and liabilities ​ ​ 121,087 ​ ​ — ​ ​ (10,573) ​ ​ 16,808 ​ ​ 127,322 ​ Net cash provided by operating activities ​ ​ 901,418 ​ ​ — ​ ​ 121,265 ​ ​ (67,165) ​ ​ 955,518 ​ Cash flows provided by (used in) investing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Additions to unproved properties ​ ​ (69,796) ​ ​ — ​ ​ — ​ ​ — ​ ​ (69,796) ​ Drilling and completion costs ​ ​ (978,496) ​ ​ — ​ ​ — ​ ​ 20,565 ​ ​ (957,931) ​ Additions to water handling and treatment systems ​ ​ — ​ ​ — ​ ​ (24,547) ​ ​ 131 ​ ​ (24,416) ​ Additions to gathering systems and facilities ​ ​ — ​ ​ — ​ ​ (48,239) ​ ​ — ​ ​ (48,239) ​ Additions to other property and equipment ​ ​ (4,918) ​ ​ — ​ ​ (1,062) ​ ​ — ​ ​ (5,980) ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (25,020) ​ ​ — ​ ​ (25,020) ​ Proceeds from the Antero Midstream Partners LP Transactions ​ ​ 296,611 ​ ​ — ​ ​ — ​ ​ — ​ ​ 296,611 ​ Change in other assets ​ ​ 10,818 ​ ​ — ​ ​ (3,357) ​ ​ — ​ ​ 7,461 ​ Proceeds from sale of assets ​ ​ 1,983 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,983 ​ Net cash used in investing activities ​ ​ (743,798) ​ ​ — ​ ​ (102,225) ​ ​ 20,696 ​ ​ (825,327) ​ Cash flows provided by (used in) financing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Repurchases of common stock ​ ​ (17,924) ​ ​ — ​ ​ — ​ ​ — ​ ​ (17,924) ​ Issuance of senior notes ​ ​ — ​ ​ — ​ ​ 650,000 ​ ​ — ​ ​ 650,000 ​ Borrowings (repayments) on bank credit facility, net ​ ​ (135,379) ​ ​ — ​ ​ 90,379 ​ ​ — ​ ​ (45,000) ​ Payments of deferred financing costs ​ ​ (791) ​ ​ — ​ ​ (7,468) ​ ​ — ​ ​ (8,259) ​ Distributions to noncontrolling interests in Antero Midstream Partners LP ​ ​ — ​ ​ — ​ ​ (131,545) ​ ​ 46,469 ​ ​ (85,076) ​ Employee tax withholding for settlement of equity compensation awards ​ ​ (2,350) ​ ​ — ​ ​ (29) ​ ​ — ​ ​ (2,379) ​ Other ​ ​ (1,176) ​ ​ — ​ ​ (845) ​ ​ — ​ ​ (2,021) ​ Net cash provided by (used in) financing activities ​ ​ (157,620) ​ ​ — ​ ​ 600,492 ​ ​ 46,469 ​ ​ 489,341 ​ Effect of deconsolidation of Antero Midstream Partners LP ​ ​ — ​ ​ — ​ ​ (619,532) ​ ​ — ​ ​ (619,532) ​ Net increase in cash and cash equivalents ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Cash and cash equivalents, beginning of period ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Cash and cash equivalents, end of period ​ $ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Principles of Consolidation (Details) - USD ($) $ in Millions	Mar. 11, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Mar. 12, 2019	Dec. 31, 2018
Basis of Presentation
Other comprehensive income (loss)		$ 0	$ 0	$ 0	$ 0
Accounts Payable
Basis of Presentation
Bank Overdrafts		8		8			$ 10
Revenue distributions payable
Basis of Presentation
Bank Overdrafts		$ 34		$ 34			$ 28
Antero Midstream Corporation
Basis of Presentation
Ownership interest in equity method						31.00%
Antero Midstream Partners LP
Basis of Presentation
Ownership interest	53.00%

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Property and equipment (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019USD ($)a	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)
Oil and Gas Properties
Exploration			$ 0	$ 0
Impairment of oil and gas properties	$ 1,041,469	$ 221,094	1,253,712	406,068
Impairment of oil and gas properties for leases expired or expected to expire			347,000	406,000
Impairment of proved properties	$ 7,800	$ 1,157	14,782	$ 9,658
Land received in exchange | a	20,770
Land delivered in exchange | a	18,857
Acreage and ownership interest	$ 0
Utica Shale
Oil and Gas Properties
Impairment of proved properties			881,000
Oil and gas property wells
Oil and Gas Properties
Impairment of oil and gas properties			$ 26,000

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - EPS and New Accounting Principle (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Earnings per share
Basic weighted average number of shares outstanding	307,781	317,082	308,509	316,850
Diluted weighted average number of shares outstanding	307,781	317,082	308,646	316,850
Restricted stock and restricted stock unit
Earnings per share
Add: Dilutive effect of non-vested restricted stock units			27
Weighted Average Anti-dilutive Awards	2,356	2,813	2,008	2,996
Stock options
Earnings per share
Weighted Average Anti-dilutive Awards	514	619	541	637
Performance share unit awards
Earnings per share
Add: Dilutive effect of non-vested restricted stock units			110
Weighted Average Anti-dilutive Awards	2,676	1,880	2,141	1,665

Deconsolidation of Antero Mid_3

Deconsolidation of Antero Midstream Partners LP - Narrative (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Mar. 12, 2019	Mar. 11, 2019	Sep. 30, 2019	Dec. 31, 2018
Deconsolidation
Cash received			$ 296,611
Par value per share			$ 0.01	$ 0.01
Antero Midstream Corporation
Deconsolidation
Cash received	$ 297,000
Shares of Antero Midstream's common stock received	158,400
Par value per share	$ 0.01
Ownership interest in equity method	31.00%
Gain on deconsolidation			$ 1,400,000
Fair value of our retained equity method investment			$ 2,000,000
Antero Midstream Partners LP
Deconsolidation
Number of common units owned	98,870,335
Ownership interest		53.00%

Deconsolidation of Antero Mid_4

Deconsolidation of Antero Midstream Partners LP - Summarized Financial Information of Antero Midstream Partners (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Mar. 12, 2019	Dec. 31, 2018	Sep. 30, 2018
Deconsolidation
Current assets	$ 729,500		$ 806,613
Property and equipment, net	9,914,749		13,869,915
Other noncurrent assets	21,388		47,125
Total assets	16,120,288		15,519,464	$ 15,802,535
Current liabilities	1,171,168		853,540
Long-term debt	3,703,828		5,461,688
Other noncurrent liabilities	59,366		63,098
Total liabilities	$ 8,673,590		$ 7,031,987
Antero Midstream Partners LP
Deconsolidation
Current assets		$ 763,109
Property and equipment, net		3,003,693
Other noncurrent assets		501,208
Total assets		4,268,010
Current liabilities		123,473
Long-term debt		2,359,084
Other noncurrent liabilities		123,523
Total liabilities		2,606,080
Net assets		$ 1,661,930

Revenue (Details)

Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue
Revenues from contracts with customers	$ 896,612	$ 1,019,555	$ 2,980,757	$ 2,865,104
Income from derivatives and other sources	222,269	56,977	475,195	228,874
Total revenue	1,118,881	1,076,532	3,455,952	3,093,978
Natural gas sales
Disaggregation of Revenue
Revenues from contracts with customers	524,448	527,122	1,735,086	1,498,324
Oil sales
Disaggregation of Revenue
Revenues from contracts with customers	40,561	59,722	137,675	128,869
Marketing
Disaggregation of Revenue
Revenues from contracts with customers	46,645	89,598	200,911	394,189
Other income
Disaggregation of Revenue
Revenues from contracts with customers	1,481		3,348
Exploration and production | Natural gas sales
Disaggregation of Revenue
Revenues from contracts with customers	524,448	527,122	1,735,086	1,498,324
Exploration and production | Natural gas liquids sales (ethane)
Disaggregation of Revenue
Revenues from contracts with customers	26,488	56,185	92,378	115,947
Exploration and production | Natural gas liquids sales (C3+ NGLs)
Disaggregation of Revenue
Revenues from contracts with customers	258,470	282,084	810,228	712,477
Exploration and production | Oil sales
Disaggregation of Revenue
Revenues from contracts with customers	40,561	59,722	137,675	128,869
Gathering and compression | Gathering and compression
Disaggregation of Revenue
Revenues from contracts with customers		4,439	3,972	12,848
Water handling and treatment | Water handling and treatment
Disaggregation of Revenue
Revenues from contracts with customers		405	507	2,450
Marketing | Marketing
Disaggregation of Revenue
Revenues from contracts with customers	$ 46,645	$ 89,598	$ 200,911	$ 394,189

Revenue - Transaction Price All

Revenue - Transaction Price Allocation and Contract Balances (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Revenue
Original expected duration	true
Receivables from contracts with customers	$ 281	$ 475

Equity Method Investments (Deta

Equity Method Investments (Details) $ in Thousands	Mar. 12, 2019item	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2019USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)
Investments in unconsolidated affiliates
Balance at beginning of period					$ 433,642
Investments					25,020
Equity in earnings (loss) of unconsolidated affiliates		$ (117,859)	$ 10,705		(90,193)	$ 27,832
Distributions/dividends from unconsolidated affiliates					(109,241)	$ (29,660)
Elimination of intercompany profit					30,621
Effects of deconsolidation					1,529,474
Balance at end of period		1,819,323			1,819,323
Stonewall
Investments in unconsolidated affiliates
Balance at beginning of period					68,103
Equity in earnings (loss) of unconsolidated affiliates					1,894
Distributions/dividends from unconsolidated affiliates					(3,000)
Effects of deconsolidation					(66,997)
Appalachia joint venture | MarkWest
Investments in unconsolidated affiliates
Balance at beginning of period					365,539
Investments					25,020
Equity in earnings (loss) of unconsolidated affiliates					10,370
Distributions/dividends from unconsolidated affiliates					(9,605)
Effects of deconsolidation					(391,324)
Antero Midstream Corporation
Equity Method Investments
Ownership percentage	31.00%
Investments in unconsolidated affiliates
Equity in earnings (loss) of unconsolidated affiliates					(102,457)
Distributions/dividends from unconsolidated affiliates					(96,636)
Elimination of intercompany profit					30,621
Effects of deconsolidation					1,987,795
Balance at end of period		1,819,323			1,819,323
Balance Sheet
Current assets		109,224			109,224
Noncurrent assets		6,336,280			6,336,280
Total assets		6,445,504			6,445,504
Current liabilities		259,628			259,628
Noncurrent liabilities		2,662,846			2,662,846
Stockholders' equity		3,523,030			3,523,030
Total liabilities and equity		$ 6,445,504			$ 6,445,504
Statement of Operations
Revenues				$ 553,521
Operating expenses				745,940
Loss from operations				(192,419)
Net loss attributable to the equity method investments				$ (197,006)
Antero Midstream Corporation | Antero Midstream Corporation
Equity Method Investments
Ownership percentage		31.50%			31.50%
Antero Midstream Partners LP
Equity Method Investments
Number of equity method investments | item	2
Antero Midstream Partners LP | Stonewall
Equity Method Investments
Ownership percentage	15.00%
Antero Midstream Partners LP | Appalachia joint venture
Equity Method Investments
Ownership percentage	50.00%

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Accrued Liabilities
Accrued capital expenditures	$ 83,963	$ 113,237
Accrued gathering, compression, processing, and transportation expenses	141,036	148,032
Accrued marketing expenses	47,763	67,082
Accrued interest expense, net	62,255	43,444
Other accrued liabilities	57,709	93,275
Total accrued liabilities	$ 392,726	$ 465,070

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Thousands	Oct. 26, 2017	Sep. 30, 2019	Dec. 31, 2018	Dec. 21, 2016	Mar. 17, 2015	Sep. 18, 2014	May 06, 2014	Nov. 05, 2013
Long- term Debt
Long-term debt		$ 3,703,828	$ 5,461,688
Credit Facility
Long- term Debt
Current borrowing base		4,500,000
Lender commitments		$ 2,500,000
Time period prior to maturity date of senior notes as one option for maturity date of Credit Facility	91 days	91 days
Outstanding balance		$ 275,000	405,000
Average annualized interest rate		4.39%
Outstanding letters of credit		$ 703,000	685,000
Credit Facility | Minimum | Not Investment Grade Period
Long- term Debt
Basis points added to the reference rate		0.25%
Commitment fees on the unused portion during any period that is not an Investment Grade Period (as a percent)		0.30%
Credit Facility | Minimum | Investment Grade Period
Long- term Debt
Basis points added to the reference rate		0.125%
Commitment fees on the unused portion during an Investment Grade period (as a percent)		0.15%
Credit Facility | Maximum | Not Investment Grade Period
Long- term Debt
Basis points added to the reference rate		2.25%
Commitment fees on the unused portion during any period that is not an Investment Grade Period (as a percent)		0.375%
Credit Facility | Maximum | Investment Grade Period
Long- term Debt
Basis points added to the reference rate		1.75%
Commitment fees on the unused portion during an Investment Grade period (as a percent)		0.30%
5.375% senior notes due 2021
Long- term Debt
Interest rate (as a percent)								5.375%
Senior notes issued								$ 1,000,000
Issue price as percentage of par value								100.00%
Redemption price		101.344%
Redemption price at which notes may be required to be repurchased in event of change of control		101.00%
5.375% senior notes due 2021 | On or after November 1, 2019
Long- term Debt
Redemption price		100.00%
Stand-alone revolving note
Long- term Debt
Maximum amount of the Credit Facility		$ 25,000
Stand-alone revolving note | Other current liabilities
Long- term Debt
Outstanding balance		$ 0	5,400
Stand-alone revolving note | Lender's Prime Rate
Long- term Debt
Basis spread on variable rate (as a percent)		1.00%
5.125 senior notes due 2022
Long- term Debt
Interest rate (as a percent)							5.125%
Senior notes issued						$ 500,000	$ 600,000
Issue price as percentage of par value						100.50%	100.00%
Redemption price		101.281%
Redemption price at which notes may be required to be repurchased in event of change of control		101.00%
5.125 senior notes due 2022 | On or after June 1, 2020
Long- term Debt
Redemption price		100.00%
5.625% senior notes due 2023
Long- term Debt
Interest rate (as a percent)					5.625%
Senior notes issued					$ 750,000
Issue price as percentage of par value					100.00%
Redemption price		102.813%
Redemption price at which notes may be required to be repurchased in event of change of control		101.00%
5.625% senior notes due 2023 | On Or After June 1, 2021
Long- term Debt
Redemption price		100.00%
5.375% senior notes due 2024
Long- term Debt
Interest rate (as a percent)		5.375%
5.00% senior notes due 2025
Long- term Debt
Long-term notes payable				$ 600,000
Interest rate (as a percent)				5.00%
Issue price as percentage of par value				100.00%
Redemption price at which notes may be required to be repurchased in event of change of control		101.00%
5.00% senior notes due 2025 | Prior to March 1, 2020
Long- term Debt
Redemption price		100.00%
5.00% senior notes due 2025 | On or before March 1, 2020
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)		105.00%
5.00% senior notes due 2025 | On or after March 1, 2020
Long- term Debt
Redemption price		103.75%
5.00% senior notes due 2025 | On or after March1, 2023
Long- term Debt
Redemption price		100.00%
Reportable legal entity
Long- term Debt
Long-term debt		$ 3,703,828	3,829,541
Reportable legal entity | Parent (Antero)
Long- term Debt
Net unamortized premium		1,021	1,241
Net unamortized debt issuance costs		(22,193)	(26,700)
Long-term debt		3,703,828	3,829,541
Reportable legal entity | Credit Facility | Parent (Antero)
Long- term Debt
Bank credit facility long-term debt		275,000	405,000
Reportable legal entity | 5.375% senior notes due 2021 | Parent (Antero)
Long- term Debt
Long-term notes payable		1,000,000	1,000,000
Reportable legal entity | 5.125 senior notes due 2022 | Parent (Antero)
Long- term Debt
Long-term notes payable		1,100,000	1,100,000
Reportable legal entity | 5.625% senior notes due 2023 | Parent (Antero)
Long- term Debt
Long-term notes payable		750,000	750,000
Reportable legal entity | 5.00% senior notes due 2025 | Parent (Antero)
Long- term Debt
Long-term notes payable		$ 600,000	600,000
Antero Midstream Partners LP
Long- term Debt
Net unamortized debt issuance costs			(7,853)
Long-term debt			1,632,147
Antero Midstream Partners LP | Midstream Credit Facility
Long- term Debt
Bank credit facility long-term debt			990,000
Antero Midstream Partners LP | 5.375% senior notes due 2024
Long- term Debt
Long-term notes payable			$ 650,000

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Asset Retirement Obligations
Asset retirement obligations - beginning of period			$ 58,979
Obligations settled			(153)
Obligations incurred			1,361
Accretion expense	$ 927	$ 710	2,821	$ 2,101
Effect of deconsolidation of Antero Midstream Partners LP			(7,518)
Asset retirement obligations - end of period	$ 55,490		$ 55,490

Equity-Based Compensation (Deta

Equity-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Stock-based compensation expense
Number of stock-based compensation awards authorized	16,906,500		16,906,500
Common stock, par value (in dollars per share)	$ 0.01		$ 0.01		$ 0.01
Number of shares available for future grant under the Plan	6,046,007		6,046,007
Equity based compensation expense recognized	$ 3,875	$ 16,202	$ 19,327	$ 56,429
Midstream Plan
Stock-based compensation expense
Number of stock-based compensation awards authorized	10,000,000		10,000,000
Restricted stock awards
Stock-based compensation expense
Equity based compensation expense recognized	$ 2,229	10,001	$ 8,829	33,676
Stock options
Stock-based compensation expense
Equity based compensation expense recognized		452	389	1,428
Performance share unit awards
Stock-based compensation expense
Equity based compensation expense recognized	399	1,017	6,027	7,018
Antero Midstream Partners Phantom Unit Awards
Stock-based compensation expense
Equity based compensation expense recognized	867	4,193	2,942	12,752
Equity awards issued to directors
Stock-based compensation expense
Equity based compensation expense recognized	$ 380	$ 539	$ 1,140	$ 1,555
Antero Midstream Corporation | Midstream Plan
Stock-based compensation expense
Conversion rate of units converted into restricted stock			1.8926
Common stock, par value (in dollars per share)	$ 0.01		$ 0.01

Equity-Based Compensation - Res

Equity-Based Compensation - Restricted Stock and RSU Awards (Details) - Restricted stock and restricted stock unit $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)$ / sharesshares
Number of shares
Total awarded and unvested at the beginning of the period (in shares) | shares	1,712,485
Granted (in shares) | shares	1,610,690
Vested (in shares) | shares	(718,192)
Forfeited (in shares) | shares	(307,938)
Total awarded and unvested at the end of the period (in shares) | shares	2,297,045
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares	$ 24.57
Granted (in dollars per share) | $ / shares	8.60
Vested (in dollars per share) | $ / shares	27.70
Forfeited (in dollars per share) | $ / shares	16.56
Total awarded and unvested at the end of the period (in dollars per share) | $ / shares	$ 13.47
Additional equity compensation to be recognized over the remaining period | $	$ 25
Weighted average period for recognizing unrecognized stock-based compensation expense	2 years 7 months 6 days

Equity-Based Compensation - Sto

Equity-Based Compensation - Stock Options (Details) - Stock options - USD ($) $ / shares in Units, $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Stock options
Outstanding at the beginning of the period (in shares)	579,617
Options forfeited (in shares)	(79,484)
Outstanding at the end of the period (in shares)	500,133	579,617
Vested or expected to vest (in shares)	500,133
Exercisable (in shares)	500,133
Weighted average exercise price
Outstanding at the beginning of the period (in dollars per share)	$ 50.55
Options forfeited (in dollars per share)	50.25
Outstanding at the end of the period (in dollars per share)	50.60	$ 50.55
Vested or expected to vest (in dollars per share)	50.60
Exercisable (in dollars per share)	$ 50.60
Weighted average remaining contractual life
Outstanding	4 years 11 months 23 days	5 years 9 months 21 days
Vested or expected to vest	4 years 11 months 23 days
Exercisable	4 years 11 months 23 days
Additional disclosures
Additional equity compensation to be recognized over the remaining period	$ 0
Maximum
Stock-based compensation
Contractual life	10 years

Equity-Based Compensation - PSU

Equity-Based Compensation - PSU awards (Details) - USD ($) $ / shares in Units, $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Performance share unit awards
Number of units
Total awarded and unvested at the beginning of the period (in shares)	1,767,299
Granted (in shares)	1,416,378
Vested (in shares)	(31,944)
Forfeited (in shares)	(614,450)
Total awarded and unvested at the end of the period (in shares)	2,537,283		1,767,299
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share)	$ 26.36
Granted (in dollars per share)	9.26	$ 24.85
Vested (in dollars per share)	27.38
Forfeited (in dollars per share)	26.61
Total awarded and unvested at the end of the period (in dollars per share)	$ 16.74		$ 26.36
Additional disclosures
Additional equity compensation to be recognized over the remaining period	$ 20
Weighted average period for recognizing unrecognized stock-based compensation expense	1 year 10 months 24 days
Weighted-average assumptions used to calculate fair value of performance share units granted
Volatility (as a percent)	36.00%	41.00%
Risk-free interest rate (as a percent)	2.35%	2.49%
Weighted average fair value of awards granted (in dollars per share)	$ 9.26	$ 24.85
Price target and TSR performance share unit awards
Amortization period of PSU expense			3 years
Price target and TSR performance share unit awards | Minimum
Number of PSUs that may be earned as compared to the number of PSUs granted, as a percent			0.00%
Price target and TSR performance share unit awards | Maximum
Number of PSUs that may be earned as compared to the number of PSUs granted, as a percent			200.00%
Price target performance share unit awards
Number of successive days closing stock price must achieve specific thresholds for PSUs to vest per schedule	10 days
Vesting period	3 years
Price target performance share unit awards | Vesting before first anniversary | Maximum
Number of PSUs that may vest, as a percent	0.00%
Price target performance share unit awards | Vesting before the second anniversary | Maximum
Number of PSUs that may vest, as a percent	33.33%
Price target performance share unit awards | Vesting before the third anniversary | Maximum
Number of PSUs that may vest, as a percent	66.67%
TSR performance share unit awards
Price target as a percentage of beginning price	125.00%
Vesting period	3 years
Amortization period of PSU expense	3 years
TSR performance share unit awards | Minimum
Number of PSUs that may be earned as compared to the number of PSUs granted, as a percent	0.00%
TSR performance share unit awards | Maximum
Number of PSUs that may be earned as compared to the number of PSUs granted, as a percent	200.00%
ROCE performance share unit awards
Vesting period	3 years
Amortization period of PSU expense	3 years
ROCE performance share unit awards | Minimum
Number of PSUs that may vest, as a percent	0.00%
ROCE performance share unit awards | Maximum
Price target as a percentage of beginning price	125.00%
Number of PSUs that may vest, as a percent	200.00%

Equity-Based Compensation - Pha

Equity-Based Compensation - Phantom Unit Awards (Details) - USD ($) $ / shares in Units, $ in Thousands	2 Months Ended	4 Months Ended	9 Months Ended
	Mar. 12, 2019	Jun. 30, 2019	Sep. 30, 2019
Antero Midstream Partners Phantom Unit Awards
Number of units
Total awarded and unvested at the beginning of the period (in shares)	583,000	564,781	583,000
Granted (in shares)	5,972
Effect of conversion		504,119
Vested (in shares)	(3,853)	(358,831)
Forfeited (in shares)	(20,338)	(45,803)
Total awarded and unvested at the end of the period (in shares)	564,781	664,266
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share)	$ 27.63	$ 27.59	$ 27.63
Granted (in dollars per share)	23.44
Effect of conversion (in dollars per share)		14.58
Vested (in dollars per share)	32.44	14.34
Forfeited (in dollars per share)	26.73	14.58
Total awarded and unvested at the end of the period (in dollars per share)	$ 27.59	$ 14.70
Aggregate intrinsic value
Outstanding at the beginning of the period	$ 12,470	$ 13,476	$ 12,470
Outstanding at the end of the period	$ 13,476	$ 4,916
Additional equity compensation to be recognized over the remaining period			$ 7,600
Weighted average period for recognizing unrecognized stock-based compensation expense			1 year 10 months 24 days
Restricted stock and restricted stock unit
Number of units
Total awarded and unvested at the beginning of the period (in shares)	1,712,485		1,712,485
Granted (in shares)			1,610,690
Vested (in shares)			(718,192)
Forfeited (in shares)			(307,938)
Total awarded and unvested at the end of the period (in shares)			2,297,045
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share)	$ 24.57		$ 24.57
Granted (in dollars per share)			8.60
Vested (in dollars per share)			27.70
Forfeited (in dollars per share)			16.56
Total awarded and unvested at the end of the period (in dollars per share)			$ 13.47
Aggregate intrinsic value
Outstanding at the beginning of the period	$ 16,080		$ 16,080
Outstanding at the end of the period			6,937
Additional equity compensation to be recognized over the remaining period			$ 25,000
Weighted average period for recognizing unrecognized stock-based compensation expense			2 years 7 months 6 days
Antero Midstream Corporation | Midstream Plan
Aggregate intrinsic value
Conversion rate of units converted into restricted stock			1.8926

Financial Instruments (Details)

Financial Instruments (Details) - USD ($) $ in Billions	Sep. 30, 2019	Dec. 31, 2018
Recurring | Level 2 market data
Financial Instruments
Fair value of senior notes	$ 3.1	$ 3.9

Derivative Instruments - Commod

Derivative Instruments - Commodity derivatives (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2019MMBTU / d$ / MMBTUbblgal	Sep. 30, 2019$ / gal	Sep. 30, 2019$ / MMBTU	Sep. 30, 2019$ / bbl	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Derivatives not designated as hedges for accounting purposes | NYMEX | Three months ending December 31, 2019
Derivative Instruments
Ceiling | MMBTU / d	1,575,000
Floor | $ / MMBTU	1,333,234
Weighted average index price ceiling price | $ / MMBTU			3.52
Weighted average index price floor price | $ / MMBTU			2.50
Commodity derivative
Derivative Instruments
Gross amounts on balance sheet | $					$ 838,795	$ 658,830
Commodity derivative | Derivatives not designated as hedges for accounting purposes
Derivative Instruments
Gross amounts on balance sheet | $					13,000
Unamortized portion of premium | $					$ 4,500
Swaps | NYMEX | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price | $ / MMBTU			3.23
Swaps | NYMEX | Year ending December 31, 2020
Derivative Instruments
Weighted average index price | $ / MMBTU			2.87
Swaps | NYMEX | Year Ending December 31, 2021
Derivative Instruments
Weighted average index price | $ / MMBTU			2.79
Swaps | NYMEX | Year ending December 31, 2022
Derivative Instruments
Weighted average index price | $ / MMBTU			2.96
Swaps | NYMEX | Year ending December 31, 2023
Derivative Instruments
Weighted average index price | $ / MMBTU			2.91
Swaps | ARA Propane | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price		0.81		0.68
Swaps | ARA Propane | Year ending December 31, 2020
Derivative Instruments
Weighted average index price		0.81		0.65
Swaps | FEI Propane | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price | $ / gal		0.50
Swaps | FEI Propane | Year ending December 31, 2020
Derivative Instruments
Weighted average index price | $ / gal		0.57
Swaps | Mont Belvieu Propane Non-TET | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price | $ / gal		0.59
Swaps | Mont Belvieu Butane Non-TET | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price | $ / gal		1.14
Swaps | NYMEX-WTI | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price | $ / gal		59.05
Swaps | NYMEX-WTI | Year ending December 31, 2020
Derivative Instruments
Weighted average index price | $ / gal		56.60
Swaps | Natural gas | Three months ending December 31, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	996,766
Swaps | Natural gas | Year ending December 31, 2020
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	2,227,500
Swaps | Natural gas | NYMEX | Three months ending December 31, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	996,766
Swaps | Natural gas | NYMEX | Year ending December 31, 2020
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	2,227,500
Swaps | Natural gas | NYMEX | Year Ending December 31, 2021
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	2,110,000
Swaps | Natural gas | NYMEX | Year ending December 31, 2022
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	290,000
Swaps | Natural gas | NYMEX | Year ending December 31, 2023
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	90,000
Swaps | Natural gas liquids | Three months ending December 31, 2019
Derivative Instruments
Notional amount	35,422
Swaps | Natural gas liquids | Year ending December 31, 2020
Derivative Instruments
Notional amount	13,806
Swaps | Natural gas liquids | ARA Propane | Three months ending December 31, 2019
Derivative Instruments
Notional amount	10,113
Swaps | Natural gas liquids | ARA Propane | Year ending December 31, 2020
Derivative Instruments
Notional amount	9,761
Swaps | Natural gas liquids | FEI Propane | Three months ending December 31, 2019
Derivative Instruments
Notional amount	9,809
Swaps | Natural gas liquids | FEI Propane | Year ending December 31, 2020
Derivative Instruments
Notional amount	2,045
Swaps | Natural gas liquids | Mont Belvieu Propane Non-TET | Three months ending December 31, 2019
Derivative Instruments
Notional amount	8,000
Swaps | Natural gas liquids | Mont Belvieu Butane Non-TET | Three months ending December 31, 2019
Derivative Instruments
Notional amount	4,000
Swaps | Natural gas liquids | Mont Belvieu Butane Non-TET | Year ending December 31, 2020
Derivative Instruments
Notional amount	2,000
Swaps | Natural gas liquids | Mont Belvieu Natural Gasoline Non-TET | Three months ending December 31, 2019
Derivative Instruments
Notional amount	3,500
Swaps | Oil | Three months ending December 31, 2019
Derivative Instruments
Notional amount | gal	18,000
Swaps | Oil | Year ending December 31, 2020
Derivative Instruments
Notional amount | gal	12,000
Swaps | Oil | NYMEX-WTI | Three months ending December 31, 2019
Derivative Instruments
Notional amount | gal	18,000
Swaps | Oil | NYMEX-WTI | Year ending December 31, 2020
Derivative Instruments
Notional amount | gal	12,000

Derivative Instruments (Details

Derivative Instruments (Details) - 9 months ended Sep. 30, 2019 - Swaps	MMBTU / dbblgal	$ / gal	$ / MMBTU
ARA to Mont Belvieu Non-TET | Three months ending December 31, 2019 | Hedged differential
Derivative [Line Items]
Weighted average hedged differential | $ / gal		0.25
ARA to Mont Belvieu Non-TET | Year ending December 31, 2020 | Hedged differential
Derivative [Line Items]
Weighted average hedged differential		0.23	0.353
NYMEX to TCO | Year Ending December 31, 2021 | Hedged differential
Derivative [Line Items]
Weighted average hedged differential | $ / MMBTU			0.414
NYMEX to TCO | Year ending December 31, 2022 | Hedged differential
Derivative [Line Items]
Weighted average hedged differential | $ / MMBTU			0.515
NYMEX to TCO | Year ending December 31, 2023 | Hedged differential
Derivative [Line Items]
Weighted average hedged differential | $ / MMBTU			0.525
NYMEX to TCO | Year ending December 31, 2024 | Hedged differential
Derivative [Line Items]
Weighted average hedged differential | $ / MMBTU			0.530
Mont Belvieu Propane to NYMEX-WTI | Three months ending December 31, 2019
Derivative [Line Items]
Weighted average payout ratio	50
Mont Belvieu Propane to NYMEX-WTI | Year ending December 31, 2020
Derivative [Line Items]
Weighted average payout ratio	50
Mont Belvieu Natural Gasoline to NYMEX-WTI | Three months ending December 31, 2019
Derivative [Line Items]
Weighted average payout ratio	81
Mont Belvieu Natural Gasoline to NYMEX-WTI | Year ending December 31, 2020
Derivative [Line Items]
Weighted average payout ratio	79
Mont Belvieu Natural Gasoline to NYMEX-WTI | Year Ending December 31, 2021
Derivative [Line Items]
Weighted average payout ratio	78
Natural gas | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	996,766
Natural gas | Year ending December 31, 2020
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	2,227,500
Natural gas | NYMEX to TCO | Year ending December 31, 2020
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	60,000
Natural gas | NYMEX to TCO | Year Ending December 31, 2021
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	40,000
Natural gas | NYMEX to TCO | Year ending December 31, 2022
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	60,000
Natural gas | NYMEX to TCO | Year ending December 31, 2023
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	50,000
Natural gas | NYMEX to TCO | Year ending December 31, 2024
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	50,000
Oil | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount | gal	18,000
Oil | Year ending December 31, 2020
Derivative [Line Items]
Notional amount | gal	12,000
Natural gas liquids | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount	35,422
Natural gas liquids | Year ending December 31, 2020
Derivative [Line Items]
Notional amount	13,806
Natural gas liquids | ARA to Mont Belvieu Non-TET | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount	4,050
Natural gas liquids | ARA to Mont Belvieu Non-TET | Year ending December 31, 2020
Derivative [Line Items]
Notional amount	4,273
Natural gas liquids | Mont Belvieu Index Price to WTI | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount	14,400
Natural gas liquids | Mont Belvieu Index Price to WTI | Year ending December 31, 2020
Derivative [Line Items]
Notional amount	15,500
Natural gas liquids | Mont Belvieu Propane to NYMEX-WTI | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount	500
Natural gas liquids | Mont Belvieu Propane to NYMEX-WTI | Year ending December 31, 2020
Derivative [Line Items]
Notional amount	500
Natural gas liquids | Mont Belvieu Natural Gasoline to NYMEX-WTI | Three months ending December 31, 2019
Derivative [Line Items]
Notional amount	13,900
Natural gas liquids | Mont Belvieu Natural Gasoline to NYMEX-WTI | Year ending December 31, 2020
Derivative [Line Items]
Notional amount	15,000
Natural gas liquids | Mont Belvieu Natural Gasoline to NYMEX-WTI | Year Ending December 31, 2021
Derivative [Line Items]
Notional amount	13,000

Derivative Instruments - Fair v

Derivative Instruments - Fair value (Details) $ in Thousands	Sep. 30, 2019USD ($)item	Dec. 31, 2018USD ($)item
Fair value of derivative instruments
Current portion of fair value of derivative assets	$ 411,774	$ 245,263
Noncurrent portion of fair value of derivative assets	405,180	362,169
Current portion of fair value of derivative liabilities		532
Commodity derivative
Fair value of derivative instruments
Total asset derivatives	816,954	607,432
Total liability derivatives		532
Derivatives not designated as hedges for accounting purposes
Fair value of derivative instruments
Total asset derivatives	816,954	607,432
Total liability derivatives		532
Net derivatives	816,954	606,900
Derivatives not designated as hedges for accounting purposes | Commodity derivative
Fair value of derivative instruments
Current portion of fair value of derivative assets	411,774	245,263
Noncurrent portion of fair value of derivative assets	$ 405,180	362,169
Current portion of fair value of derivative liabilities		$ 532
Derivatives designated as hedges for accounting purposes
Fair value of derivative instruments
Number of derivative instruments held designated as hedges | item	0	0

Derivative Instruments - Assets

Derivative Instruments - Assets and liabilities (Details) - Commodity derivative - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Commodity derivative assets
Gross amounts on balance sheet	$ 838,795	$ 658,830
Gross amounts offset on balance sheet	(21,841)	(51,398)
Total asset derivatives	816,954	607,432
Commodity derivative liabilities
Gross amounts on balance sheet	(21,841)	(51,930)
Gross amounts offset on balance sheet	$ 21,841	51,398
Total liability derivatives		$ (532)

Derivative Instruments - Fair_2

Derivative Instruments - Fair value gains (losses) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Summary of realized and unrealized gains (losses) on derivative instruments
Commodity derivative fair value gains	$ 220,788	$ 57,019	$ 471,847	$ 134,793
Marketing derivative fair value gains (losses)	0	(42)	0	94,081
Revenue
Summary of realized and unrealized gains (losses) on derivative instruments
Commodity derivative fair value gains	$ 220,788	57,019	$ 471,847	134,793
Marketing derivative fair value gains (losses)		(42)		$ 94,081
Maximum
Summary of realized and unrealized gains (losses) on derivative instruments
Marketing derivative fair value gains (losses)		$ 1,000

Leases (Details)

Leases (Details)	9 Months Ended
	Sep. 30, 2019
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) $ in Thousands	Sep. 30, 2019USD ($)
Lease Assets
Operating leases right-of-use assets	$ 3,230,148
Finance leases, right of use assets	3,039
Finance leases, accumulated amortization	9,000
Short-term lease liabilities, operating leases	408,814
Long-term lease liabilities, operating leases	2,821,334
Total lease liabilities, operating leases	3,230,148
Short-term lease liabilities, finance leases	1,176
Long-term lease liabilities, finance leases	1,863
Total	3,039
Vehicles
Lease Assets
Operating leases right-of-use assets	4,971
Finance leases, right of use assets	2,591
Other office and field equipment
Lease Assets
Operating leases right-of-use assets	299
Finance leases, right of use assets	448
Processing plants
Lease Assets
Operating leases right-of-use assets	1,554,601
Drilling and completion rigs
Lease Assets
Operating leases right-of-use assets	93,846
Gas gathering lines and compressor stations
Lease Assets
Operating leases right-of-use assets	1,535,146
Gas gathering lines and compressor stations | Antero Midstream Corporation
Lease Assets
Finance leases, accumulated amortization	1,300,000
Office space
Lease Assets
Operating leases right-of-use assets	$ 41,285

Leases - Supplemental Informati

Leases - Supplemental Information Related to Leases (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Leases
Total Lease Expense	$ 240,477	$ 663,094
Capitalized operating leases	53,000	161,000
Short-term lease costs		115,000
Cash paid for amounts included in the measurement of lease liabilities: Operating cash out flows related to operating leases	234,399	591,963
Cash paid for amounts included in the measurement of lease liabilities: Investing cash out flows related to operating leases	47,417	146,315
Cash paid for amounts included in the measurement of lease liabilities for operating leases	281,816	738,278
Cash paid for amounts included in the measurement of lease liabilities: Financing cash out flows related to financing leases	303	1,967
Cash paid for amounts included in the measurement of lease liabilities for finance leases	303	1,967
Leased assets obtained in exchange for new operating lease liabilities		3,345,549
Gathering, compression, water handling and treatment
Leases
Total Lease Expense	237,618	644,007
General and administrative
Leases
Total Lease Expense	2,859	8,395
Contract termination and rig stacking
Leases
Total Lease Expense		10,692
Maximum
Leases
Finance leases, interest expense	1,000	1,000
Capitalized finance leases	$ 1,000	$ 1,000

Leases - Maturities of Lease Li

Leases - Maturities of Lease Liabilities (Details) $ in Thousands	Sep. 30, 2019USD ($)
Future minimum payments for operating lease liabilities
Remainder of 2019	$ 151,345
2020	578,615
2021	506,402
2022	495,694
2023	491,513
2024	482,745
Thereafter	1,447,537
Total lease payments	4,153,851
Less: imputed interest	(923,703)
Total lease liabilities, operating leases	3,230,148
Future minimum payments for financing lease liabilities
Remainder of 2019	21
2020	523
2021	1,152
2022	1,298
2023	45
Total lease payments	3,039
Total	3,039
Future minimum payments for total lease liabilities
Remainder of 2019	151,366
2020	579,138
2021	507,554
2022	496,992
2023	491,558
2024	482,745
Thereafter	1,447,537
Total lease payments	4,156,890
Less: imputed interest	(923,703)
Total	$ 3,233,187

Leases - Office and equipment l

Leases - Office and equipment leases (Details) $ in Thousands	Dec. 31, 2018USD ($)
Office and Equipment Leases
Office and equipment leases:
2019	$ 14,672
2020	12,988
2021	10,860
2022	8,701
2023	7,495
Thereafter	49,367
Total	104,083
Office Leases
Office and equipment leases:
2019	8,630
2020	8,471
2021	8,450
2022	8,427
2023	7,495
Thereafter	49,367
Total	90,840
Equipment Leases
Office and equipment leases:
2019	6,042
2020	4,517
2021	2,410
2022	274
Total	$ 13,243

Leases - Lease Term and Discoun

Leases - Lease Term and Discount Rate (Details)	Sep. 30, 2019
Leases
Weighted-average remaining lease term: Operating lease	8 years 4 months 24 days
Weighted-average discount rate: Operating lease	6.10%
Weighted-average remaining lease term: Finance lease	2 years 1 month 6 days
Weighted-average discount rate: Finance lease	5.70%

Leases - Related party disclosu

Leases - Related party disclosure (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)
Leases
Amount included within accounts payable, related parties	$ 100,437	$ 100,437
Antero Midstream Corporation
Leases
Utilizing capacity (as a percent)		75.00%
Payment of capacity (as a percent)		70.00%
Term of lease	10 years	10 years
Gathering and compression fees paid	$ 171,000	$ 486,000
Amount included within accounts payable, related parties	$ 60,000	$ 60,000

Commitments (Details)

Commitments (Details) $ in Thousands	Sep. 30, 2019USD ($)
Future minimum payments
Remainder of 2019	$ 452,257
2020	1,762,902
2021	1,664,903
2022	1,598,019
2023	1,584,764
2024	1,535,966
Thereafter	9,416,654
Total	18,015,465
Firm transportation
Future minimum payments
Remainder of 2019	282,571
2020	1,123,782
2021	1,100,079
2022	1,047,162
2023	1,034,641
2024	994,534
Thereafter	7,816,594
Total	13,399,363
Gas processing, gathering and compression
Future minimum payments
Remainder of 2019	13,667
2020	54,425
2021	54,093
2022	53,606
2023	58,565
2024	58,687
Thereafter	152,523
Total	445,566
Land payment obligations
Future minimum payments
Remainder of 2019	4,653
2020	5,557
2021	3,177
2022	259
Total	13,646
Operating and Financing Leases
Future minimum payments
Remainder of 2019	102,808
2020	399,881
2021	350,364
2022	361,057
2023	377,836
2024	392,323
Thereafter	1,248,918
Total	3,233,187
Imputed Interest for Leases
Future minimum payments
Remainder of 2019	48,558
2020	179,257
2021	157,190
2022	135,935
2023	113,722
2024	90,422
Thereafter	198,619
Total	$ 923,703

Contingencies (Details)

Contingencies (Details)	Jun. 20, 2019USD ($)	Feb. 01, 2018MMBTU / d	Jan. 01, 2018MMBTU / d	Oct. 29, 2019USD ($)	Jul. 31, 2017MMBTU / d	Jan. 31, 2018MMBTU / d	Sep. 30, 2019USD ($)contract	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Oct. 29, 2019USD ($)	Nov. 30, 2017MMBTU / d	Sep. 30, 2019USD ($)MMBTU / dcontract	Sep. 30, 2018USD ($)	Dec. 31, 2018USD ($)	Nov. 30, 2018MMBTU / d	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Contingencies
Revenues from contracts with customers							$ 896,612,000	$ 1,019,555,000				$ 2,980,757,000	$ 2,865,104,000
Production and ad valorem taxes							28,863,000	30,518,000				95,509,000	82,232,000
Interest							(47,754,000)	(74,528,000)				(173,868,000)	(208,303,000)
Accrued revenue							281,177,000					281,177,000		$ 474,827,000
Accounts receivable							29,207,000					29,207,000		$ 51,073,000
Natural gas sales
Contingencies
Revenues from contracts with customers							524,448,000	$ 527,122,000				$ 1,735,086,000	$ 1,498,324,000
Doddridge County, Tyler County and Ritchie County, West Virginia | Minimum
Contingencies
Settlement amount									$ 100,000
SJGC
Contingencies
Natural gas long term purchase contract volume (in MMBtu)/day | MMBTU / d												80,000
SJGC | Settled Litigation
Contingencies
Settlement amount received				$ 23,000,000			59,000,000			$ 82,000,000
Production and ad valorem taxes							3,000,000					$ 3,000,000
Interest							8,000,000					8,000,000
Accrued revenue							23,000,000					23,000,000
SJGC | Settled Litigation | Natural gas sales
Contingencies
Revenues from contracts with customers							$ 54,000,000					$ 54,000,000
WGL
Contingencies
Natural gas long term purchase contract volume increase after specified events (in MMBtu)/day | MMBTU / d															530,000
Damages awarded	$ 96,000,000
WGL | Pending Litigation
Contingencies
Damages sought																$ 40,000,000
WGL | Pending Litigation | Minimum
Contingencies
Damages sought																	$ 30,000,000
WGL - Braxton, West Virginia
Contingencies
Natural gas long term purchase contract volume (in MMBtu)/day | MMBTU / d		200,000	500,000
WGL - Loudoun County, Virginia
Contingencies
Natural gas long term purchase contract volume increase after specified events (in MMBtu)/day | MMBTU / d															330,000
Potential Positive Outcome of Litigation | SJGC
Contingencies
Number of long term gas contracts | contract							2					2
Potential Positive Outcome of Litigation | WGL
Contingencies
Natural gas long term purchase contract volume (in MMBtu)/day | MMBTU / d					500,000	500,000					600,000

Contract Termination and Rig _2

Contract Termination and Rig Stacking (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Costs for delay or cancelation of drilling and completion contracts with third-party contractors	$ 62	$ 14,026
Maximum
Costs for delay or cancelation of drilling and completion contracts with third-party contractors	$ 1,000	$ 14,000

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Sales and revenues:
Sales and revenues	$ 1,117,400	$ 1,076,532	$ 3,448,175	$ 3,093,978
Sales and revenues	1,118,881	1,076,532	3,455,952	3,093,978
Operating expenses:
Impairment of oil and gas properties	1,041,469	221,094	1,253,712	406,068
Impairment of midstream assets	7,800	1,157	14,782	9,658
Depletion, depreciation, and amortization	241,503	243,186	724,006	709,480
General and administrative	35,923	59,860	146,507	181,576
Other operating expenses	138,276	183,658	522,794	649,279
Total operating expenses	2,104,759	1,071,728	4,375,541	2,975,444
Operating income (loss)	(985,878)	4,804	(919,589)	118,534
Equity in earnings (loss) of unconsolidated affiliates	(117,859)	10,705	(90,193)	27,832
Investments in unconsolidated affiliates	1,819,323		1,819,323		$ 433,642
Segment assets	16,120,288	15,802,535	16,120,288	15,802,535	$ 15,519,464
Capital expenditures for segment assets	292,176	567,221	1,106,362	1,676,245
Marketing
Sales and revenues:
Sales and revenues			200,911
Operating expenses:
Other operating expenses			408,839
Total operating expenses			408,839
Operating income (loss)			(207,928)
Segment assets	25,361		25,361
Antero Midstream Corporation
Sales and revenues:
Sales and revenues			50
Operating expenses:
Impairment of midstream assets			472,854
Depletion, depreciation, and amortization			68,557
General and administrative			85,026
Other operating expenses			8,005
Total operating expenses			774,193
Operating income (loss)			(220,672)
Equity in earnings (loss) of unconsolidated affiliates			34,981
Investments in unconsolidated affiliates	672,310		672,310
Segment assets	6,445,504		6,445,504
Capital expenditures for segment assets			262,065
Operating segments
Sales and revenues:
Sales and revenues				3,093,978
Operating segments | Exploration and production
Sales and revenues:
Sales and revenues	1,070,755	982,131	3,247,214	2,590,409
Sales and revenues	1,072,236	987,328	3,252,213	2,606,660
Operating expenses:
Impairment of oil and gas properties	1,041,469	221,094	1,253,712	406,068
Depletion, depreciation, and amortization	241,503	204,465	702,299	601,446
General and administrative	35,923	45,474	128,213	138,555
Other operating expenses	30,060	30,695	112,952	85,067
Total operating expenses	1,988,743	979,454	4,022,639	2,566,489
Operating income (loss)	(916,507)	7,874	(770,426)	40,171
Equity in earnings (loss) of unconsolidated affiliates	(117,859)		(102,457)
Investments in unconsolidated affiliates	1,819,323		1,819,323
Segment assets	16,094,927	13,484,457	16,094,927	13,484,457
Capital expenditures for segment assets	292,176	485,219	1,053,210	1,464,041
Operating segments | Marketing
Sales and revenues:
Sales and revenues	46,645	89,556		488,270
Sales and revenues	46,645	89,556	200,911	488,270
Operating expenses:
Other operating expenses	108,216	151,764		560,924
Total operating expenses	108,216	151,764		560,924
Operating income (loss)	(61,571)	(62,208)		(72,654)
Segment assets	25,361	20,481	25,361	20,481
Operating segments | Antero Midstream Corporation
Sales and revenues:
Sales and revenues		4,845		15,299
Sales and revenues	243,795	266,205	553,521	746,772
Operating expenses:
Impairment of midstream assets	465,278	1,157		9,658
Depletion, depreciation, and amortization	24,460	38,721		108,034
General and administrative	30,595	15,018		44,967
Other operating expenses	3,210	5,219		15,129
Total operating expenses	585,684	140,424		398,955
Operating income (loss)	(341,889)	125,781		347,817
Equity in earnings (loss) of unconsolidated affiliates	18,478	10,705		27,832
Investments in unconsolidated affiliates	672,310		672,310
Segment assets	6,445,504	3,411,496	6,445,504	3,411,496
Capital expenditures for segment assets	120,875	149,953		414,833
Elimination of intersegment transaction
Sales and revenues:
Sales and revenues	1,481	(266,557)	7,777	(747,724)
Sales and revenues	(243,795)	(266,557)	(550,693)	(747,724)
Operating expenses:
Impairment of midstream assets	(457,478)		(458,072)
Depletion, depreciation, and amortization	(24,460)		(46,850)
General and administrative	(30,595)	(632)	(66,732)	(1,946)
Other operating expenses	(3,210)	(4,020)	(7,002)	(11,841)
Total operating expenses	(577,884)	(199,914)	(830,130)	(550,924)
Operating income (loss)	334,089	(66,643)	279,437	(196,800)
Equity in earnings (loss) of unconsolidated affiliates	(18,478)		(22,717)
Investments in unconsolidated affiliates	(672,310)		(672,310)
Segment assets	(6,445,504)	(1,113,899)	(6,445,504)	(1,113,899)
Capital expenditures for segment assets	(120,875)	(67,951)	(208,913)	(202,629)
Elimination of intersegment transaction | Exploration and production
Sales and revenues:
Sales and revenues	1,481	5,197	4,999	16,251
Elimination of intersegment transaction | Antero Midstream Corporation
Sales and revenues:
Sales and revenues	243,795	261,360	553,471	731,473
Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	603,860	326,504	1,595,223	926,228
Gathering, compression, water handling and treatment | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold			28,324
Gathering, compression, water handling and treatment | Operating segments | Exploration and production
Operating expenses:
Cost of goods and services sold	603,860	442,602	1,705,709	1,236,655
Gathering, compression, water handling and treatment | Operating segments | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold	13,091	12,701		36,469
Gathering, compression, water handling and treatment | Elimination of intersegment transaction
Operating expenses:
Cost of goods and services sold	(13,091)	(128,799)	(138,810)	(346,896)
Lease operating
Operating expenses:
Cost of goods and services sold	35,928	36,269	118,517	93,155
Lease operating | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold			111,427
Lease operating | Operating segments | Exploration and production
Operating expenses:
Cost of goods and services sold	35,928	35,124	119,754	98,698
Lease operating | Operating segments | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold	49,050	67,608		184,698
Lease operating | Elimination of intersegment transaction
Operating expenses:
Cost of goods and services sold	$ (49,050)	$ (66,463)	$ (112,664)	$ (190,241)

Subsidiary Guarantors - Balance

Subsidiary Guarantors - Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Accounts receivable, net	$ 29,207			$ 51,073
Accrued revenue	281,177			474,827
Derivative instruments	411,774			245,263
Other current assets	7,342			35,450
Total current assets	729,500			806,613
Unproved properties	1,406,464			1,767,600
Proved properties	11,568,285			12,705,672
Water handling and treatment systems				1,013,818
Gathering systems and facilities	5,802			2,470,708
Other property and equipment	70,965			65,842
Property and equipment, gross	13,051,516			18,023,640
Less accumulated depletion, depreciation, and amortization	(3,136,767)			(4,153,725)
Property and equipment, net	9,914,749			13,869,915
Operating leases right-of-use assets	3,230,148
Derivative instruments	405,180			362,169
Investment in consolidated affiliates	1,819,323			433,642
Investments in unconsolidated affiliates	1,819,323			433,642
Other assets	21,388			47,125
Total assets	16,120,288			15,519,464	$ 15,802,535
Liabilities and Stockholders' Equity
Accounts payable	32,496			66,289
Accounts payable, related parties	100,437
Accrued liabilities	392,726			465,070
Revenue distributions payable	231,152			310,827
Derivative instruments				532
Short-term lease liabilities	409,990			2,459
Other current liabilities	4,367			8,363
Total current liabilities	1,171,168			853,540
Long-term debt	3,703,828			5,461,688
Deferred income tax liability	916,031			650,788
Long-term lease liabilities	2,823,197			2,873
Other liabilities	59,366			63,098
Total liabilities	8,673,590			7,031,987
Common stock	3,041			3,086
Additional paid-in capital	6,124,042			6,485,174
Accumulated earnings	1,319,615			1,177,548
Total stockholders' equity	7,446,698			7,665,808
Noncontrolling interests in consolidated subsidiary				821,669
Total equity	7,446,698	$ 8,339,700	$ 8,292,798	8,487,477	$ 8,671,152	$ 8,802,911	$ 8,921,098	$ 8,876,136
Total liabilities and equity	16,120,288			15,519,464
Reportable legal entity
Liabilities and Stockholders' Equity
Long-term debt	3,703,828			3,829,541
Reportable legal entity | Parent (Antero)
Current assets:
Accounts receivable, net	29,207			49,529
Intercompany receivables				383
Accrued revenue	281,177			474,827
Derivative instruments	411,774			245,263
Other current assets	7,342			13,937
Total current assets	729,500			783,939
Unproved properties	1,406,464			1,767,600
Proved properties	11,568,285			13,306,585
Gathering systems and facilities	5,802			17,825
Other property and equipment	70,965			65,770
Property and equipment, gross	13,051,516			15,157,780
Less accumulated depletion, depreciation, and amortization	(3,136,767)			(3,654,392)
Property and equipment, net	9,914,749			11,503,388
Operating leases right-of-use assets	3,230,148
Derivative instruments	405,180			362,169
Investment in consolidated affiliates	1,337,849			(740,031)
Contingent acquisition consideration				114,995
Investments in unconsolidated affiliates	481,474
Other assets	21,388			31,200
Total assets	16,120,288			12,055,660
Liabilities and Stockholders' Equity
Accounts payable	32,496			44,917
Accounts payable, related parties	300,774
Intercompany payable				111,620
Accrued liabilities	392,726			392,949
Revenue distributions payable	231,152			310,827
Derivative instruments				532
Short-term lease liabilities	409,990			2,459
Other current liabilities	4,367			2,162
Total current liabilities	1,371,505			865,466
Long-term debt	3,703,828			3,829,541
Deferred income tax liability	916,031			650,788
Long-term lease liabilities	2,823,197			2,873
Other liabilities	59,366			55,017
Total liabilities	8,873,927			5,403,685
Common stock	3,041			3,086
Additional paid-in capital	6,124,042			5,471,341
Accumulated earnings	1,119,278			1,177,548
Total stockholders' equity				6,651,975
Total equity	7,246,361			6,651,975
Total liabilities and equity	16,120,288			12,055,660
Reportable legal entity | Guarantor Subsidiaries
Current assets:
Intercompany receivables	131,135
Total current assets	131,135
Investments in unconsolidated affiliates	1,337,849
Total assets	1,468,984
Liabilities and Stockholders' Equity
Additional paid-in capital	1,337,849
Accumulated earnings	131,135
Total equity	1,468,984
Total liabilities and equity	1,468,984
Reportable legal entity | Non-Guarantor Subsidiaries
Current assets:
Accounts receivable, net				1,544
Intercompany receivables				115,378
Other current assets				21,513
Total current assets				138,435
Water handling and treatment systems				1,004,793
Gathering systems and facilities				2,452,883
Other property and equipment				72
Property and equipment, gross				3,457,748
Less accumulated depletion, depreciation, and amortization				(499,333)
Property and equipment, net				2,958,415
Investments in unconsolidated affiliates				433,642
Other assets				15,925
Total assets				3,546,417
Liabilities and Stockholders' Equity
Accounts payable				21,372
Intercompany payable				4,141
Accrued liabilities				72,121
Other current liabilities				2,052
Total current liabilities				99,686
Long-term debt				1,632,147
Contingent acquisition consideration				114,995
Other liabilities				8,081
Total liabilities				1,854,909
Partners' capital				1,691,508
Total stockholders' equity				1,691,508
Total equity				1,691,508
Total liabilities and equity				3,546,417
Eliminations
Current assets:
Intercompany receivables	(131,135)			(115,761)
Total current assets	(131,135)			(115,761)
Proved properties				(600,913)
Water handling and treatment systems				9,025
Property and equipment, gross				(591,888)
Property and equipment, net				(591,888)
Investment in consolidated affiliates	(1,337,849)			740,031
Contingent acquisition consideration				(114,995)
Total assets	(1,468,984)			(82,613)
Liabilities and Stockholders' Equity
Accounts payable, related parties	(200,337)
Intercompany payable				(115,761)
Other current liabilities				4,149
Total current liabilities	(200,337)			(111,612)
Contingent acquisition consideration				(114,995)
Total liabilities	(200,337)			(226,607)
Partners' capital				(1,691,508)
Additional paid-in capital	(1,337,849)			1,013,833
Accumulated earnings	69,202
Total stockholders' equity				(677,675)
Noncontrolling interests in consolidated subsidiary				821,669
Total equity	(1,268,647)			143,994
Total liabilities and equity	$ (1,468,984)			$ (82,613)

Subsidiary Guarantors - Stateme

Subsidiary Guarantors - Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenue and other:
Revenues from contracts with customers	$ 896,612			$ 1,019,555			$ 2,980,757	$ 2,865,104
Commodity derivative fair value gains	220,788			57,019			471,847	134,793
Marketing derivative fair value gains (losses)	0			(42)			0	94,081
Loss on sale of assets							951
Total revenue	1,118,881			1,076,532			3,455,952	3,093,978
Operating expenses:
Production and ad valorem taxes	28,863			30,518			95,509	82,232
Impairment of oil and gas properties	1,041,469			221,094			1,253,712	406,068
Impairment of midstream assets	7,800			1,157			14,782	9,658
Depletion, depreciation, and amortization	241,503			243,186			724,006	709,480
Accretion of asset retirement obligations	927			710			2,821	2,101
General and administrative	35,923			59,860			146,507	181,576
Contract termination and rig stacking	62						14,026
Total operating expenses	2,104,759			1,071,728			4,375,541	2,975,444
Operating income (loss)	(985,878)			4,804			(919,589)	118,534
Equity in earnings (loss) of unconsolidated affiliates	(117,859)			10,705			(90,193)	27,832
Interest expense, net	(47,754)			(74,528)			(173,868)	(208,303)
Gain on deconsolidation of Antero Midstream Partners LP							1,406,042
Total other income (expenses)	(165,613)			(63,823)			1,141,981	(180,471)
Income (loss) before income taxes	(1,151,491)			(59,019)			222,392	(61,937)
Provision for income tax (expense) benefit	272,627			(18,953)			(33,332)	(2,500)
Net income (loss) and comprehensive income (loss) including noncontrolling interests	(878,864)	$ 42,168	$ 1,025,756	(77,972)	$ (67,275)	$ 80,810	189,060	(64,437)
Net income and comprehensive income attributable to noncontrolling interests				76,447			46,993	211,534
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	(878,864)			(154,419)			142,067	(275,971)
Natural gas sales
Revenue and other:
Revenues from contracts with customers	524,448			527,122			1,735,086	1,498,324
Natural gas liquids sales
Revenue and other:
Revenues from contracts with customers	284,958			338,269			902,606	828,424
Oil sales
Revenue and other:
Revenues from contracts with customers	40,561			59,722			137,675	128,869
Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers				4,844			4,479	15,298
Operating expenses:
Cost of goods and services sold	603,860			326,504			1,595,223	926,228
Marketing
Revenue and other:
Revenues from contracts with customers	46,645			89,598			200,911	394,189
Operating expenses:
Cost of goods and services sold	108,216			151,764			408,839	560,924
Exploration
Operating expenses:
Cost of goods and services sold	208			666			648	4,022
Lease operating
Operating expenses:
Cost of goods and services sold	35,928			36,269			118,517	93,155
Other income
Revenue and other:
Revenues from contracts with customers	1,481						3,348
Reportable legal entity | Parent (Antero)
Revenue and other:
Commodity derivative fair value gains	220,788			57,019			471,847	134,793
Marketing derivative fair value gains (losses)				(42)				94,081
Loss on sale of assets							951
Total revenue	1,118,881			1,077,015			3,453,124	3,095,061
Operating expenses:
Production and ad valorem taxes	28,863			29,352			94,569	79,045
Impairment of oil and gas properties	1,041,469			221,094			1,253,712	406,068
Impairment of midstream assets	7,800						7,800	4,470
Depletion, depreciation, and amortization	241,503			204,730			702,299	602,159
Accretion of asset retirement obligations	927			677			2,758	2,000
General and administrative	35,923			45,477			128,213	138,555
Contract termination and rig stacking	62						14,026
Accretion of contingent acquisition consideration								(11,841)
Total operating expenses	2,104,759			1,131,486			4,439,278	3,132,596
Operating income (loss)	(985,878)			(54,471)			(986,154)	(37,535)
Equity in earnings (loss) of unconsolidated affiliates	(38,255)						(33,255)
Interest expense, net	(47,754)			(57,632)			(157,053)	(165,519)
Equity in earnings (loss) of consolidated subsidiaries				(23,363)			15,021	(70,417)
Gain on deconsolidation of Antero Midstream Partners LP							1,205,705
Total other income (expenses)	(86,009)			(80,995)			1,030,418	(235,936)
Income (loss) before income taxes	(1,071,887)			(135,466)			44,264	(273,471)
Provision for income tax (expense) benefit	272,627			(18,953)			(33,332)	(2,500)
Net income (loss) and comprehensive income (loss) including noncontrolling interests				(154,419)			10,932	(275,971)
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	(799,260)			(154,419)			10,932	(275,971)
Reportable legal entity | Parent (Antero) | Natural gas sales
Revenue and other:
Revenues from contracts with customers	524,448			527,122			1,735,086	1,498,324
Reportable legal entity | Parent (Antero) | Natural gas liquids sales
Revenue and other:
Revenues from contracts with customers	284,958			338,269			902,606	828,424
Reportable legal entity | Parent (Antero) | Oil sales
Revenue and other:
Revenues from contracts with customers	40,561			59,722			137,675	128,869
Reportable legal entity | Parent (Antero) | Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	603,860			442,602			1,705,709	1,236,655
Reportable legal entity | Parent (Antero) | Marketing
Revenue and other:
Revenues from contracts with customers	46,645			89,598			200,911	394,189
Operating expenses:
Cost of goods and services sold	108,216			151,764			408,839	560,924
Reportable legal entity | Parent (Antero) | Exploration
Operating expenses:
Cost of goods and services sold	208			666			648	4,022
Reportable legal entity | Parent (Antero) | Lease operating
Operating expenses:
Cost of goods and services sold	35,928			35,124			119,754	98,698
Reportable legal entity | Parent (Antero) | Other income
Revenue and other:
Revenues from contracts with customers	1,481			5,327			4,999	16,381
Reportable legal entity | Guarantor Subsidiaries
Operating expenses:
Equity in earnings (loss) of unconsolidated affiliates	(79,604)						(69,202)
Gain on deconsolidation of Antero Midstream Partners LP							200,337
Total other income (expenses)	(79,604)						131,135
Income (loss) before income taxes	(79,604)						131,135
Net income (loss) and comprehensive income (loss) including noncontrolling interests							131,135
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	$ (79,604)						131,135
Reportable legal entity | Non-Guarantor Subsidiaries
Revenue and other:
Loss on sale of assets								(583)
Total revenue				266,205			218,360	746,771
Operating expenses:
Production and ad valorem taxes				1,166				3,187
Impairment of midstream assets				1,157			6,982	5,771
Depletion, depreciation, and amortization				38,456			21,707	107,321
Accretion of asset retirement obligations				33			63	101
General and administrative				15,015			18,793	44,967
Accretion of contingent acquisition consideration				4,020			1,928	11,841
Total operating expenses				140,156			114,291	394,355
Operating income (loss)				126,049			104,069	352,416
Equity in earnings (loss) of unconsolidated affiliates				10,705			12,264	27,832
Interest expense, net				(16,989)			(16,815)	(42,913)
Total other income (expenses)				(6,284)			(4,551)	(15,081)
Income (loss) before income taxes				119,765			99,518	337,335
Net income (loss) and comprehensive income (loss) including noncontrolling interests				119,765			99,518	337,335
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation				119,765			99,518	337,335
Reportable legal entity | Non-Guarantor Subsidiaries | Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers				266,205			218,360	746,188
Operating expenses:
Cost of goods and services sold				12,701				36,469
Reportable legal entity | Non-Guarantor Subsidiaries | Lease operating
Operating expenses:
Cost of goods and services sold				67,608			64,818	184,698
Eliminations
Revenue and other:
Loss on sale of assets								583
Total revenue				(266,688)			(215,532)	(747,854)
Operating expenses:
Production and ad valorem taxes							940
Impairment of midstream assets								(583)
General and administrative				(632)			(499)	(1,946)
Accretion of contingent acquisition consideration				(4,020)			(1,928)	(11,841)
Total operating expenses				(199,914)			(178,028)	(551,507)
Operating income (loss)				(66,774)			(37,504)	(196,347)
Interest expense, net				93				129
Equity in earnings (loss) of consolidated subsidiaries				23,363			(15,021)	70,417
Total other income (expenses)				23,456			(15,021)	70,546
Income (loss) before income taxes				(43,318)			(52,525)	(125,801)
Net income (loss) and comprehensive income (loss) including noncontrolling interests				(43,318)			(52,525)	(125,801)
Net income and comprehensive income attributable to noncontrolling interests				76,447			46,993	211,534
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation				(119,765)			(99,518)	(337,335)
Eliminations | Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers				(261,361)			(213,881)	(730,890)
Operating expenses:
Cost of goods and services sold				(128,799)			(110,486)	(346,896)
Eliminations | Lease operating
Operating expenses:
Cost of goods and services sold				(66,463)			(66,055)	(190,241)
Eliminations | Other income
Revenue and other:
Revenues from contracts with customers				$ (5,327)			$ (1,651)	$ (16,381)

Subsidiary Guarantors - Cash Fl

Subsidiary Guarantors - Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests	$ (878,864)	$ 42,168	$ 1,025,756	$ (77,972)	$ (67,275)	$ 80,810	$ 189,060	$ (64,437)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, amortization, and accretion							726,827	711,581
Impairment of oil and gas properties	1,041,469			221,094			1,253,712	406,068
Impairment of midstream assets	7,800			1,157			14,782	9,658
Commodity derivative fair value gains	(220,788)			(57,019)			(471,847)	(134,793)
Gains on settled commodity derivatives							261,794	268,369
Marketing derivative fair value (gains) losses	0			42			0	(94,081)
Gains on settled marketing derivatives								78,098
Deferred income tax expense							32,019	2,500
Gain on sale of assets							951
Equity-based compensation expense	3,875			16,202			19,327	56,429
Equity in earnings (loss) of unconsolidated affiliates	117,859			(10,705)			90,193	(27,832)
Distributions/dividends of earnings from unconsolidated affiliates							109,241	29,660
Gain on deconsolidation of Antero Midstream Partners LP							(1,406,042)
Other							8,179	2,945
Changes in current assets and liabilities							127,322	16,233
Net cash provided by operating activities							955,518	1,260,398
Cash flows provided by (used in) investing activities:
Additions to unproved properties							(69,796)	(130,381)
Drilling and completion costs							(957,931)	(1,125,660)
Additions to water handling and treatment systems							(24,416)	(77,385)
Additions to gathering systems and facilities							(48,239)	(337,448)
Additions to other property and equipment							(5,980)	(5,371)
Investments in unconsolidated affiliates							(25,020)	(91,419)
Proceeds from the Antero Midstream Partners LP Transactions							296,611
Change in other assets							7,461	(2,675)
Proceeds from sale of assets							1,983
Net cash used in investing activities							(825,327)	(1,770,339)
Cash flows provided by (used in) financing activities:
Repurchases of common stock							(17,924)
Issuance of senior notes							650,000
Borrowings (repayments) on bank credit facilities, net							(45,000)	682,000
Payments of deferred financing costs							(8,259)
Distributions to noncontrolling interests in Antero Midstream Partners LP							(85,076)	(188,775)
Employee tax withholding for settlement of equity compensation awards							(2,379)	(8,205)
Other							(2,021)	(3,520)
Net cash provided by financing activities							489,341	481,500
Effect of deconsolidation of Antero Midstream Partners LP							(619,532)
Net increase (decrease) in cash and cash equivalents								(28,441)
Cash and cash equivalents, beginning of period						28,441		28,441
Reportable legal entity | Parent (Antero)
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests				(154,419)			10,932	(275,971)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, amortization, and accretion							705,057	604,159
Accretion of contingent acquisition consideration								(11,841)
Impairment of oil and gas properties	1,041,469			221,094			1,253,712	406,068
Impairment of midstream assets	7,800						7,800	4,470
Commodity derivative fair value gains	(220,788)			(57,019)			(471,847)	(134,793)
Gains on settled commodity derivatives							261,794	268,369
Marketing derivative fair value (gains) losses				42				(94,081)
Gains on settled marketing derivatives								78,098
Deferred income tax expense							32,019	2,500
Gain on sale of assets							951
Equity-based compensation expense							16,850	39,823
Equity in earnings of consolidated subsidiaries				23,363			(15,021)	70,417
Equity in earnings (loss) of unconsolidated affiliates	38,255						33,255
Distributions/dividends of earnings from unconsolidated affiliates							96,636
Gain on deconsolidation of Antero Midstream Partners LP							(1,205,705)
Distributions from subsidiaries							94,391	115,678
Other							(40,493)	862
Changes in current assets and liabilities							121,087	20,015
Net cash provided by operating activities							901,418	1,093,773
Cash flows provided by (used in) investing activities:
Additions to unproved properties							(69,796)	(130,381)
Drilling and completion costs							(978,496)	(1,328,289)
Additions to gathering systems and facilities								175
Additions to other property and equipment							(4,918)	(5,371)
Proceeds from the Antero Midstream Partners LP Transactions							296,611
Change in other assets							10,818	(1,810)
Proceeds from sale of assets							1,983
Net cash used in investing activities							(743,798)	(1,465,676)
Cash flows provided by (used in) financing activities:
Repurchases of common stock							(17,924)
Borrowings (repayments) on bank credit facilities, net							(135,379)	362,000
Payments of deferred financing costs							(791)
Employee tax withholding for settlement of equity compensation awards							(2,350)	(6,806)
Other							(1,176)	(3,369)
Net cash provided by financing activities							(157,620)	351,825
Net increase (decrease) in cash and cash equivalents								(20,078)
Cash and cash equivalents, beginning of period						20,078		20,078
Reportable legal entity | Guarantor Subsidiaries
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests							131,135
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Equity in earnings (loss) of unconsolidated affiliates	$ 79,604						69,202
Gain on deconsolidation of Antero Midstream Partners LP							(200,337)
Reportable legal entity | Non-Guarantor Subsidiaries
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests				119,765			99,518	337,335
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, amortization, and accretion							21,770	107,422
Accretion of contingent acquisition consideration				4,020			1,928	11,841
Impairment of midstream assets				1,157			6,982	5,771
Gain on sale of assets								(583)
Equity-based compensation expense							2,477	16,606
Equity in earnings (loss) of unconsolidated affiliates				(10,705)			(12,264)	(27,832)
Distributions/dividends of earnings from unconsolidated affiliates							12,605	29,660
Other							750	2,083
Changes in current assets and liabilities							(10,573)	(10,901)
Net cash provided by operating activities							121,265	471,402
Cash flows provided by (used in) investing activities:
Additions to water handling and treatment systems							(24,547)	(68,325)
Additions to gathering systems and facilities							(48,239)	(337,623)
Additions to other property and equipment							(1,062)
Investments in unconsolidated affiliates							(25,020)	(91,419)
Change in other assets							(3,357)	(865)
Other								4,470
Net cash used in investing activities							(102,225)	(493,762)
Cash flows provided by (used in) financing activities:
Issuance of senior notes							650,000
Borrowings (repayments) on bank credit facilities, net							90,379	320,000
Payments of deferred financing costs							(7,468)
Distributions to noncontrolling interests in Antero Midstream Partners LP							(131,545)	(304,453)
Employee tax withholding for settlement of equity compensation awards							(29)	(1,399)
Other							(845)	(151)
Net cash provided by financing activities							600,492	13,997
Effect of deconsolidation of Antero Midstream Partners LP							(619,532)
Net increase (decrease) in cash and cash equivalents								(8,363)
Cash and cash equivalents, beginning of period						$ 8,363		8,363
Eliminations
Cash flows provided by (used in) operating activities:
Net income (loss) including noncontrolling interests				(43,318)			(52,525)	(125,801)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Accretion of contingent acquisition consideration				(4,020)			(1,928)	(11,841)
Impairment of midstream assets								(583)
Gain on sale of assets								583
Equity in earnings of consolidated subsidiaries				$ (23,363)			15,021	(70,417)
Distributions from subsidiaries							(94,391)	(115,678)
Other							47,922
Changes in current assets and liabilities							16,808	7,119
Net cash provided by operating activities							(67,165)	(304,777)
Cash flows provided by (used in) investing activities:
Drilling and completion costs							20,565	202,629
Additions to water handling and treatment systems							131	(9,060)
Other								(4,470)
Net cash used in investing activities							20,696	189,099
Cash flows provided by (used in) financing activities:
Distributions to noncontrolling interests in Antero Midstream Partners LP							46,469	115,678
Net cash provided by financing activities							$ 46,469	$ 115,678