Antero Resources (AR) 10-Q 31 Jul 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2019	Jul. 26, 2019
Document and Entity Information
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Document Period End Date	Jun. 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
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		309,221,992
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Entity Central Index Key	0001433270
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Accounts receivable	$ 49,994	$ 51,073
Accrued revenue	308,761	474,827
Derivative instruments	346,894	245,263
Other current assets	7,400	35,450
Total current assets	713,049	806,613
Oil and gas properties, at cost (successful efforts method):
Unproved properties	1,585,355	1,767,600
Proved properties	13,357,733	12,705,672
Water handling and treatment systems		1,013,818
Gathering systems and facilities	17,825	2,470,708
Other property and equipment	69,676	65,842
Property and equipment, gross	15,030,589	18,023,640
Less accumulated depletion, depreciation, and amortization	(4,115,187)	(4,153,725)
Property and equipment, net	10,915,402	13,869,915
Operating leases right-of-use assets	3,330,795
Derivative instruments	369,548	362,169
Investments in unconsolidated affiliates	1,967,203	433,642
Other assets	34,883	47,125
Total assets	17,330,880	15,519,464
Current liabilities:
Accounts payable	44,758	66,289
Accounts payable, related parties	98,570
Accrued liabilities	358,680	465,070
Revenue distributions payable	301,032	310,827
Derivative instruments	274	532
Short-term lease liabilities	413,691	2,459
Other current liabilities	4,102	8,363
Total current liabilities	1,221,107	853,540
Long-term liabilities:
Long-term debt	3,602,379	5,461,688
Deferred income tax liability	1,188,975	650,788
Long-term lease liabilities	2,920,754	2,873
Other liabilities	57,965	63,098
Total liabilities	8,991,180	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 309,123 shares issued and outstanding at December 31, 2018 and June 30, 2019, respectively	3,091	3,086
Additional paid-in capital	6,138,130	6,485,174
Accumulated earnings	2,198,479	1,177,548
Total stockholders' equity	8,339,700	7,665,808
Noncontrolling interests in consolidated subsidiary		821,669
Total equity	8,339,700	8,487,477
Total liabilities and equity	$ 17,330,880	$ 15,519,464

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 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	309,123,000	308,594,000
Common stock, shares outstanding	309,123,000	308,594,000

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue and other:
Revenues from contracts with customers	$ 969,477	$ 934,118	$ 2,084,145	$ 1,845,548
Commodity derivative fair value gains (losses)	328,427	55,336	251,059	77,773
Marketing derivative fair value gains		(110)		94,124
Total revenue	1,299,664	989,344	2,337,071	2,017,445
Operating expenses:
Production and ad valorem taxes	30,968	25,891	66,646	51,714
Impairment of oil and gas properties	130,999	134,437	212,243	184,973
Impairment of gathering systems and facilities		8,501	6,982	8,501
Depletion, depreciation, and amortization	242,302	238,050	482,503	466,294
Loss on sale of assets	951		951
Accretion of asset retirement obligations	918	700	1,894	1,390
General and administrative	42,382	61,687	110,584	121,717
Contract termination and rig stacking	5,604		13,964
Total operating expenses	1,199,668	1,022,107	2,270,782	1,903,714
Operating income (loss)	99,996	(32,763)	66,289	113,731
Other income (expenses):
Equity in earnings (loss) of unconsolidated affiliates	13,585	9,264	27,666	17,126
Interest expense, net	(54,164)	(69,349)	(126,114)	(133,775)
Gain on deconsolidation of Antero Midstream Partners LP			1,406,042
Total other expenses	(40,579)	(60,085)	1,307,594	(116,649)
Income (loss) before income taxes	59,417	(92,848)	1,373,883	(2,918)
Provision for income tax (expense) benefit	(17,249)	25,573	(305,959)	16,453
Net income (loss) and comprehensive income (loss) including noncontrolling interests	42,168	(67,275)	1,067,924	13,535
Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests		69,110	46,993	135,087
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	$ 42,168	$ (136,385)	$ 1,020,931	$ (121,552)
Earnings (loss) per common share-basic (in dollars per share)
Earnings (loss) per common share-basic (in dollars per share)	$ 0.14	$ (0.43)	$ 3.31	$ (0.38)
Earnings (loss) per common share-assuming dilution (in dollars per share)
Earnings (loss) per common share-assuming dilution (in dollars per share)	$ 0.14	$ (0.43)	$ 3.30	$ (0.38)
Weighted average number of shares outstanding
Basic (in shares)	309,062	316,992	308,879	316,733
Diluted (in shares)	309,137	316,992	309,082	316,733
Natural gas sales
Revenue and other:
Revenues from contracts with customers	$ 553,372	$ 473,540	$ 1,210,638	$ 971,203
Natural gas liquids sales
Revenue and other:
Revenues from contracts with customers	303,963	255,985	617,648	490,155
Oil sales
Revenue and other:
Revenues from contracts with customers	49,062	38,873	97,114	69,146
Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers		5,518	4,479	10,453
Operating expenses:
Cost of goods and services sold	566,834	307,786	991,363	599,724
Marketing
Revenue and other:
Revenues from contracts with customers	63,080	160,202	154,266	304,591
Operating expenses:
Cost of goods and services sold	137,539	213,420	300,623	409,159
Other income
Revenue and other:
Revenues from contracts with customers	1,760		1,867
Lease operating
Operating expenses:
Cost of goods and services sold	40,857	30,164	82,589	56,886
Exploration
Operating expenses:
Cost of goods and services sold	$ 314	$ 1,471	$ 440	$ 3,356

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)
Equity-based compensation expense	$ 6,549	$ 19,071	$ 15,452	$ 40,227

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)					13,535
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
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
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)					1,067,924
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
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

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash flows provided by (used in) operating activities:
Net income including noncontrolling interests	$ 1,067,924	$ 13,535
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion	484,397	467,684
Impairment of oil and gas properties	212,243	184,973
Impairment of gathering systems and facilities	6,982	8,501
Commodity derivative fair value (gains) losses	(251,059)	(77,773)
Gains on settled commodity derivatives	141,791	197,225
Marketing derivative fair value gains		(94,124)
Gains on settled marketing derivatives		94,158
Deferred income tax expense (benefit)	304,963	(16,453)
Loss on sale of assets	951
Equity-based compensation expense	15,452	40,227
Equity in earnings of unconsolidated affiliates	(27,666)	(17,126)
Distributions of earnings from unconsolidated affiliates	60,527	17,895
Gain on deconsolidation of Antero Midstream Partners LP	(1,406,042)
Other	5,670	1,932
Changes in current assets and liabilities:
Accounts receivable	5,848	10,237
Accrued revenue	166,066	(21,092)
Other current assets	2,307	2,353
Accounts payable	(2,424)	2,948
Accrued liabilities	(22,146)	24,065
Revenue distributions payable	(9,795)	1,617
Other current liabilities	1,119	(1,842)
Net cash provided by operating activities	757,108	838,940
Cash flows provided by (used in) investing activities:
Additions to unproved properties	(56,814)	(87,861)
Drilling and completion costs	(680,088)	(752,781)
Additions to water handling and treatment systems	(24,416)	(58,127)
Additions to gathering systems and facilities	(48,239)	(206,753)
Additions to other property and equipment	(4,629)	(3,502)
Investments in unconsolidated affiliates	(25,020)	(56,297)
Proceeds from the Antero Midstream Partners LP Transactions	296,611
Change in other assets	(4,974)	(7,026)
Proceeds from asset sales	1,983
Net cash used in investing activities	(545,586)	(1,172,347)
Cash flows provided by (used in) financing activities:
Issuance of senior notes	650,000
Borrowings (repayments) on bank credit facilities, net	(145,000)	485,000
Payments of deferred financing costs	(8,259)
Distributions to noncontrolling interests in Antero Midstream Partners LP	(85,076)	(119,023)
Employee tax withholding for settlement of equity compensation awards	(2,295)	(7,967)
Other	(1,360)	(2,436)
Net cash provided by financing activities	408,010	355,574
Effect of deconsolidation of Antero Midstream Partners LP	(619,532)
Net decrease in cash and cash equivalents		22,167
Cash and cash equivalents, beginning of period		28,441
Cash and cash equivalents, end of period		50,608
Supplemental disclosure of cash flow information:
Cash paid during the period for interest	119,180	130,231
Increase in accounts payable and accrued liabilities for additions to property and equipment	$ (33,240)	$ 2,089

Organization

Organization	6 Months Ended
	Jun. 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	6 Months Ended
	Jun. 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 June 30, 2019, and the results of its operations and its cash flows for the three and six months ended June 30, 2018 and 2019. The Company has 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 June 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 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 a 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, the Company 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 which 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 June 30, 2019, the book overdraft included within accounts payable and revenue distributions payable were million, respectively. As of December 31, 2018, the book overdraft included within accounts payable and revenue distributions payable were (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 30, 2018 and 2019. During the six months ended June 30, 2019, we recorded an impairment charge of 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 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, anticipated capital expenditures, and a commensurate discount rate. The Company did not record any impairment expenses associated with its proved properties during the six months ended June 30, 2018 and 2019. (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 resell the Company’s production to third parties located in foreign countries. 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 June 30, ​ Six months ended June 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Basic weighted average number of shares outstanding ​ 316,992 ​ 309,062 ​ 316,733 ​ 308,879 ​ Add: Dilutive effect of restricted stock units ​ — ​ 33 ​ — ​ 48 ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ — ​ — ​ Add: Dilutive effect of performance stock units ​ — ​ 42 ​ — ​ 155 ​ Diluted weighted average number of shares outstanding ​ 316,992 ​ 309,137 ​ 316,733 ​ 309,082 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding equity awards excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ ​ ​ ​ ​ Restricted stock units ​ 2,899 ​ 2,284 ​ 3,088 ​ 1,877 ​ Outstanding stock options ​ 639 ​ 538 ​ 646 ​ 554 ​ Performance stock units ​ 1,860 ​ 2,592 ​ 1,556 ​ 1,996 ​ (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 issued, 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 and implemented new lease software 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	6 Months Ended
	Jun. 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 previously announced Simplification Agreement (the “Simplification Agreement”), dated as of October 9, 2018, by and among Antero Midstream GP LP, Antero Partners surviving the merger as an indirect, wholly owned subsidiary of Antero Midstream Corporation (together, along with the other transactions contemplated by the Simplification Agreement, the “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	6 Months Ended
	Jun. 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 the purchaser 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 the 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. (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— ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended June 30, ​ Six months ended June 30, ​ Segment to which ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ revenues relate ​ Revenues from contracts with customers: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 473,540 ​ ​ 553,372 ​ $ 971,203 ​ ​ 1,210,638 ​ Exploration and production ​ Natural gas liquids sales (ethane) ​ ​ 32,687 ​ ​ 30,374 ​ ​ 59,762 ​ ​ 65,890 ​ Exploration and production ​ Natural gas liquids sales (C3+ NGLs) ​ ​ 223,298 ​ ​ 273,589 ​ ​ 430,393 ​ ​ 551,758 ​ Exploration and production ​ Oil sales ​ ​ 38,873 ​ ​ 49,062 ​ ​ 69,146 ​ ​ 97,114 ​ Exploration and production ​ Gathering and compression (1) ​ 4,263 ​ — ​ ​ 8,408 ​ 3,972 ​ Equity method investment in AMC ​ Water handling and treatment (1) ​ ​ 1,255 ​ ​ — ​ ​ 2,045 ​ ​ 507 ​ Equity method investment in AMC ​ Marketing ​ ​ 160,202 ​ ​ 63,080 ​ ​ 304,591 ​ ​ 154,266 ​ Marketing ​ Total ​ 934,118 ​ 969,477 ​ ​ 1,845,548 ​ 2,084,145 ​ ​ ​ Income from derivatives and other sources ​ ​ 55,226 ​ ​ 330,187 ​ ​ 171,897 ​ ​ 252,926 ​ ​ ​ Total revenue and other ​ $ 989,344 ​ ​ 1,299,664 ​ $ 2,017,445 ​ ​ 2,337,071 ​ ​ ​ (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 (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 June 30, 2019, our receivables from contracts with customers were

Equity Method Investments

Equity Method Investments	6 Months Ended
	Jun. 30, 2019
Equity Method Investments.
Equity Method Investments	(5) Equity Method Investments At June 30, 2019, Antero owned approximately 31.3% 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 six months ended June 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 ​ ​ 15,402 ​ ​ 27,666 ​ Distributions/dividends from unconsolidated affiliates ​ (3,000) ​ ​ (9,605) ​ ​ (47,922) ​ ​ (60,527) ​ Elimination of intercompany profit ​ ​ — ​ ​ — ​ ​ 11,928 ​ ​ 11,928 ​ Effects of deconsolidation (4) ​ (66,997) ​ ​ (391,324) ​ ​ 1,987,795 ​ ​ 1,529,474 ​ Balance at June 30, 2019 ​ $ — ​ ​ — ​ ​ 1,967,203 ​ ​ 1,967,203 ​ (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 six months ended June 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) ​ June 30, 2019 ​ Current assets ​ $ 115,367 ​ Noncurrent assets ​ ​ 6,653,642 ​ Total assets ​ $ 6,769,009 ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 237,504 ​ Noncurrent liabilities ​ ​ 2,559,146 ​ Stockholders' equity ​ ​ 3,972,359 ​ Total liabilities and equity ​ $ 6,769,009 ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ For the period ​ ​ ​ ​ March 13, 2019 through ​ (in thousands) ​ June 30, 2019 ​ Revenues ​ $ 309,726 ​ Operating expenses ​ ​ 168,056 ​ Income from operations ​ $ 141,670 ​ Net income attributable to the equity method investments ​ $ 92,471 ​ ​

Accrued Liabilities

Accrued Liabilities	6 Months Ended
	Jun. 30, 2019
Accrued Liabilities
Accrued Liabilities	(6) Accrued Liabilities Accrued liabilities as of December 31, 2018 and June 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 June 30, 2019 ​ Capital expenditures ​ $ 113,237 ​ 62,631 ​ Gathering, compression, processing, and transportation expenses ​ ​ 148,032 ​ ​ 147,797 ​ Marketing expenses ​ ​ 67,082 ​ ​ 47,018 ​ Interest expense, net ​ 43,444 ​ 31,599 ​ Other ​ 93,275 ​ 69,635 ​ ​ ​ $ 465,070 ​ 358,680 ​ ​

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2019
Long-Term Debt.
Long-Term Debt	(7) Long-Term Debt ​ Long-term debt was as follows at December 31, 2018 and June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 June 30, 2019 ​ Antero Resources: ​ ​ ​ ​ ​ ​ ​ Credit Facility (a) ​ $ 405,000 ​ 175,000 ​ 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 ​ 1,095 ​ Net unamortized debt issuance costs ​ ​ (26,700) ​ ​ (23,716) ​ 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) ​ ​ — ​ ​ ​ $ 5,461,688 ​ 3,602,379 ​ (1) At December 31, 2018, Antero Midstream Partners’ indebtedness was included in the consolidated financial statements of Antero. At June 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 June 30, 2019, the borrowing base under the Credit Facility was 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 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 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 basis points. Antero was in compliance with all of the financial covenants under the Credit Facility as of December 31, 2018 and June 30, 2019. As of June 30, 2019, Antero had an outstanding balance under the Credit Facility of $175 million, with a weighted average interest rate of 3.69%, and outstanding letters of credit of $701 million. As of December 31, 2018, Antero had an outstanding balance under the Credit Facility of million. Commitment fees on the unused portion of the Credit Facility are due quarterly at rates ranging from (i) (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 2019. If Antero undergoes a change of control, 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 (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 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 2020. If Antero undergoes a change of control, 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 (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 2021. If Antero undergoes a change of control, 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 (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 on or after March 1, 2023. In addition, on or before March 1, 2020, Antero may redeem up to 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 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, 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 (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 . The note matures on June 1, 2020. At December 31, 2018, there was

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 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 six months ended June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ Asset retirement obligations—December 31, 2018 ​ $ 58,979 ​ Obligations settled ​ ​ (153) ​ Obligations incurred ​ 807 ​ Revisions to prior estimates ​ ​ — ​ Accretion expense ​ 1,894 ​ Effect of deconsolidation of Antero Midstream Partners LP (1) ​ (7,518) ​ Asset retirement obligations—June 30, 2019 ​ $ 54,009 ​ (1) Effective March 13, 2019, Antero Midstream Partners is no longer consolidated in Antero’s results. ​ Asset retirement obligations are included in other liabilities on the Company’s unaudited condensed consolidated balance sheets.

Equity-Based Compensation

Equity-Based Compensation	6 Months Ended
	Jun. 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 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). 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 six months ended June 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended June 30, ​ Six months ended June 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Restricted stock unit awards ​ $ 10,231 ​ ​ 2,624 ​ $ 23,675 ​ ​ 6,600 ​ Stock options ​ ​ 495 ​ ​ 45 ​ ​ 976 ​ ​ 389 ​ Performance share unit awards ​ ​ 3,490 ​ ​ 2,666 ​ ​ 6,001 ​ ​ 5,628 ​ Antero Midstream Partners phantom unit awards (1) ​ ​ 4,341 ​ ​ 949 ​ ​ 8,559 ​ ​ 2,075 ​ Equity awards issued to directors ​ ​ 514 ​ ​ 265 ​ ​ 1,016 ​ ​ 760 ​ Total expense ​ $ 19,071 ​ ​ 6,549 ​ $ 40,227 ​ ​ 15,452 ​ (1) Antero recognized compensation expense for equity awards granted under both the Plan and the AMP Plan because the awards under the AMP Plan are accounted for as if they are distributed by Antero Midstream Partners to Antero. Antero allocates a portion of equity-based compensation expense related to grants prior to the Transactions to Antero Midstream 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 Midstream 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 the Company’s common stock on the date of the grant. A summary of restricted stock unit award activity for the six months ended June 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 1,568,617 ​ $ 8.69 ​ ​ ​ ​ Vested (674,312) ​ $ 28.04 ​ ​ ​ ​ Forfeited (190,525) ​ $ 18.05 ​ ​ ​ ​ Total awarded and unvested—June 30, 2019 2,416,265 ​ $ 13.81 ​ $ 13,362 ​ ​ Intrinsic values are based on the closing price of the Company’s stock on the referenced dates. As of June 30, 2019, there was 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 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 the Company’s common stock on the dates of grant. A summary of stock option activity for the six months ended June 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 (46,062) ​ $ 50.00 ​ ​ ​ ​ ​ ​ ​ Expired — ​ $ — ​ ​ ​ ​ ​ ​ ​ Outstanding at June 30, 2019 533,555 ​ $ 50.60 ​ 5.29 ​ $ — ​ Vested or expected to vest as of June 30, 2019 533,555 ​ $ 50.60 ​ 5.29 ​ $ — ​ Exercisable at June 30, 2019 533,555 ​ $ 50.60 ​ ​ 5.29 ​ $ — ​ ​ Intrinsic values are based on the exercise price of the options and the closing price of the Company’s 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 the Company’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 June 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 the Company’s common stock achieving specific price thresholds over -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 . 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 the Company’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 of the PSUs granted. Expense related to these PSUs is recognized on a straight-line basis over . 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 the Company’s absolute TSR, with target payout achieved if the price per share of the Company’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 of the PSUs granted. Expense related to these PSUs is recognized on a straight-line basis over . 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 the Company’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 the Company’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 of the target number of TSR PSUs originally granted. Expense related to the TSR PSUs is recognized on a straight-line basis over . 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 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 six months ended June 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 (342,161) ​ $ 32.72 ​ Total awarded and unvested—June 30, 2019 2,809,572 ​ $ 16.95 ​ ​ 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 the Company’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 six months ended June 30, 2018 and 2019, and the assumptions used to determine the fair values: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Six months ended June 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 June 30, 2019, there was $26 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 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 ​ A summary of phantom unit awards activity for the six months ended June 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 (317,651) ​ $ 14.06 ​ ​ ​ ​ Forfeited (18,906) ​ $ 13.86 ​ ​ ​ ​ Total awarded and unvested—June 30, 2019 732,343 ​ $ 14.82 ​ $ 8,393 ​ (1) Effective March 12, 2019, a ll outstanding units in the AMP Plan , whether vested or unvested, were assumed by Antero Midstream Corporation and converted into restricted stock units under the AMC Plan. ​ Intrinsic values are based on the closing price of Antero Midstream Corporation’s common units on the referenced dates. As of June 30, 2019, there was

Financial Instruments

Financial Instruments	6 Months Ended
	Jun. 30, 2019
Financial Instruments
Financial Instruments	(10) Financial Instruments The carrying values of accounts receivable and accounts payable at December 31, 2018 and June 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 June 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 $3.3 billion at December 31, 2018 and June 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	6 Months Ended
	Jun. 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 six months ended June 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. 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 June 30, 2019, the Company’s fixed price natural gas and NGL swap positions from July 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; Argus Butane ARA=European Butane CIF ARA Argus; Argus Butane FEI=Argus Butane Far East Index; Argus Propane ARA=European Propane CIF ARA Argus; Argus Propane FEI=Argus Propane Far East Index): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas MMBtu/day ​ ​ Oil ​ ​ Natural Gas ​ Weighted ​ Three months ending September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 755,000 ​ ​ — ​ ​ — ​ $ 3.32 ​ NYMEX-WTI($/Bbl) ​ — ​ ​ 5,000 ​ ​ — ​ ​ 61.83 ​ Argus Butane ARA ($/MT) ​ — ​ ​ — ​ ​ 242 ​ ​ 330.25 ​ Argus Butane FEI ($/MT) ​ — ​ ​ — ​ ​ 24 ​ ​ 370.00 ​ Argus Propane ARA ($/MT) ​ — ​ ​ — ​ ​ 484 ​ ​ 328.17 ​ Argus Propane FEI ($/MT) ​ — ​ ​ — ​ ​ 274 ​ ​ 383.41 ​ Total ​ 755,000 ​ ​ 5,000 ​ ​ 1,024 ​ ​ ​ ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 755,000 ​ ​ — ​ ​ ​ ​ $ 3.45 ​ NYMEX-WTI($/Bbl) ​ — ​ ​ 5,000 ​ ​ ​ ​ ​ 61.83 ​ Total ​ 755,000 ​ ​ 5,000 ​ ​ ​ ​ ​ ​ ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 2,227,500 ​ ​ — ​ ​ ​ ​ $ 2.87 ​ NYMEX-WTI($/Bbl) ​ — ​ ​ 5,000 ​ ​ ​ ​ ​ 59.03 ​ Total ​ 2,227,500 ​ ​ 5,000 ​ ​ ​ ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,010,000 ​ ​ ​ ​ ​ ​ ​ $ 2.88 ​ Year ending December 31, 2022: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 850,000 ​ ​ ​ ​ ​ ​ ​ $ 3.00 ​ Year ending December 31, 2023: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 90,000 ​ ​ ​ ​ ​ ​ ​ $ 2.91 ​ ​ As of June 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 were as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas ​ Hedged ​ ​ ​ MMBtu/day ​ differential ​ Year ending December 31, 2020: ​ 60,000 ​ $ 0.353 ​ Year ending December 31, 2021: ​ 40,000 ​ $ 0.414 ​ Year ending December 31, 2022: ​ 60,000 ​ $ 0.515 ​ Year ending December 31, 2023: ​ 50,000 ​ $ 0.525 ​ Year ending December 31, 2024: ​ 50,000 ​ $ 0.530 ​ ​ As of June 30, 2019, the Company had NGL contracts totaling 500 Bbls/day of propane for July 1, 2019 through March 31, 2020 that fix the Mont Belvieu Propane index price at 50% of WTI. ​ ​ As of June 30, 2019, the Company’s fixed price natural gas collar positions from July 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 ​ Weighted average index price ​ ​ ​ MMBtu/day ​ Ceiling price ​ Floor price ​ Three months ending September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,575,000 ​ $ 3.30 ​ $ 2.50 ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,575,000 ​ $ 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 June 30, 2019, the unamortized portion of the premium was ​ (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 six months ended June 30, 2018, the Company recognized a fair value loss of less than million, respectively. There were no marketing derivative fair value gains or losses during the three or six months ended June 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 June 30, 2019. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ June 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 ​ $ 346,894 ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ 362,169 ​ Derivative instruments ​ ​ 369,548 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total asset derivatives ​ ​ ​ ​ 607,432 ​ ​ ​ ​ 716,442 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liability derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives - current ​ Derivative instruments ​ ​ 532 ​ Derivative instruments ​ ​ 274 ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ — ​ Derivative instruments ​ ​ — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total liability derivatives ​ ​ ​ ​ 532 ​ ​ ​ ​ 274 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net derivatives ​ ​ ​ $ 606,900 ​ ​ ​ $ 716,168 ​ ​ 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 ​ June 30, 2019 ​ ​ ​ Gross ​ Gross amounts ​ Net amounts ​ Gross ​ Gross amounts ​ Net amounts Commodity derivative assets ​ $ 658,830 ​ (51,398) ​ 607,432 ​ $ 729,664 ​ (13,222) ​ 716,442 ​ Commodity derivative liabilities ​ $ (51,930) ​ 51,398 ​ (532) ​ $ (13,496) ​ 13,222 ​ (274) ​ ​ 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 June 30, ​ Six months ended June 30, ​ ​ ​ location ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Commodity derivative fair value gains ​ Revenue ​ $ 55,336 ​ ​ 328,427 ​ ​ 77,773 ​ ​ 251,059 ​ Marketing derivative fair value gains (losses) ​ Revenue ​ $ (110) ​ ​ — ​ ​ 94,124 ​ ​ — ​ ​ The fair value of derivative instruments was determined using Level 2 inputs.

Leases

Leases	6 Months Ended
	Jun. 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 June 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ June 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Right-of-use Assets: ​ ​ ​ ​ ​ ​ ​ Processing plants ​ $ 1,587,374 ​ ​ — ​ Drilling rigs and completion services ​ ​ 115,034 ​ ​ — ​ Gas gathering lines and compressor stations (1) ​ ​ 1,580,130 ​ ​ — ​ Office space ​ ​ 42,200 ​ ​ — ​ Vehicles ​ ​ 5,627 ​ ​ 2,819 ​ Other office and field equipment ​ ​ 430 ​ ​ 831 ​ Total right-of-use assets ​ $ 3,330,795 ​ ​ 3,650 (2) (1) Gas gathering lines and compressor stations leases includes $1.4 billion related to Antero Midstream Corporation. (2) Financing lease assets are recorded net of accumulated amortization of $9 million as of June 30, 2019. ​ The Company’s lease liabilities as of June 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ June 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Location on the balance sheet: ​ ​ ​ ​ ​ ​ ​ Short-term lease liabilities ​ $ 412,143 ​ ​ 1,548 ​ Long-term lease liabilities ​ ​ 2,918,652 ​ ​ 2,102 ​ Total lease liabilities ​ $ 3,330,795 ​ ​ 3,650 ​ ​ 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 six months ended June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Statement of Operations Location ​ Three months ended June 30, 2019 ​ Six months ended June 30, 2019 ​ Gathering, compression, processing, and transportation ​ $ 218,542 ​ $ 406,389 ​ General and administrative ​ ​ 2,810 ​ ​ 5,536 ​ Contract termination and rig stacking ​ ​ 2,673 ​ ​ 10,692 ​ Total Lease Expense ​ $ 224,025 ​ $ 422,617 ​ ​ Costs associated with finance leases of less than $1 million for each of the three and six months ended June 30, 2019 were included in interest expense. ​ We capitalized $53 million and $108 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 six months ended June 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 $74 million at June 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 months ended June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended June 30, 2019 ​ Six months ended June 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 ​ $ 207,244 ​ ​ — ​ $ 357,564 ​ ​ — ​ Investing cash out flows related to operating leases ​ ​ 46,532 ​ ​ — ​ ​ 98,898 ​ ​ — ​ Financing cash out flows related to financing leases ​ ​ — ​ ​ 873 ​ ​ — ​ ​ 1,664 ​ ​ ​ ​ 253,776 ​ ​ 873 ​ ​ 456,462 ​ ​ 1,664 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 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 June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2019 ​ $ 206,320 ​ ​ 99 ​ ​ 206,419 ​ 2020 ​ ​ 396,473 ​ ​ 869 ​ ​ 397,342 ​ 2021 ​ ​ 349,212 ​ ​ 1,294 ​ ​ 350,506 ​ 2022 ​ ​ 359,759 ​ ​ 1,388 ​ ​ 361,147 ​ 2023 ​ ​ 377,790 ​ ​ — ​ ​ 377,790 ​ 2024 ​ ​ 392,323 ​ ​ — ​ ​ 392,323 ​ Thereafter ​ ​ 1,248,918 ​ ​ — ​ ​ 1,248,918 ​ Total lease payments ​ ​ 3,330,795 ​ ​ 3,650 ​ ​ 3,334,445 ​ Less: imputed interest ​ ​ — ​ ​ — ​ ​ — ​ Total ​ $ 3,330,795 ​ ​ 3,650 ​ ​ 3,334,445 ​ ​ 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 June 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ June 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Weighted-average remaining lease term: ​ ​ 8.5 years ​ ​ 2.2 years ​ Weighted-average discount rate: ​ ​ 6.0 % ​ 5.5 % ​ As of June 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 six months ended June 30, 2019, gathering and compression fees paid by Antero related to this agreement were million, respectively. As of June 30, 2019,

Commitments

Commitments	6 Months Ended
	Jun. 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 June 30, 2019 (in millions). ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Firm ​ Processing, ​ Land payment obligations ​ Leases, including imputed interest ​ ​ ​ (in millions) ​ (a) ​ (b) ​ (c) ​ (d) ​ Total ​ Remainder of 2019 ​ $ 558 ​ ​ 27 ​ ​ 8 ​ ​ 206 ​ ​ 799 ​ 2020 ​ ​ 1,122 ​ ​ 54 ​ ​ 6 ​ ​ 397 ​ ​ 1,579 ​ 2021 ​ ​ 1,098 ​ ​ 54 ​ ​ 3 ​ ​ 350 ​ ​ 1,505 ​ 2022 ​ ​ 1,045 ​ ​ 54 ​ ​ — ​ ​ 361 ​ ​ 1,460 ​ 2023 ​ ​ 1,033 ​ ​ 48 ​ ​ — ​ ​ 378 ​ ​ 1,459 ​ 2024 ​ ​ 993 ​ ​ 48 ​ ​ — ​ ​ 392 ​ ​ 1,433 ​ Thereafter ​ ​ 7,807 ​ ​ 64 ​ ​ — ​ ​ 1,250 ​ ​ 9,121 ​ Total ​ $ 13,656 ​ ​ 349 ​ ​ 17 ​ ​ 3,334 ​ ​ 17,356 ​ ​ (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	6 Months Ended
	Jun. 30, 2019
Contingencies
Contingencies	​ (14) Contingencies Environmental In March 2011, we received orders for compliance from federal regulatory agencies, including the U.S. Environmental Protection Agency, relating to certain of our activities in West Virginia. The orders allege that certain of our operations at several well sites are in non-compliance with certain environmental regulations, such as unpermitted discharges of fill material into wetlands or waters of the United States that are potentially in violation of the Clean Water Act. Antero voluntarily reviewed all of its pre-2011 construction sites and entered into an agreement to restore or mitigate all areas of concern. The vast majority of the sites cited by regulators were among the sites we voluntarily reviewed. On January 31, 2019, we entered into a consent decree with state and federal regulators to settle for million and perform restoration at these sites along with mitigation at an approved mitigation site. The settlement was filed in federal court in West Virginia on February 11, 2019, entered and approved by the court on May 22, 2019, and paid in June 2019. Our operations at these locations 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. ​ 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 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. Since receipt of the NOV and information request, we have met with the EPA to discuss the alleged compliance issues but do not yet have any indication with respect to whether, and to what extent, the NOV and information request will result in monetary sanctions; however we believe that there is a reasonable possibility that these actions may result in monetary sanctions exceeding . 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 The Company is the plaintiff in two lawsuits against South Jersey Gas Company and South Jersey Resources Group, LLC (collectively, “SJGC”) pending in United States District Court in Colorado. In March 2015, the Company filed suit against SJGC 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 nearly identical long term gas contracts. Under those contracts, SJGC are long term purchasers of 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 and the appeal remains pending. Subsequent to the entry of judgment, 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. The second lawsuit remains pending. Through June 30, 2019, the Company estimates that it is owed approximately $88 million (gross damages, including interest) more than SJGC has paid using the indices unilaterally selected by them. Substantially all of this amount has not been accrued in the Company’s financial statements. The Company will vigorously seek recovery from SJGC of all underpayments and damages, including interest, based on the contracted price. 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 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. Through June 30, 2019, these damages amounted to approximately $ million (gross damages, including interest). This amount has not been accrued in the Company’s financial statements. 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 million from Antero. On June 20, 2019, the Company was awarded a jury verdict of approximately $95.9 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. WGL has the right to appeal 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 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 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	6 Months Ended
	Jun. 30, 2019
Contract Termination and Rig Stacking
Contract Termination and Rig Stacking	(15) Contract Termination and Rig Stacking During the three and six months ended June 30, 2019, the Company incurred $6 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	6 Months Ended
	Jun. 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	6 Months Ended
	Jun. 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 June 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated Three months ended June 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 823,734 ​ 160,092 ​ 5,518 ​ — 989,344 ​ Intersegment ​ 5,179 ​ — ​ 245,457 ​ (250,636) — ​ Total ​ $ 828,913 160,092 250,975 (250,636) 989,344 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 32,312 ​ — ​ 62,218 ​ (64,366) ​ 30,164 ​ Gathering, compression, processing, and transportation ​ ​ 409,708 ​ — ​ 12,400 ​ (114,322) 307,786 ​ Impairment of oil and gas properties ​ ​ 134,437 ​ — ​ — ​ — ​ 134,437 ​ Impairment of gathering systems and facilities ​ ​ — ​ — ​ 8,501 ​ — ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 201,393 ​ — ​ 36,657 ​ — 238,050 ​ General and administrative ​ ​ 46,662 ​ — ​ 15,494 ​ (469) ​ 61,687 ​ Other ​ ​ 27,023 ​ 213,420 ​ 4,986 ​ (3,947) ​ 241,482 ​ Total ​ ​ 851,535 ​ 213,420 ​ 140,256 ​ (183,104) ​ 1,022,107 ​ Operating income (loss) ​ $ (22,622) (53,328) 110,719 (67,532) ​ (32,763) ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 9,264 ​ — ​ 9,264 ​ Segment assets ​ $ 13,381,044 ​ 61,684 ​ 3,293,101 ​ (1,045,222) ​ 15,690,607 ​ Capital expenditures for segment assets ​ $ 506,055 ​ — ​ 130,925 ​ (73,919) ​ 563,061 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Three months ended June 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,234,824 ​ 63,080 ​ 46 ​ — 1,297,950 ​ Intersegment ​ 1,760 ​ — ​ 255,572 ​ (255,618) 1,714 ​ Total ​ $ 1,236,584 63,080 255,618 (255,618) 1,299,664 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 40,857 ​ — ​ 50,549 ​ (50,549) ​ 40,857 ​ Gathering, compression, processing, and transportation ​ ​ 566,834 ​ — ​ 12,311 ​ (12,311) 566,834 ​ Impairment of oil and gas properties ​ ​ 130,999 ​ — ​ — ​ — ​ 130,999 ​ Impairment of gathering systems and facilities ​ ​ — ​ — ​ 594 ​ (594) ​ — ​ Depletion, depreciation, and amortization ​ ​ 242,302 ​ — ​ 36,447 ​ (36,447) 242,302 ​ General and administrative ​ ​ 42,382 ​ — ​ 34,622 ​ (34,622) ​ 42,382 ​ Other ​ ​ 38,755 ​ 137,539 ​ 3,504 ​ (3,504) ​ 176,294 ​ Total ​ ​ 1,062,129 ​ 137,539 ​ 138,027 ​ (138,027) ​ 1,199,668 ​ Operating income (loss) ​ $ 174,455 (74,459) 117,591 (117,591) ​ 99,996 ​ Equity in earnings of unconsolidated affiliates ​ $ 13,585 ​ — ​ 13,623 ​ (13,623) ​ 13,585 ​ Investments in unconsolidated affiliates ​ $ 1,967,203 ​ — ​ 1,186,161 ​ (1,186,161) ​ 1,967,203 ​ Segment assets ​ $ 17,305,519 ​ 25,361 ​ 6,769,009 ​ (6,769,009) ​ 17,330,880 ​ Capital expenditures for segment assets ​ $ 342,253 ​ — ​ 125,185 ​ (125,185) ​ 342,253 ​ ​ The operating results and assets of the Company’s reportable segments were as follows for the six months ended June 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated ​ Six months ended June 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,608,277 ​ 398,715 ​ 10,453 ​ — 2,017,445 ​ Intersegment ​ 11,054 ​ — ​ 470,113 ​ (481,167) — ​ Total ​ $ 1,619,331 398,715 480,566 (481,167) 2,017,445 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 63,574 ​ — ​ 117,090 ​ (123,778) ​ 56,886 ​ Gathering, compression, processing, and transportation ​ ​ 794,053 ​ — ​ 23,768 ​ (218,097) 599,724 ​ Impairment of oil and gas properties ​ ​ 184,973 ​ — ​ — ​ — ​ 184,973 ​ Impairment of gathering systems and facilities ​ ​ — ​ — ​ 8,501 ​ — ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 396,981 ​ — ​ 69,313 ​ — 466,294 ​ General and administrative ​ ​ 93,082 ​ — ​ 29,949 ​ (1,314) ​ 121,717 ​ Other ​ ​ 54,371 ​ 409,159 ​ 9,910 ​ (7,821) ​ 465,619 ​ Total ​ ​ 1,587,034 ​ 409,159 ​ 258,531 ​ (351,010) ​ 1,903,714 ​ Operating income (loss) ​ $ 32,297 (10,444) 222,035 (130,157) ​ 113,731 ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 17,126 ​ — ​ 17,126 ​ Segment assets ​ $ 13,381,044 ​ 61,684 ​ 3,293,101 ​ (1,045,222) ​ 15,690,607 ​ Capital expenditures for segment assets ​ $ 978,822 ​ — ​ 264,880 ​ (134,678) ​ 1,109,024 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Six months ended June 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 2,176,459 ​ 154,266 ​ 50 ​ — 2,330,775 Intersegment ​ 3,518 ​ — ​ 309,676 ​ (306,898) 6,296 Total ​ $ 2,179,977 154,266 309,726 (306,898) 2,337,071 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 83,826 ​ — ​ 62,377 ​ (63,614) ​ 82,589 Gathering, compression, processing, and transportation ​ ​ 1,101,849 ​ — ​ 15,233 ​ (125,719) 991,363 Impairment of oil and gas properties ​ ​ 212,243 ​ — ​ — ​ — ​ 212,243 Impairment of gathering systems and facilities ​ ​ — ​ — ​ 7,576 ​ (594) ​ 6,982 Depletion, depreciation, and amortization ​ ​ 460,796 ​ — ​ 44,097 ​ (22,390) 482,503 General and administrative ​ ​ 92,290 ​ — ​ 54,431 ​ (36,137) ​ 110,584 Other ​ ​ 82,892 ​ 300,623 ​ 4,795 ​ (3,792) ​ 384,518 Total ​ ​ 2,033,896 ​ 300,623 ​ 188,509 ​ (252,246) ​ 2,270,782 Operating income (loss) ​ $ 146,081 (146,357) 121,217 (54,652) ​ 66,289 Equity in earnings of unconsolidated affiliates ​ $ 15,402 ​ — ​ 16,503 ​ (4,239) ​ 27,666 Investments in unconsolidated affiliates ​ $ 1,967,203 ​ — ​ 1,186,161 ​ (1,186,161) ​ 1,967,203 Segment assets ​ $ 17,305,519 ​ 25,361 ​ 6,769,009 ​ (6,769,009) ​ 17,330,880 Capital expenditures for segment assets ​ $ 761,034 ​ — ​ 141,190 ​ (88,038) ​ 814,186 ​

Subsidiary Guarantors

Subsidiary Guarantors	6 Months Ended
	Jun. 30, 2019
Subsidiary Guarantors
Subsidiary Guarantors	​ (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 which 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 June 30, 2019, and the related Condensed Consolidating Statements of Operations and Comprehensive Income (Loss) for the three and six months ended June 30, 2018 and 2019, and Condensed Consolidating Statements of Cash Flows for the six months ended June 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 ​ December 31, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 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 ​ June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Assets ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts receivable, net ​ $ 49,994 ​ ​ 200,337 ​ ​ — ​ ​ (200,337) ​ ​ 49,994 ​ Accrued revenue ​ ​ 308,761 ​ ​ — ​ ​ — ​ ​ — ​ ​ 308,761 ​ Derivative instruments ​ ​ 346,894 ​ ​ — ​ ​ — ​ ​ — ​ ​ 346,894 ​ Other current assets ​ ​ 7,400 ​ ​ — ​ ​ — ​ ​ — ​ ​ 7,400 ​ Total current assets ​ ​ 713,049 ​ ​ 200,337 ​ ​ — ​ ​ (200,337) ​ ​ 713,049 ​ Property and equipment: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil and gas properties, at cost (successful efforts method): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Unproved properties ​ ​ 1,585,355 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,585,355 ​ Proved properties ​ ​ 13,357,733 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,357,733 ​ Gathering systems and facilities ​ ​ 17,825 ​ ​ — ​ ​ — ​ ​ — ​ ​ 17,825 ​ Other property and equipment ​ ​ 69,676 ​ ​ — ​ ​ — ​ ​ — ​ ​ 69,676 ​ ​ ​ ​ 15,030,589 ​ ​ — ​ ​ — ​ ​ — ​ ​ 15,030,589 ​ Less accumulated depletion, depreciation, and amortization ​ ​ (4,115,187) ​ ​ — ​ ​ — ​ ​ — ​ ​ (4,115,187) ​ Property and equipment, net ​ ​ 10,915,402 ​ ​ — ​ ​ — ​ ​ — ​ ​ 10,915,402 ​ Operating leases right-of-use assets ​ ​ 3,330,795 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,330,795 ​ Derivative instruments ​ ​ 369,548 ​ ​ — ​ ​ — ​ ​ — ​ ​ 369,548 ​ Investments in unconsolidated affiliates ​ ​ 625,423 ​ ​ 1,341,780 ​ ​ — ​ ​ — ​ ​ 1,967,203 ​ Investments in consolidated affiliates ​ ​ 1,341,780 ​ ​ — ​ ​ — ​ ​ (1,341,780) ​ ​ — ​ Other assets ​ ​ 34,883 ​ ​ — ​ ​ — ​ ​ — ​ ​ 34,883 ​ Total assets ​ $ 17,330,880 ​ ​ 1,542,117 ​ ​ — ​ ​ (1,542,117) ​ ​ 17,330,880 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liabilities and Equity ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts payable ​ $ 44,758 ​ ​ — ​ ​ — ​ ​ — ​ ​ 44,758 ​ Accounts payable, related parties ​ ​ 298,907 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 98,570 ​ Accrued liabilities ​ ​ 358,680 ​ ​ — ​ ​ — ​ ​ — ​ ​ 358,680 ​ Revenue distributions payable ​ ​ 301,032 ​ ​ — ​ ​ — ​ ​ — ​ ​ 301,032 ​ Derivative instruments ​ ​ 274 ​ ​ — ​ ​ — ​ ​ — ​ ​ 274 ​ Short-term lease liabilities ​ ​ 413,691 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 413,691 ​ Other current liabilities ​ ​ 4,102 ​ ​ — ​ ​ — ​ ​ — ​ ​ 4,102 ​ Total current liabilities ​ ​ 1,421,444 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 1,221,107 ​ Long-term liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Long-term debt ​ ​ 3,602,379 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,602,379 ​ Deferred income tax liability ​ ​ 1,188,975 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,188,975 ​ Long-term lease liabilities ​ ​ 2,920,754 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 2,920,754 ​ Other liabilities ​ ​ 57,965 ​ ​ — ​ ​ — ​ ​ — ​ ​ 57,965 ​ Total liabilities ​ ​ 9,191,517 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 8,991,180 ​ Equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stockholders' equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Partners' capital ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Common stock ​ ​ 3,091 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,091 ​ Additional paid-in capital ​ ​ 6,138,130 ​ ​ 1,341,780 ​ ​ — ​ ​ (1,341,780) ​ ​ 6,138,130 ​ Accumulated earnings ​ ​ 1,998,142 ​ ​ 200,337 ​ ​ — ​ ​ — ​ ​ 2,198,479 ​ Total equity ​ ​ 8,139,363 ​ ​ 1,542,117 ​ ​ — ​ ​ (1,341,780) ​ ​ 8,339,700 ​ Total liabilities and equity ​ $ 17,330,880 ​ ​ 1,542,117 ​ ​ — ​ ​ (1,542,117) ​ ​ 17,330,880 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) ​ Three Months Ended June 30, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 473,540 ​ ​ — ​ ​ — ​ ​ — ​ ​ 473,540 ​ Natural gas liquids sales ​ 255,985 ​ — ​ — ​ — ​ 255,985 ​ Oil sales ​ ​ 38,873 ​ ​ — ​ ​ — ​ ​ — ​ ​ 38,873 ​ Commodity derivative fair value gains ​ ​ 55,336 ​ ​ — ​ ​ — ​ ​ — ​ ​ 55,336 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 250,392 ​ ​ (244,874) ​ ​ 5,518 ​ Marketing ​ ​ 160,202 ​ ​ — ​ ​ — ​ ​ — ​ ​ 160,202 ​ Marketing derivative fair value losses ​ ​ (110) ​ ​ — ​ ​ — ​ ​ — ​ ​ (110) ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ 583 ​ ​ (583) ​ ​ — ​ Other income ​ ​ 5,179 ​ ​ — ​ ​ — ​ ​ (5,179) ​ ​ — ​ Total revenue and other ​ ​ 989,005 ​ ​ — ​ ​ 250,975 ​ ​ (250,636) ​ ​ 989,344 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 32,312 ​ ​ — ​ ​ 62,218 ​ ​ (64,366) ​ ​ 30,164 ​ Gathering, compression, processing, and transportation ​ ​ 409,708 ​ ​ — ​ ​ 12,400 ​ ​ (114,322) ​ ​ 307,786 ​ Production and ad valorem taxes ​ ​ 24,886 ​ ​ — ​ ​ 1,005 ​ ​ — ​ ​ 25,891 ​ Marketing ​ ​ 213,420 ​ ​ — ​ ​ — ​ ​ — ​ ​ 213,420 ​ Exploration ​ ​ 1,471 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,471 ​ Impairment of oil and gas properties ​ ​ 134,437 ​ ​ — ​ ​ — ​ ​ — ​ ​ 134,437 ​ Impairment of gathering systems and facilities ​ ​ 4,470 ​ ​ — ​ ​ 4,614 ​ ​ (583) ​ ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 201,617 ​ ​ — ​ ​ 36,433 ​ ​ — ​ ​ 238,050 ​ Accretion of asset retirement obligations ​ ​ 666 ​ ​ — ​ ​ 34 ​ ​ — ​ ​ 700 ​ General and administrative ​ ​ 46,662 ​ ​ — ​ ​ 15,494 ​ ​ (469) ​ ​ 61,687 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 3,947 ​ ​ (3,947) ​ ​ — ​ Total operating expenses ​ ​ 1,069,649 ​ ​ — ​ ​ 136,145 ​ ​ (183,687) ​ ​ 1,022,107 ​ Operating income (loss) ​ ​ (80,644) ​ ​ — ​ ​ 114,830 ​ ​ (66,949) ​ ​ (32,763) ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 9,264 ​ ​ — ​ ​ 9,264 ​ Interest expense, net ​ ​ (54,388) ​ ​ — ​ ​ (14,628) ​ ​ (333) ​ ​ (69,349) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (26,926) ​ ​ — ​ ​ — ​ ​ 26,926 ​ ​ — ​ Total other expenses ​ ​ (81,314) ​ ​ — ​ ​ (5,364) ​ ​ 26,593 ​ ​ (60,085) ​ Income (loss) before income taxes ​ ​ (161,958) ​ ​ — ​ ​ 109,466 ​ ​ (40,356) ​ ​ (92,848) ​ Provision for income tax benefit ​ ​ 25,573 ​ ​ — ​ ​ — ​ ​ — ​ ​ 25,573 ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (136,385) ​ ​ — ​ ​ 109,466 ​ ​ (40,356) ​ ​ (67,275) ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 69,110 ​ ​ 69,110 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (136,385) ​ ​ — ​ ​ 109,466 ​ ​ (109,466) ​ ​ (136,385) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) ​ Three Months Ended June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 553,372 ​ ​ — ​ ​ — ​ ​ — ​ ​ 553,372 ​ Natural gas liquids sales ​ 303,963 ​ — ​ — ​ — ​ 303,963 ​ Oil sales ​ ​ 49,062 ​ ​ — ​ ​ — ​ ​ — ​ ​ 49,062 ​ Commodity derivative fair value gains ​ ​ 328,427 ​ ​ — ​ ​ — ​ ​ — ​ ​ 328,427 ​ Marketing ​ ​ 63,080 ​ ​ — ​ ​ — ​ ​ — ​ ​ 63,080 ​ Other income ​ ​ 1,760 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,760 ​ Total revenue and other ​ ​ 1,299,664 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,299,664 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 40,857 ​ ​ — ​ ​ — ​ ​ — ​ ​ 40,857 ​ Gathering, compression, processing, and transportation ​ ​ 566,834 ​ ​ — ​ ​ — ​ ​ — ​ ​ 566,834 ​ Production and ad valorem taxes ​ ​ 30,968 ​ ​ — ​ ​ — ​ ​ — ​ ​ 30,968 ​ Marketing ​ ​ 137,539 ​ ​ — ​ ​ — ​ ​ — ​ ​ 137,539 ​ Exploration ​ ​ 314 ​ ​ — ​ ​ — ​ ​ — ​ ​ 314 ​ Impairment of oil and gas properties ​ ​ 130,999 ​ ​ — ​ ​ — ​ ​ — ​ ​ 130,999 ​ Depletion, depreciation, and amortization ​ ​ 242,302 ​ ​ — ​ ​ — ​ ​ — ​ ​ 242,302 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Accretion of asset retirement obligations ​ ​ 918 ​ ​ — ​ ​ — ​ ​ — ​ ​ 918 ​ General and administrative ​ ​ 42,382 ​ ​ — ​ ​ — ​ ​ — ​ ​ 42,382 ​ Contract termination and rig stacking ​ ​ 5,604 ​ ​ — ​ ​ — ​ ​ — ​ ​ 5,604 ​ Total operating expenses ​ ​ 1,199,668 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,199,668 ​ Operating income ​ ​ 99,996 ​ ​ — ​ ​ — ​ ​ — ​ ​ 99,996 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ 13,585 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,585 ​ Interest expense, net ​ ​ (54,164) ​ ​ — ​ ​ — ​ ​ — ​ ​ (54,164) ​ Total other expenses ​ ​ (40,579) ​ ​ — ​ ​ — ​ ​ — ​ ​ (40,579) ​ Income (loss) before income taxes ​ ​ 59,417 ​ ​ — ​ ​ — ​ ​ — ​ ​ 59,417 ​ Provision for income tax expense ​ ​ (17,249) ​ ​ — ​ ​ — ​ ​ — ​ ​ (17,249) ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ 42,168 ​ ​ — ​ ​ — ​ ​ — ​ ​ 42,168 ​ Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ 42,168 ​ ​ — ​ ​ — ​ ​ — ​ ​ 42,168 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) ​ Six Months Ended June 30, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 971,203 ​ ​ — ​ ​ — ​ ​ — ​ ​ 971,203 ​ Natural gas liquids sales ​ 490,155 ​ — ​ — ​ — ​ 490,155 ​ Oil sales ​ ​ 69,146 ​ ​ — ​ ​ — ​ ​ — ​ ​ 69,146 ​ Commodity derivative fair value gains ​ ​ 77,773 ​ ​ — ​ ​ — ​ ​ — ​ ​ 77,773 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 479,983 ​ ​ (469,530) ​ ​ 10,453 ​ Marketing ​ ​ 304,591 ​ ​ — ​ ​ — ​ ​ — ​ ​ 304,591 ​ Marketing derivative fair value gains ​ ​ 94,124 ​ ​ — ​ ​ — ​ ​ — ​ ​ 94,124 ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ 583 ​ ​ (583) ​ ​ — ​ Other income ​ ​ 11,054 ​ ​ — ​ ​ — ​ ​ (11,054) ​ ​ — ​ Total revenue and other ​ ​ 2,018,046 ​ ​ — ​ ​ 480,566 ​ ​ (481,167) ​ ​ 2,017,445 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 63,574 ​ ​ — ​ ​ 117,090 ​ ​ (123,778) ​ ​ 56,886 ​ Gathering, compression, processing, and transportation ​ ​ 794,053 ​ ​ — ​ ​ 23,768 ​ ​ (218,097) ​ ​ 599,724 ​ Production and ad valorem taxes ​ ​ 49,693 ​ ​ — ​ ​ 2,021 ​ ​ — ​ ​ 51,714 ​ Marketing ​ ​ 409,159 ​ ​ — ​ ​ — ​ ​ — ​ ​ 409,159 ​ Exploration ​ ​ 3,356 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,356 ​ Impairment of oil and gas properties ​ ​ 184,973 ​ ​ — ​ ​ — ​ ​ — ​ ​ 184,973 ​ Impairment of gathering systems and facilities ​ ​ 4,470 ​ ​ — ​ ​ 4,614 ​ ​ (583) ​ ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 397,429 ​ ​ — ​ ​ 68,865 ​ ​ — ​ ​ 466,294 ​ Accretion of asset retirement obligations ​ ​ 1,322 ​ ​ — ​ ​ 68 ​ ​ — ​ ​ 1,390 ​ General and administrative ​ ​ 93,082 ​ ​ — ​ ​ 29,949 ​ ​ (1,314) ​ ​ 121,717 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 7,821 ​ ​ (7,821) ​ ​ — ​ Total operating expenses ​ ​ 2,001,111 ​ ​ — ​ ​ 254,196 ​ ​ (351,593) ​ ​ 1,903,714 ​ Operating income ​ ​ 16,935 ​ ​ — ​ ​ 226,370 ​ ​ (129,574) ​ ​ 113,731 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 17,126 ​ ​ — ​ ​ 17,126 ​ Interest expense, net ​ ​ (107,886) ​ ​ — ​ ​ (25,925) ​ ​ 36 ​ ​ (133,775) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (47,054) ​ ​ — ​ ​ — ​ ​ 47,054 ​ ​ — ​ Total other expenses ​ ​ (154,940) ​ ​ — ​ ​ (8,799) ​ ​ 47,090 ​ ​ (116,649) ​ Income (loss) before income taxes ​ ​ (138,005) ​ ​ — ​ ​ 217,571 ​ ​ (82,484) ​ ​ (2,918) ​ Provision for income tax benefit ​ ​ 16,453 ​ ​ — ​ ​ — ​ ​ — ​ ​ 16,453 ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (121,552) ​ ​ — ​ ​ 217,571 ​ ​ (82,484) ​ ​ 13,535 ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 135,087 ​ ​ 135,087 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (121,552) ​ ​ — ​ ​ 217,571 ​ ​ (217,571) ​ ​ (121,552) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income ​ Six Months Ended June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 1,210,638 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,210,638 ​ Natural gas liquids sales ​ 617,648 ​ — ​ — ​ — ​ 617,648 ​ Oil sales ​ ​ 97,114 ​ ​ — ​ ​ — ​ ​ — ​ ​ 97,114 ​ Commodity derivative fair value gains ​ ​ 251,059 ​ ​ — ​ ​ — ​ ​ — ​ ​ 251,059 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 218,360 ​ ​ (213,881) ​ ​ 4,479 ​ Marketing ​ ​ 154,266 ​ ​ — ​ ​ — ​ ​ — ​ ​ 154,266 ​ Other income ​ ​ 3,518 ​ ​ — ​ ​ — ​ ​ (1,651) ​ ​ 1,867 ​ Total revenue and other ​ ​ 2,334,243 ​ ​ — ​ ​ 218,360 ​ ​ (215,532) ​ ​ 2,337,071 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 83,826 ​ ​ — ​ ​ 64,818 ​ ​ (66,055) ​ ​ 82,589 ​ Gathering, compression, processing, and transportation ​ ​ 1,101,849 ​ ​ — ​ ​ — ​ ​ (110,486) ​ ​ 991,363 ​ Production and ad valorem taxes ​ ​ 65,706 ​ ​ — ​ ​ — ​ ​ 940 ​ ​ 66,646 ​ Marketing ​ ​ 300,623 ​ ​ — ​ ​ — ​ ​ — ​ ​ 300,623 ​ Exploration ​ ​ 440 ​ ​ — ​ ​ — ​ ​ — ​ ​ 440 ​ Impairment of oil and gas properties ​ ​ 212,243 ​ ​ — ​ ​ — ​ ​ — ​ ​ 212,243 ​ Impairment of gathering systems and facilities ​ ​ — ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 6,982 ​ Depletion, depreciation, and amortization ​ ​ 460,796 ​ ​ — ​ ​ 21,707 ​ ​ — ​ ​ 482,503 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Accretion of asset retirement obligations ​ ​ 1,831 ​ ​ — ​ ​ 63 ​ ​ — ​ ​ 1,894 ​ General and administrative ​ ​ 92,290 ​ ​ — ​ ​ 18,793 ​ ​ (499) ​ ​ 110,584 ​ Contract termination and rig stacking ​ ​ 13,964 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,964 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 1,928 ​ ​ (1,928) ​ ​ — ​ Total operating expenses ​ ​ 2,334,519 ​ ​ — ​ ​ 114,291 ​ ​ (178,028) ​ ​ 2,270,782 ​ Operating income (loss) ​ ​ (276) ​ ​ — ​ ​ 104,069 ​ ​ (37,504) ​ ​ 66,289 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ 4,999 ​ ​ 10,403 ​ ​ 12,264 ​ ​ — ​ ​ 27,666 ​ Interest expense, net ​ ​ (109,299) ​ ​ — ​ ​ (16,815) ​ ​ — ​ ​ (126,114) ​ 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) ​ ​ 1,116,426 ​ ​ 210,740 ​ ​ (4,551) ​ ​ (15,021) ​ ​ 1,307,594 ​ Income before income taxes ​ ​ 1,116,150 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 1,373,883 ​ Provision for income tax expense ​ ​ (305,959) ​ ​ — ​ ​ — ​ ​ — ​ ​ (305,959) ​ Net income and comprehensive income including noncontrolling interests ​ ​ 810,191 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 1,067,924 ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 46,993 ​ ​ 46,993 ​ Net income and comprehensive income attributable to Antero Resources Corporation ​ $ 810,191 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (99,518) ​ ​ 1,020,931 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Cash Flows ​ Six Months Ended June 30, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Cash flows provided by (used in) operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net income (loss) including noncontrolling interests ​ $ (121,552) ​ ​ — ​ ​ 217,571 ​ ​ (82,484) ​ ​ 13,535 ​ Adjustment to reconcile net income (loss) to net cash provided by operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depletion, depreciation, amortization, and accretion ​ ​ 398,751 ​ ​ — ​ ​ 68,933 ​ ​ — ​ ​ 467,684 ​ Accretion of contingent acquisition consideration ​ ​ (7,821) ​ ​ — ​ ​ 7,821 ​ ​ — ​ ​ — ​ Impairment of oil and gas properties ​ ​ 184,973 ​ ​ — ​ ​ — ​ ​ — ​ ​ 184,973 ​ Impairment of gathering systems and facilities ​ ​ 4,470 ​ ​ — ​ ​ 4,614 ​ ​ (583) ​ ​ 8,501 ​ Commodity derivative fair value gains ​ ​ (77,773) ​ ​ — ​ ​ — ​ ​ — ​ ​ (77,773) ​ Gains on settled commodity derivatives ​ ​ 197,225 ​ ​ — ​ ​ — ​ ​ — ​ ​ 197,225 ​ Marketing derivative fair value gains ​ ​ (94,124) ​ ​ — ​ ​ — ​ ​ — ​ ​ (94,124) ​ Gains on settled marketing derivatives ​ ​ 94,158 ​ ​ — ​ ​ — ​ ​ — ​ ​ 94,158 ​ Deferred income tax benefit ​ ​ (16,453) ​ ​ — ​ ​ — ​ ​ — ​ ​ (16,453) ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ (583) ​ ​ 583 ​ ​ — ​ Equity-based compensation expense ​ ​ 28,149 ​ ​ — ​ ​ 12,078 ​ ​ — ​ ​ 40,227 ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ 47,054 ​ ​ — ​ ​ — ​ ​ (47,054) ​ ​ — ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (17,126) ​ ​ — ​ ​ (17,126) ​ Distributions of earnings from unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 17,895 ​ ​ — ​ ​ 17,895 ​ Distributions from Antero Midstream Partners LP ​ ​ 74,647 ​ ​ — ​ ​ — ​ ​ (74,647) ​ ​ — ​ Other ​ ​ 547 ​ ​ — ​ ​ 1,385 ​ ​ — ​ ​ 1,932 ​ Changes in current assets and liabilities ​ ​ 14,510 ​ ​ — ​ ​ (157) ​ ​ 3,933 ​ ​ 18,286 ​ Net cash provided by operating activities ​ ​ 726,761 ​ ​ — ​ ​ 312,431 ​ ​ (200,252) ​ ​ 838,940 ​ Cash flows provided by (used in) investing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Additions to unproved properties ​ ​ (87,861) ​ ​ — ​ ​ — ​ ​ — ​ ​ (87,861) ​ Drilling and completion costs ​ ​ (887,459) ​ ​ — ​ ​ — ​ ​ 134,678 ​ ​ (752,781) ​ Additions to water handling and treatment systems ​ ​ — ​ ​ — ​ ​ (49,054) ​ ​ (9,073) ​ ​ (58,127) ​ Additions to gathering systems and facilities ​ ​ — ​ ​ — ​ ​ (206,753) ​ ​ — ​ ​ (206,753) ​ Additions to other property and equipment ​ ​ (3,502) ​ ​ — ​ ​ — ​ ​ — ​ ​ (3,502) ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (56,297) ​ ​ — ​ ​ (56,297) ​ Change in other assets ​ ​ 2,051 ​ ​ — ​ ​ (9,077) ​ ​ — ​ ​ (7,026) ​ Net cash used in investing activities ​ ​ (976,771) ​ ​ — ​ ​ (321,181) ​ ​ 125,605 ​ ​ (1,172,347) ​ Cash flows provided by (used in) financing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Borrowings (repayments) on bank credit facility, net ​ ​ 270,000 ​ ​ — ​ ​ 215,000 ​ ​ — ​ ​ 485,000 ​ Distributions to noncontrolling interests in Antero Midstream Partners LP ​ ​ — ​ ​ — ​ ​ (193,670) ​ ​ 74,647 ​ ​ (119,023) ​ Employee tax withholding for settlement of equity compensation awards ​ ​ (6,649) ​ ​ — ​ ​ (1,318) ​ ​ — ​ ​ (7,967) ​ Other ​ ​ (2,336) ​ ​ — ​ ​ (100) ​ ​ — ​ ​ (2,436) ​ Net cash provided by financing activities ​ ​ 261,015 ​ ​ — ​ ​ 19,912 ​ ​ 74,647 ​ ​ 355,574 ​ Net increase in cash and cash equivalents ​ ​ 11,005 ​ ​ — ​ ​ 11,162 ​ ​ — ​ ​ 22,167 ​ Cash and cash equivalents, beginning of period ​ ​ 20,078 ​ ​ — ​ ​ 8,363 ​ ​ — ​ ​ 28,441 ​ Cash and cash equivalents, end of period ​ $ 31,083 ​ ​ — ​ ​ 19,525 ​ ​ — ​ ​ 50,608 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Cash Flows ​ Six Months Ended June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Cash flows provided by (used in) operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net income including noncontrolling interests ​ $ 810,191 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 1,067,924 ​ Adjustment to reconcile net income to net cash provided by operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depletion, depreciation, amortization, and accretion ​ ​ 462,627 ​ ​ — ​ ​ 21,770 ​ ​ — ​ ​ 484,397 ​ Impairment of oil and gas properties ​ ​ 212,243 ​ ​ — ​ ​ — ​ ​ — ​ ​ 212,243 ​ Impairment of gathering systems and facilities ​ ​ — ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 6,982 ​ Commodity derivative fair value gains ​ ​ (251,059) ​ ​ — ​ ​ — ​ ​ — ​ ​ (251,059) ​ Gains on settled commodity derivatives ​ ​ 141,791 ​ ​ — ​ ​ — ​ ​ — ​ ​ 141,791 ​ Deferred income tax expense ​ ​ 304,963 ​ ​ — ​ ​ — ​ ​ — ​ ​ 304,963 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Equity-based compensation expense ​ ​ 12,975 ​ ​ — ​ ​ 2,477 ​ ​ — ​ ​ 15,452 ​ Equity in earnings of affiliates ​ ​ (15,021) ​ ​ — ​ ​ — ​ ​ 15,021 ​ ​ — ​ Equity in earnings of unconsolidated affiliates ​ ​ (4,999) ​ ​ (10,403) ​ ​ (12,264) ​ ​ — ​ ​ (27,666) ​ Distributions/dividends of earnings from unconsolidated affiliates ​ ​ 47,922 ​ ​ — ​ ​ 12,605 ​ ​ — ​ ​ 60,527 ​ 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 ​ ​ (43,002) ​ ​ — ​ ​ 750 ​ ​ 47,922 ​ ​ 5,670 ​ Changes in current assets and liabilities ​ ​ 134,740 ​ ​ — ​ ​ (10,573) ​ ​ 16,808 ​ ​ 140,975 ​ Net cash provided by operating activities ​ ​ 703,008 ​ ​ — ​ ​ 121,265 ​ ​ (67,165) ​ ​ 757,108 ​ Cash flows provided by (used in) investing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Additions to unproved properties ​ ​ (56,814) ​ ​ — ​ ​ — ​ ​ — ​ ​ (56,814) ​ Drilling and completion costs ​ ​ (700,653) ​ ​ — ​ ​ — ​ ​ 20,565 ​ ​ (680,088) ​ 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 ​ ​ (3,567) ​ ​ — ​ ​ (1,062) ​ ​ — ​ ​ (4,629) ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (25,020) ​ ​ — ​ ​ (25,020) ​ Proceeds from the Antero Midstream Partners LP Transactions ​ ​ 296,611 ​ ​ — ​ ​ — ​ ​ — ​ ​ 296,611 ​ Change in other assets ​ ​ (1,617) ​ ​ — ​ ​ (3,357) ​ ​ — ​ ​ (4,974) ​ Proceeds from sale of assets ​ ​ 1,983 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,983 ​ Net cash used in investing activities ​ ​ (464,057) ​ ​ — ​ ​ (102,225) ​ ​ 20,696 ​ ​ (545,586) ​ Cash flows provided by (used in) financing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Issuance of senior notes ​ ​ — ​ ​ — ​ ​ 650,000 ​ ​ — ​ ​ 650,000 ​ Borrowings (repayments) on bank credit facility, net ​ ​ (235,379) ​ ​ — ​ ​ 90,379 ​ ​ — ​ ​ (145,000) ​ 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 ​ ​ (2,266) ​ ​ — ​ ​ (29) ​ ​ — ​ ​ (2,295) ​ Other ​ ​ (515) ​ ​ — ​ ​ (845) ​ ​ — ​ ​ (1,360) ​ Net cash provided by (used in) financing activities ​ ​ (238,951) ​ ​ — ​ ​ 600,492 ​ ​ 46,469 ​ ​ 408,010 ​ 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_2

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 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 June 30, 2019, and the results of its operations and its cash flows for the three and six months ended June 30, 2018 and 2019. The Company has 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 June 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 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 a 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, the Company 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 which 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 June 30, 2019, the book overdraft included within accounts payable and revenue distributions payable were million, respectively. As of December 31, 2018, the book overdraft included within accounts payable and revenue distributions payable were
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 30, 2018 and 2019. During the six months ended June 30, 2019, we recorded an impairment charge of 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 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, anticipated capital expenditures, and a commensurate discount rate. The Company did not record any impairment expenses associated with its proved properties during the six months ended June 30, 2018 and 2019.
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 resell the Company’s production to third parties located in foreign countries. 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. 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 June 30, ​ Six months ended June 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Basic weighted average number of shares outstanding ​ 316,992 ​ 309,062 ​ 316,733 ​ 308,879 ​ Add: Dilutive effect of restricted stock units ​ — ​ 33 ​ — ​ 48 ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ — ​ — ​ Add: Dilutive effect of performance stock units ​ — ​ 42 ​ — ​ 155 ​ Diluted weighted average number of shares outstanding ​ 316,992 ​ 309,137 ​ 316,733 ​ 309,082 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding equity awards excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ ​ ​ ​ ​ Restricted stock units ​ 2,899 ​ 2,284 ​ 3,088 ​ 1,877 ​ Outstanding stock options ​ 639 ​ 538 ​ 646 ​ 554 ​ Performance stock units ​ 1,860 ​ 2,592 ​ 1,556 ​ 1,996 ​ (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.
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 issued, 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 and implemented new lease software 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)	6 Months Ended
	Jun. 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 June 30, ​ Six months ended June 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Basic weighted average number of shares outstanding ​ 316,992 ​ 309,062 ​ 316,733 ​ 308,879 ​ Add: Dilutive effect of restricted stock units ​ — ​ 33 ​ — ​ 48 ​ Add: Dilutive effect of outstanding stock options ​ — ​ — ​ — ​ — ​ Add: Dilutive effect of performance stock units ​ — ​ 42 ​ — ​ 155 ​ Diluted weighted average number of shares outstanding ​ 316,992 ​ 309,137 ​ 316,733 ​ 309,082 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average number of outstanding equity awards excluded from calculation of diluted earnings per common share (1) ​ ​ ​ ​ ​ ​ ​ ​ ​ Restricted stock units ​ 2,899 ​ 2,284 ​ 3,088 ​ 1,877 ​ Outstanding stock options ​ 639 ​ 538 ​ 646 ​ 554 ​ Performance stock units ​ 1,860 ​ 2,592 ​ 1,556 ​ 1,996 ​ (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)	6 Months Ended
	Jun. 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)	6 Months Ended
	Jun. 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— ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended June 30, ​ Six months ended June 30, ​ Segment to which ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ revenues relate ​ Revenues from contracts with customers: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 473,540 ​ ​ 553,372 ​ $ 971,203 ​ ​ 1,210,638 ​ Exploration and production ​ Natural gas liquids sales (ethane) ​ ​ 32,687 ​ ​ 30,374 ​ ​ 59,762 ​ ​ 65,890 ​ Exploration and production ​ Natural gas liquids sales (C3+ NGLs) ​ ​ 223,298 ​ ​ 273,589 ​ ​ 430,393 ​ ​ 551,758 ​ Exploration and production ​ Oil sales ​ ​ 38,873 ​ ​ 49,062 ​ ​ 69,146 ​ ​ 97,114 ​ Exploration and production ​ Gathering and compression (1) ​ 4,263 ​ — ​ ​ 8,408 ​ 3,972 ​ Equity method investment in AMC ​ Water handling and treatment (1) ​ ​ 1,255 ​ ​ — ​ ​ 2,045 ​ ​ 507 ​ Equity method investment in AMC ​ Marketing ​ ​ 160,202 ​ ​ 63,080 ​ ​ 304,591 ​ ​ 154,266 ​ Marketing ​ Total ​ 934,118 ​ 969,477 ​ ​ 1,845,548 ​ 2,084,145 ​ ​ ​ Income from derivatives and other sources ​ ​ 55,226 ​ ​ 330,187 ​ ​ 171,897 ​ ​ 252,926 ​ ​ ​ Total revenue and other ​ $ 989,344 ​ ​ 1,299,664 ​ $ 2,017,445 ​ ​ 2,337,071 ​ ​ ​ (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)	6 Months Ended
	Jun. 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 six months ended June 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 ​ ​ 15,402 ​ ​ 27,666 ​ Distributions/dividends from unconsolidated affiliates ​ (3,000) ​ ​ (9,605) ​ ​ (47,922) ​ ​ (60,527) ​ Elimination of intercompany profit ​ ​ — ​ ​ — ​ ​ 11,928 ​ ​ 11,928 ​ Effects of deconsolidation (4) ​ (66,997) ​ ​ (391,324) ​ ​ 1,987,795 ​ ​ 1,529,474 ​ Balance at June 30, 2019 ​ $ — ​ ​ — ​ ​ 1,967,203 ​ ​ 1,967,203 ​ (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 six months ended June 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) ​ June 30, 2019 ​ Current assets ​ $ 115,367 ​ Noncurrent assets ​ ​ 6,653,642 ​ Total assets ​ $ 6,769,009 ​ ​ ​ ​ ​ ​ Current liabilities ​ $ 237,504 ​ Noncurrent liabilities ​ ​ 2,559,146 ​ Stockholders' equity ​ ​ 3,972,359 ​ Total liabilities and equity ​ $ 6,769,009 ​ ​ Statement of Operations ​ ​ ​ ​ ​ ​ ​ ​ For the period ​ ​ ​ ​ March 13, 2019 through ​ (in thousands) ​ June 30, 2019 ​ Revenues ​ $ 309,726 ​ Operating expenses ​ ​ 168,056 ​ Income from operations ​ $ 141,670 ​ Net income attributable to the equity method investments ​ $ 92,471 ​ ​

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2019
Accrued Liabilities
Schedule of accrued liabilities	Accrued liabilities as of December 31, 2018 and June 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 June 30, 2019 ​ Capital expenditures ​ $ 113,237 ​ 62,631 ​ Gathering, compression, processing, and transportation expenses ​ ​ 148,032 ​ ​ 147,797 ​ Marketing expenses ​ ​ 67,082 ​ ​ 47,018 ​ Interest expense, net ​ 43,444 ​ 31,599 ​ Other ​ 93,275 ​ 69,635 ​ ​ ​ $ 465,070 ​ 358,680 ​

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Long-Term Debt.
Schedule of long-term debt	Long-term debt was as follows at December 31, 2018 and June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 June 30, 2019 ​ Antero Resources: ​ ​ ​ ​ ​ ​ ​ Credit Facility (a) ​ $ 405,000 ​ 175,000 ​ 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 ​ 1,095 ​ Net unamortized debt issuance costs ​ ​ (26,700) ​ ​ (23,716) ​ 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) ​ ​ — ​ ​ ​ $ 5,461,688 ​ 3,602,379 ​ (1) At December 31, 2018, Antero Midstream Partners’ indebtedness was included in the consolidated financial statements of Antero. At June 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)	6 Months Ended
	Jun. 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 six months ended June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ Asset retirement obligations—December 31, 2018 ​ $ 58,979 ​ Obligations settled ​ ​ (153) ​ Obligations incurred ​ 807 ​ Revisions to prior estimates ​ ​ — ​ Accretion expense ​ 1,894 ​ Effect of deconsolidation of Antero Midstream Partners LP (1) ​ (7,518) ​ Asset retirement obligations—June 30, 2019 ​ $ 54,009 ​ (1) Effective March 13, 2019, Antero Midstream Partners is no longer consolidated in Antero’s results. ​

Equity-Based Compensation (Tabl

Equity-Based Compensation (Tables)	6 Months Ended
	Jun. 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 six months ended June 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended June 30, ​ Six months ended June 30, ​ ​ ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Restricted stock unit awards ​ $ 10,231 ​ ​ 2,624 ​ $ 23,675 ​ ​ 6,600 ​ Stock options ​ ​ 495 ​ ​ 45 ​ ​ 976 ​ ​ 389 ​ Performance share unit awards ​ ​ 3,490 ​ ​ 2,666 ​ ​ 6,001 ​ ​ 5,628 ​ Antero Midstream Partners phantom unit awards (1) ​ ​ 4,341 ​ ​ 949 ​ ​ 8,559 ​ ​ 2,075 ​ Equity awards issued to directors ​ ​ 514 ​ ​ 265 ​ ​ 1,016 ​ ​ 760 ​ Total expense ​ $ 19,071 ​ ​ 6,549 ​ $ 40,227 ​ ​ 15,452 ​ (1) Antero recognized compensation expense for equity awards granted under both the Plan and the AMP Plan because the awards under the AMP Plan are accounted for as if they are distributed by Antero Midstream Partners to Antero. Antero allocates a portion of equity-based compensation expense related to grants prior to the Transactions to Antero Midstream 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 Midstream 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 1,568,617 ​ $ 8.69 ​ ​ ​ ​ Vested (674,312) ​ $ 28.04 ​ ​ ​ ​ Forfeited (190,525) ​ $ 18.05 ​ ​ ​ ​ Total awarded and unvested—June 30, 2019 2,416,265 ​ $ 13.81 ​ $ 13,362 ​
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 (46,062) ​ $ 50.00 ​ ​ ​ ​ ​ ​ ​ Expired — ​ $ — ​ ​ ​ ​ ​ ​ ​ Outstanding at June 30, 2019 533,555 ​ $ 50.60 ​ 5.29 ​ $ — ​ Vested or expected to vest as of June 30, 2019 533,555 ​ $ 50.60 ​ 5.29 ​ $ — ​ Exercisable at June 30, 2019 533,555 ​ $ 50.60 ​ ​ 5.29 ​ $ — ​
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 (342,161) ​ $ 32.72 ​ Total awarded and unvested—June 30, 2019 2,809,572 ​ $ 16.95 ​
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 (317,651) ​ $ 14.06 ​ ​ ​ ​ Forfeited (18,906) ​ $ 13.86 ​ ​ ​ ​ Total awarded and unvested—June 30, 2019 732,343 ​ $ 14.82 ​ $ 8,393 ​ (1) Effective March 12, 2019, a ll outstanding units in the AMP Plan , whether vested or unvested, were assumed by Antero Midstream Corporation and converted into restricted stock units under the AMC Plan. ​

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments.
Schedule of outstanding commodity derivatives	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas MMBtu/day ​ ​ Oil ​ ​ Natural Gas ​ Weighted ​ Three months ending September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 755,000 ​ ​ — ​ ​ — ​ $ 3.32 ​ NYMEX-WTI($/Bbl) ​ — ​ ​ 5,000 ​ ​ — ​ ​ 61.83 ​ Argus Butane ARA ($/MT) ​ — ​ ​ — ​ ​ 242 ​ ​ 330.25 ​ Argus Butane FEI ($/MT) ​ — ​ ​ — ​ ​ 24 ​ ​ 370.00 ​ Argus Propane ARA ($/MT) ​ — ​ ​ — ​ ​ 484 ​ ​ 328.17 ​ Argus Propane FEI ($/MT) ​ — ​ ​ — ​ ​ 274 ​ ​ 383.41 ​ Total ​ 755,000 ​ ​ 5,000 ​ ​ 1,024 ​ ​ ​ ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 755,000 ​ ​ — ​ ​ ​ ​ $ 3.45 ​ NYMEX-WTI($/Bbl) ​ — ​ ​ 5,000 ​ ​ ​ ​ ​ 61.83 ​ Total ​ 755,000 ​ ​ 5,000 ​ ​ ​ ​ ​ ​ ​ Year ending December 31, 2020: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 2,227,500 ​ ​ — ​ ​ ​ ​ $ 2.87 ​ NYMEX-WTI($/Bbl) ​ — ​ ​ 5,000 ​ ​ ​ ​ ​ 59.03 ​ Total ​ 2,227,500 ​ ​ 5,000 ​ ​ ​ ​ ​ ​ ​ Year ending December 31, 2021: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,010,000 ​ ​ ​ ​ ​ ​ ​ $ 2.88 ​ Year ending December 31, 2022: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 850,000 ​ ​ ​ ​ ​ ​ ​ $ 3.00 ​ 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 TCO to NYMEX	As of June 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 were as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas ​ Hedged ​ ​ ​ MMBtu/day ​ differential ​ Year ending December 31, 2020: ​ 60,000 ​ $ 0.353 ​ Year ending December 31, 2021: ​ 40,000 ​ $ 0.414 ​ Year ending December 31, 2022: ​ 60,000 ​ $ 0.515 ​ Year ending December 31, 2023: ​ 50,000 ​ $ 0.525 ​ Year ending December 31, 2024: ​ 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.	​ ​ As of June 30, 2019, the Company’s fixed price natural gas collar positions from July 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 ​ Weighted average index price ​ ​ ​ MMBtu/day ​ Ceiling price ​ Floor price ​ Three months ending September 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,575,000 ​ $ 3.30 ​ $ 2.50 ​ Three months ending December 31, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ NYMEX ($/MMBtu) ​ 1,575,000 ​ $ 3.52 ​ $ 2.50 ​
Summary of the fair values of derivative instruments, which are not designated as hedges for accounting purposes	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ June 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 ​ $ 346,894 ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ 362,169 ​ Derivative instruments ​ ​ 369,548 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total asset derivatives ​ ​ ​ ​ 607,432 ​ ​ ​ ​ 716,442 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liability derivatives not designated as hedges for accounting purposes: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Commodity derivatives - current ​ Derivative instruments ​ ​ 532 ​ Derivative instruments ​ ​ 274 ​ Commodity derivatives - noncurrent ​ Derivative instruments ​ ​ — ​ Derivative instruments ​ ​ — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Total liability derivatives ​ ​ ​ ​ 532 ​ ​ ​ ​ 274 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net derivatives ​ ​ ​ $ 606,900 ​ ​ ​ $ 716,168 ​
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 ​ June 30, 2019 ​ ​ ​ Gross ​ Gross amounts ​ Net amounts ​ Gross ​ Gross amounts ​ Net amounts Commodity derivative assets ​ $ 658,830 ​ (51,398) ​ 607,432 ​ $ 729,664 ​ (13,222) ​ 716,442 ​ Commodity derivative liabilities ​ $ (51,930) ​ 51,398 ​ (532) ​ $ (13,496) ​ 13,222 ​ (274) ​
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 June 30, ​ Six months ended June 30, ​ ​ ​ location ​ 2018 ​ 2019 ​ 2018 ​ 2019 ​ Commodity derivative fair value gains ​ Revenue ​ $ 55,336 ​ ​ 328,427 ​ ​ 77,773 ​ ​ 251,059 ​ Marketing derivative fair value gains (losses) ​ Revenue ​ $ (110) ​ ​ — ​ ​ 94,124 ​ ​ — ​

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2019
Leases
Summary of supplemental balance sheet information related to leases	The Company’s lease assets as of June 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ June 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Right-of-use Assets: ​ ​ ​ ​ ​ ​ ​ Processing plants ​ $ 1,587,374 ​ ​ — ​ Drilling rigs and completion services ​ ​ 115,034 ​ ​ — ​ Gas gathering lines and compressor stations (1) ​ ​ 1,580,130 ​ ​ — ​ Office space ​ ​ 42,200 ​ ​ — ​ Vehicles ​ ​ 5,627 ​ ​ 2,819 ​ Other office and field equipment ​ ​ 430 ​ ​ 831 ​ Total right-of-use assets ​ $ 3,330,795 ​ ​ 3,650 (2) (1) Gas gathering lines and compressor stations leases includes $1.4 billion related to Antero Midstream Corporation. (2) Financing lease assets are recorded net of accumulated amortization of $9 million as of June 30, 2019. ​ The Company’s lease liabilities as of June 30, 2019 consisted of the following items (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ June 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Location on the balance sheet: ​ ​ ​ ​ ​ ​ ​ Short-term lease liabilities ​ $ 412,143 ​ ​ 1,548 ​ Long-term lease liabilities ​ ​ 2,918,652 ​ ​ 2,102 ​ Total lease liabilities ​ $ 3,330,795 ​ ​ 3,650 ​ ​
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 six months ended June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Statement of Operations Location ​ Three months ended June 30, 2019 ​ Six months ended June 30, 2019 ​ Gathering, compression, processing, and transportation ​ $ 218,542 ​ $ 406,389 ​ General and administrative ​ ​ 2,810 ​ ​ 5,536 ​ Contract termination and rig stacking ​ ​ 2,673 ​ ​ 10,692 ​ Total Lease Expense ​ $ 224,025 ​ $ 422,617 ​
Summary of supplemental cash flow information related to leases	The following is the Company’s supplemental cash flow information related to leases for the three months ended June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended June 30, 2019 ​ Six months ended June 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 ​ $ 207,244 ​ ​ — ​ $ 357,564 ​ ​ — ​ Investing cash out flows related to operating leases ​ ​ 46,532 ​ ​ — ​ ​ 98,898 ​ ​ — ​ Financing cash out flows related to financing leases ​ ​ — ​ ​ 873 ​ ​ — ​ ​ 1,664 ​ ​ ​ ​ 253,776 ​ ​ 873 ​ ​ 456,462 ​ ​ 1,664 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 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 June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2019 ​ $ 206,320 ​ ​ 99 ​ ​ 206,419 ​ 2020 ​ ​ 396,473 ​ ​ 869 ​ ​ 397,342 ​ 2021 ​ ​ 349,212 ​ ​ 1,294 ​ ​ 350,506 ​ 2022 ​ ​ 359,759 ​ ​ 1,388 ​ ​ 361,147 ​ 2023 ​ ​ 377,790 ​ ​ — ​ ​ 377,790 ​ 2024 ​ ​ 392,323 ​ ​ — ​ ​ 392,323 ​ Thereafter ​ ​ 1,248,918 ​ ​ — ​ ​ 1,248,918 ​ Total lease payments ​ ​ 3,330,795 ​ ​ 3,650 ​ ​ 3,334,445 ​ Less: imputed interest ​ ​ — ​ ​ — ​ ​ — ​ Total ​ $ 3,330,795 ​ ​ 3,650 ​ ​ 3,334,445 ​ ​ 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 June 30, 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ (in thousands) ​ Operating Leases ​ Financing Leases ​ Total ​ Remainder of 2019 ​ $ 206,320 ​ ​ 99 ​ ​ 206,419 ​ 2020 ​ ​ 396,473 ​ ​ 869 ​ ​ 397,342 ​ 2021 ​ ​ 349,212 ​ ​ 1,294 ​ ​ 350,506 ​ 2022 ​ ​ 359,759 ​ ​ 1,388 ​ ​ 361,147 ​ 2023 ​ ​ 377,790 ​ ​ — ​ ​ 377,790 ​ 2024 ​ ​ 392,323 ​ ​ — ​ ​ 392,323 ​ Thereafter ​ ​ 1,248,918 ​ ​ — ​ ​ 1,248,918 ​ Total lease payments ​ ​ 3,330,795 ​ ​ 3,650 ​ ​ 3,334,445 ​ Less: imputed interest ​ ​ — ​ ​ — ​ ​ — ​ Total ​ $ 3,330,795 ​ ​ 3,650 ​ ​ 3,334,445 ​ ​ 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	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ June 30, 2019 ​ ​ ​ Operating Leases ​ Finance Leases ​ Weighted-average remaining lease term: ​ ​ 8.5 years ​ ​ 2.2 years ​ Weighted-average discount rate: ​ ​ 6.0 % ​ 5.5 %

Commitments (Tables)

Commitments (Tables)	6 Months Ended
	Jun. 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 June 30, 2019 (in millions). ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Firm ​ Processing, ​ Land payment obligations ​ Leases, including imputed interest ​ ​ ​ (in millions) ​ (a) ​ (b) ​ (c) ​ (d) ​ Total ​ Remainder of 2019 ​ $ 558 ​ ​ 27 ​ ​ 8 ​ ​ 206 ​ ​ 799 ​ 2020 ​ ​ 1,122 ​ ​ 54 ​ ​ 6 ​ ​ 397 ​ ​ 1,579 ​ 2021 ​ ​ 1,098 ​ ​ 54 ​ ​ 3 ​ ​ 350 ​ ​ 1,505 ​ 2022 ​ ​ 1,045 ​ ​ 54 ​ ​ — ​ ​ 361 ​ ​ 1,460 ​ 2023 ​ ​ 1,033 ​ ​ 48 ​ ​ — ​ ​ 378 ​ ​ 1,459 ​ 2024 ​ ​ 993 ​ ​ 48 ​ ​ — ​ ​ 392 ​ ​ 1,433 ​ Thereafter ​ ​ 7,807 ​ ​ 64 ​ ​ — ​ ​ 1,250 ​ ​ 9,121 ​ Total ​ $ 13,656 ​ ​ 349 ​ ​ 17 ​ ​ 3,334 ​ ​ 17,356 ​

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 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 June 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated Three months ended June 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 823,734 ​ 160,092 ​ 5,518 ​ — 989,344 ​ Intersegment ​ 5,179 ​ — ​ 245,457 ​ (250,636) — ​ Total ​ $ 828,913 160,092 250,975 (250,636) 989,344 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 32,312 ​ — ​ 62,218 ​ (64,366) ​ 30,164 ​ Gathering, compression, processing, and transportation ​ ​ 409,708 ​ — ​ 12,400 ​ (114,322) 307,786 ​ Impairment of oil and gas properties ​ ​ 134,437 ​ — ​ — ​ — ​ 134,437 ​ Impairment of gathering systems and facilities ​ ​ — ​ — ​ 8,501 ​ — ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 201,393 ​ — ​ 36,657 ​ — 238,050 ​ General and administrative ​ ​ 46,662 ​ — ​ 15,494 ​ (469) ​ 61,687 ​ Other ​ ​ 27,023 ​ 213,420 ​ 4,986 ​ (3,947) ​ 241,482 ​ Total ​ ​ 851,535 ​ 213,420 ​ 140,256 ​ (183,104) ​ 1,022,107 ​ Operating income (loss) ​ $ (22,622) (53,328) 110,719 (67,532) ​ (32,763) ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 9,264 ​ — ​ 9,264 ​ Segment assets ​ $ 13,381,044 ​ 61,684 ​ 3,293,101 ​ (1,045,222) ​ 15,690,607 ​ Capital expenditures for segment assets ​ $ 506,055 ​ — ​ 130,925 ​ (73,919) ​ 563,061 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Three months ended June 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,234,824 ​ 63,080 ​ 46 ​ — 1,297,950 ​ Intersegment ​ 1,760 ​ — ​ 255,572 ​ (255,618) 1,714 ​ Total ​ $ 1,236,584 63,080 255,618 (255,618) 1,299,664 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 40,857 ​ — ​ 50,549 ​ (50,549) ​ 40,857 ​ Gathering, compression, processing, and transportation ​ ​ 566,834 ​ — ​ 12,311 ​ (12,311) 566,834 ​ Impairment of oil and gas properties ​ ​ 130,999 ​ — ​ — ​ — ​ 130,999 ​ Impairment of gathering systems and facilities ​ ​ — ​ — ​ 594 ​ (594) ​ — ​ Depletion, depreciation, and amortization ​ ​ 242,302 ​ — ​ 36,447 ​ (36,447) 242,302 ​ General and administrative ​ ​ 42,382 ​ — ​ 34,622 ​ (34,622) ​ 42,382 ​ Other ​ ​ 38,755 ​ 137,539 ​ 3,504 ​ (3,504) ​ 176,294 ​ Total ​ ​ 1,062,129 ​ 137,539 ​ 138,027 ​ (138,027) ​ 1,199,668 ​ Operating income (loss) ​ $ 174,455 (74,459) 117,591 (117,591) ​ 99,996 ​ Equity in earnings of unconsolidated affiliates ​ $ 13,585 ​ — ​ 13,623 ​ (13,623) ​ 13,585 ​ Investments in unconsolidated affiliates ​ $ 1,967,203 ​ — ​ 1,186,161 ​ (1,186,161) ​ 1,967,203 ​ Segment assets ​ $ 17,305,519 ​ 25,361 ​ 6,769,009 ​ (6,769,009) ​ 17,330,880 ​ Capital expenditures for segment assets ​ $ 342,253 ​ — ​ 125,185 ​ (125,185) ​ 342,253 ​ ​ The operating results and assets of the Company’s reportable segments were as follows for the six months ended June 30, 2018 and 2019 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Midstream Elimination of Consolidated ​ Six months ended June 30, 2018: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 1,608,277 ​ 398,715 ​ 10,453 ​ — 2,017,445 ​ Intersegment ​ 11,054 ​ — ​ 470,113 ​ (481,167) — ​ Total ​ $ 1,619,331 398,715 480,566 (481,167) 2,017,445 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 63,574 ​ — ​ 117,090 ​ (123,778) ​ 56,886 ​ Gathering, compression, processing, and transportation ​ ​ 794,053 ​ — ​ 23,768 ​ (218,097) 599,724 ​ Impairment of oil and gas properties ​ ​ 184,973 ​ — ​ — ​ — ​ 184,973 ​ Impairment of gathering systems and facilities ​ ​ — ​ — ​ 8,501 ​ — ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 396,981 ​ — ​ 69,313 ​ — 466,294 ​ General and administrative ​ ​ 93,082 ​ — ​ 29,949 ​ (1,314) ​ 121,717 ​ Other ​ ​ 54,371 ​ 409,159 ​ 9,910 ​ (7,821) ​ 465,619 ​ Total ​ ​ 1,587,034 ​ 409,159 ​ 258,531 ​ (351,010) ​ 1,903,714 ​ Operating income (loss) ​ $ 32,297 (10,444) 222,035 (130,157) ​ 113,731 ​ Equity in earnings of unconsolidated affiliates ​ $ — ​ — ​ 17,126 ​ — ​ 17,126 ​ Segment assets ​ $ 13,381,044 ​ 61,684 ​ 3,293,101 ​ (1,045,222) ​ 15,690,607 ​ Capital expenditures for segment assets ​ $ 978,822 ​ — ​ 264,880 ​ (134,678) ​ 1,109,024 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Exploration Marketing Equity Method Investment in Antero Midstream Corporation Elimination of intersegment transactions and unconsolidated affiliates Consolidated Six months ended June 30, 2019: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Sales and revenues: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Third-party ​ $ 2,176,459 ​ 154,266 ​ 50 ​ — 2,330,775 Intersegment ​ 3,518 ​ — ​ 309,676 ​ (306,898) 6,296 Total ​ $ 2,179,977 154,266 309,726 (306,898) 2,337,071 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ $ 83,826 ​ — ​ 62,377 ​ (63,614) ​ 82,589 Gathering, compression, processing, and transportation ​ ​ 1,101,849 ​ — ​ 15,233 ​ (125,719) 991,363 Impairment of oil and gas properties ​ ​ 212,243 ​ — ​ — ​ — ​ 212,243 Impairment of gathering systems and facilities ​ ​ — ​ — ​ 7,576 ​ (594) ​ 6,982 Depletion, depreciation, and amortization ​ ​ 460,796 ​ — ​ 44,097 ​ (22,390) 482,503 General and administrative ​ ​ 92,290 ​ — ​ 54,431 ​ (36,137) ​ 110,584 Other ​ ​ 82,892 ​ 300,623 ​ 4,795 ​ (3,792) ​ 384,518 Total ​ ​ 2,033,896 ​ 300,623 ​ 188,509 ​ (252,246) ​ 2,270,782 Operating income (loss) ​ $ 146,081 (146,357) 121,217 (54,652) ​ 66,289 Equity in earnings of unconsolidated affiliates ​ $ 15,402 ​ — ​ 16,503 ​ (4,239) ​ 27,666 Investments in unconsolidated affiliates ​ $ 1,967,203 ​ — ​ 1,186,161 ​ (1,186,161) ​ 1,967,203 Segment assets ​ $ 17,305,519 ​ 25,361 ​ 6,769,009 ​ (6,769,009) ​ 17,330,880 Capital expenditures for segment assets ​ $ 761,034 ​ — ​ 141,190 ​ (88,038) ​ 814,186 ​

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	6 Months Ended
	Jun. 30, 2019
Subsidiary Guarantors
Schedule of condensed consolidated balance sheets	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Balance Sheet ​ December 31, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 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 ​ June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Assets ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current assets: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts receivable, net ​ $ 49,994 ​ ​ 200,337 ​ ​ — ​ ​ (200,337) ​ ​ 49,994 ​ Accrued revenue ​ ​ 308,761 ​ ​ — ​ ​ — ​ ​ — ​ ​ 308,761 ​ Derivative instruments ​ ​ 346,894 ​ ​ — ​ ​ — ​ ​ — ​ ​ 346,894 ​ Other current assets ​ ​ 7,400 ​ ​ — ​ ​ — ​ ​ — ​ ​ 7,400 ​ Total current assets ​ ​ 713,049 ​ ​ 200,337 ​ ​ — ​ ​ (200,337) ​ ​ 713,049 ​ Property and equipment: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Oil and gas properties, at cost (successful efforts method): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Unproved properties ​ ​ 1,585,355 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,585,355 ​ Proved properties ​ ​ 13,357,733 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,357,733 ​ Gathering systems and facilities ​ ​ 17,825 ​ ​ — ​ ​ — ​ ​ — ​ ​ 17,825 ​ Other property and equipment ​ ​ 69,676 ​ ​ — ​ ​ — ​ ​ — ​ ​ 69,676 ​ ​ ​ ​ 15,030,589 ​ ​ — ​ ​ — ​ ​ — ​ ​ 15,030,589 ​ Less accumulated depletion, depreciation, and amortization ​ ​ (4,115,187) ​ ​ — ​ ​ — ​ ​ — ​ ​ (4,115,187) ​ Property and equipment, net ​ ​ 10,915,402 ​ ​ — ​ ​ — ​ ​ — ​ ​ 10,915,402 ​ Operating leases right-of-use assets ​ ​ 3,330,795 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,330,795 ​ Derivative instruments ​ ​ 369,548 ​ ​ — ​ ​ — ​ ​ — ​ ​ 369,548 ​ Investments in unconsolidated affiliates ​ ​ 625,423 ​ ​ 1,341,780 ​ ​ — ​ ​ — ​ ​ 1,967,203 ​ Investments in consolidated affiliates ​ ​ 1,341,780 ​ ​ — ​ ​ — ​ ​ (1,341,780) ​ ​ — ​ Other assets ​ ​ 34,883 ​ ​ — ​ ​ — ​ ​ — ​ ​ 34,883 ​ Total assets ​ $ 17,330,880 ​ ​ 1,542,117 ​ ​ — ​ ​ (1,542,117) ​ ​ 17,330,880 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Liabilities and Equity ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accounts payable ​ $ 44,758 ​ ​ — ​ ​ — ​ ​ — ​ ​ 44,758 ​ Accounts payable, related parties ​ ​ 298,907 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 98,570 ​ Accrued liabilities ​ ​ 358,680 ​ ​ — ​ ​ — ​ ​ — ​ ​ 358,680 ​ Revenue distributions payable ​ ​ 301,032 ​ ​ — ​ ​ — ​ ​ — ​ ​ 301,032 ​ Derivative instruments ​ ​ 274 ​ ​ — ​ ​ — ​ ​ — ​ ​ 274 ​ Short-term lease liabilities ​ ​ 413,691 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 413,691 ​ Other current liabilities ​ ​ 4,102 ​ ​ — ​ ​ — ​ ​ — ​ ​ 4,102 ​ Total current liabilities ​ ​ 1,421,444 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 1,221,107 ​ Long-term liabilities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Long-term debt ​ ​ 3,602,379 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,602,379 ​ Deferred income tax liability ​ ​ 1,188,975 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,188,975 ​ Long-term lease liabilities ​ ​ 2,920,754 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 2,920,754 ​ Other liabilities ​ ​ 57,965 ​ ​ — ​ ​ — ​ ​ — ​ ​ 57,965 ​ Total liabilities ​ ​ 9,191,517 ​ ​ — ​ ​ — ​ ​ (200,337) ​ ​ 8,991,180 ​ Equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Stockholders' equity: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Partners' capital ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Common stock ​ ​ 3,091 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,091 ​ Additional paid-in capital ​ ​ 6,138,130 ​ ​ 1,341,780 ​ ​ — ​ ​ (1,341,780) ​ ​ 6,138,130 ​ Accumulated earnings ​ ​ 1,998,142 ​ ​ 200,337 ​ ​ — ​ ​ — ​ ​ 2,198,479 ​ Total equity ​ ​ 8,139,363 ​ ​ 1,542,117 ​ ​ — ​ ​ (1,341,780) ​ ​ 8,339,700 ​ Total liabilities and equity ​ $ 17,330,880 ​ ​ 1,542,117 ​ ​ — ​ ​ (1,542,117) ​ ​ 17,330,880 ​
Schedule of condensed consolidated statement of operations and comprehensive income (loss)	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) ​ Three Months Ended June 30, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 473,540 ​ ​ — ​ ​ — ​ ​ — ​ ​ 473,540 ​ Natural gas liquids sales ​ 255,985 ​ — ​ — ​ — ​ 255,985 ​ Oil sales ​ ​ 38,873 ​ ​ — ​ ​ — ​ ​ — ​ ​ 38,873 ​ Commodity derivative fair value gains ​ ​ 55,336 ​ ​ — ​ ​ — ​ ​ — ​ ​ 55,336 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 250,392 ​ ​ (244,874) ​ ​ 5,518 ​ Marketing ​ ​ 160,202 ​ ​ — ​ ​ — ​ ​ — ​ ​ 160,202 ​ Marketing derivative fair value losses ​ ​ (110) ​ ​ — ​ ​ — ​ ​ — ​ ​ (110) ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ 583 ​ ​ (583) ​ ​ — ​ Other income ​ ​ 5,179 ​ ​ — ​ ​ — ​ ​ (5,179) ​ ​ — ​ Total revenue and other ​ ​ 989,005 ​ ​ — ​ ​ 250,975 ​ ​ (250,636) ​ ​ 989,344 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 32,312 ​ ​ — ​ ​ 62,218 ​ ​ (64,366) ​ ​ 30,164 ​ Gathering, compression, processing, and transportation ​ ​ 409,708 ​ ​ — ​ ​ 12,400 ​ ​ (114,322) ​ ​ 307,786 ​ Production and ad valorem taxes ​ ​ 24,886 ​ ​ — ​ ​ 1,005 ​ ​ — ​ ​ 25,891 ​ Marketing ​ ​ 213,420 ​ ​ — ​ ​ — ​ ​ — ​ ​ 213,420 ​ Exploration ​ ​ 1,471 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,471 ​ Impairment of oil and gas properties ​ ​ 134,437 ​ ​ — ​ ​ — ​ ​ — ​ ​ 134,437 ​ Impairment of gathering systems and facilities ​ ​ 4,470 ​ ​ — ​ ​ 4,614 ​ ​ (583) ​ ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 201,617 ​ ​ — ​ ​ 36,433 ​ ​ — ​ ​ 238,050 ​ Accretion of asset retirement obligations ​ ​ 666 ​ ​ — ​ ​ 34 ​ ​ — ​ ​ 700 ​ General and administrative ​ ​ 46,662 ​ ​ — ​ ​ 15,494 ​ ​ (469) ​ ​ 61,687 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 3,947 ​ ​ (3,947) ​ ​ — ​ Total operating expenses ​ ​ 1,069,649 ​ ​ — ​ ​ 136,145 ​ ​ (183,687) ​ ​ 1,022,107 ​ Operating income (loss) ​ ​ (80,644) ​ ​ — ​ ​ 114,830 ​ ​ (66,949) ​ ​ (32,763) ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 9,264 ​ ​ — ​ ​ 9,264 ​ Interest expense, net ​ ​ (54,388) ​ ​ — ​ ​ (14,628) ​ ​ (333) ​ ​ (69,349) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (26,926) ​ ​ — ​ ​ — ​ ​ 26,926 ​ ​ — ​ Total other expenses ​ ​ (81,314) ​ ​ — ​ ​ (5,364) ​ ​ 26,593 ​ ​ (60,085) ​ Income (loss) before income taxes ​ ​ (161,958) ​ ​ — ​ ​ 109,466 ​ ​ (40,356) ​ ​ (92,848) ​ Provision for income tax benefit ​ ​ 25,573 ​ ​ — ​ ​ — ​ ​ — ​ ​ 25,573 ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (136,385) ​ ​ — ​ ​ 109,466 ​ ​ (40,356) ​ ​ (67,275) ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 69,110 ​ ​ 69,110 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (136,385) ​ ​ — ​ ​ 109,466 ​ ​ (109,466) ​ ​ (136,385) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) ​ Three Months Ended June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 553,372 ​ ​ — ​ ​ — ​ ​ — ​ ​ 553,372 ​ Natural gas liquids sales ​ 303,963 ​ — ​ — ​ — ​ 303,963 ​ Oil sales ​ ​ 49,062 ​ ​ — ​ ​ — ​ ​ — ​ ​ 49,062 ​ Commodity derivative fair value gains ​ ​ 328,427 ​ ​ — ​ ​ — ​ ​ — ​ ​ 328,427 ​ Marketing ​ ​ 63,080 ​ ​ — ​ ​ — ​ ​ — ​ ​ 63,080 ​ Other income ​ ​ 1,760 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,760 ​ Total revenue and other ​ ​ 1,299,664 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,299,664 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 40,857 ​ ​ — ​ ​ — ​ ​ — ​ ​ 40,857 ​ Gathering, compression, processing, and transportation ​ ​ 566,834 ​ ​ — ​ ​ — ​ ​ — ​ ​ 566,834 ​ Production and ad valorem taxes ​ ​ 30,968 ​ ​ — ​ ​ — ​ ​ — ​ ​ 30,968 ​ Marketing ​ ​ 137,539 ​ ​ — ​ ​ — ​ ​ — ​ ​ 137,539 ​ Exploration ​ ​ 314 ​ ​ — ​ ​ — ​ ​ — ​ ​ 314 ​ Impairment of oil and gas properties ​ ​ 130,999 ​ ​ — ​ ​ — ​ ​ — ​ ​ 130,999 ​ Depletion, depreciation, and amortization ​ ​ 242,302 ​ ​ — ​ ​ — ​ ​ — ​ ​ 242,302 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Accretion of asset retirement obligations ​ ​ 918 ​ ​ — ​ ​ — ​ ​ — ​ ​ 918 ​ General and administrative ​ ​ 42,382 ​ ​ — ​ ​ — ​ ​ — ​ ​ 42,382 ​ Contract termination and rig stacking ​ ​ 5,604 ​ ​ — ​ ​ — ​ ​ — ​ ​ 5,604 ​ Total operating expenses ​ ​ 1,199,668 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,199,668 ​ Operating income ​ ​ 99,996 ​ ​ — ​ ​ — ​ ​ — ​ ​ 99,996 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ 13,585 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,585 ​ Interest expense, net ​ ​ (54,164) ​ ​ — ​ ​ — ​ ​ — ​ ​ (54,164) ​ Total other expenses ​ ​ (40,579) ​ ​ — ​ ​ — ​ ​ — ​ ​ (40,579) ​ Income (loss) before income taxes ​ ​ 59,417 ​ ​ — ​ ​ — ​ ​ — ​ ​ 59,417 ​ Provision for income tax expense ​ ​ (17,249) ​ ​ — ​ ​ — ​ ​ — ​ ​ (17,249) ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ 42,168 ​ ​ — ​ ​ — ​ ​ — ​ ​ 42,168 ​ Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ ​ — ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ 42,168 ​ ​ — ​ ​ — ​ ​ — ​ ​ 42,168 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income (Loss) ​ Six Months Ended June 30, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 971,203 ​ ​ — ​ ​ — ​ ​ — ​ ​ 971,203 ​ Natural gas liquids sales ​ 490,155 ​ — ​ — ​ — ​ 490,155 ​ Oil sales ​ ​ 69,146 ​ ​ — ​ ​ — ​ ​ — ​ ​ 69,146 ​ Commodity derivative fair value gains ​ ​ 77,773 ​ ​ — ​ ​ — ​ ​ — ​ ​ 77,773 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 479,983 ​ ​ (469,530) ​ ​ 10,453 ​ Marketing ​ ​ 304,591 ​ ​ — ​ ​ — ​ ​ — ​ ​ 304,591 ​ Marketing derivative fair value gains ​ ​ 94,124 ​ ​ — ​ ​ — ​ ​ — ​ ​ 94,124 ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ 583 ​ ​ (583) ​ ​ — ​ Other income ​ ​ 11,054 ​ ​ — ​ ​ — ​ ​ (11,054) ​ ​ — ​ Total revenue and other ​ ​ 2,018,046 ​ ​ — ​ ​ 480,566 ​ ​ (481,167) ​ ​ 2,017,445 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 63,574 ​ ​ — ​ ​ 117,090 ​ ​ (123,778) ​ ​ 56,886 ​ Gathering, compression, processing, and transportation ​ ​ 794,053 ​ ​ — ​ ​ 23,768 ​ ​ (218,097) ​ ​ 599,724 ​ Production and ad valorem taxes ​ ​ 49,693 ​ ​ — ​ ​ 2,021 ​ ​ — ​ ​ 51,714 ​ Marketing ​ ​ 409,159 ​ ​ — ​ ​ — ​ ​ — ​ ​ 409,159 ​ Exploration ​ ​ 3,356 ​ ​ — ​ ​ — ​ ​ — ​ ​ 3,356 ​ Impairment of oil and gas properties ​ ​ 184,973 ​ ​ — ​ ​ — ​ ​ — ​ ​ 184,973 ​ Impairment of gathering systems and facilities ​ ​ 4,470 ​ ​ — ​ ​ 4,614 ​ ​ (583) ​ ​ 8,501 ​ Depletion, depreciation, and amortization ​ ​ 397,429 ​ ​ — ​ ​ 68,865 ​ ​ — ​ ​ 466,294 ​ Accretion of asset retirement obligations ​ ​ 1,322 ​ ​ — ​ ​ 68 ​ ​ — ​ ​ 1,390 ​ General and administrative ​ ​ 93,082 ​ ​ — ​ ​ 29,949 ​ ​ (1,314) ​ ​ 121,717 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 7,821 ​ ​ (7,821) ​ ​ — ​ Total operating expenses ​ ​ 2,001,111 ​ ​ — ​ ​ 254,196 ​ ​ (351,593) ​ ​ 1,903,714 ​ Operating income ​ ​ 16,935 ​ ​ — ​ ​ 226,370 ​ ​ (129,574) ​ ​ 113,731 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 17,126 ​ ​ — ​ ​ 17,126 ​ Interest expense, net ​ ​ (107,886) ​ ​ — ​ ​ (25,925) ​ ​ 36 ​ ​ (133,775) ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ (47,054) ​ ​ — ​ ​ — ​ ​ 47,054 ​ ​ — ​ Total other expenses ​ ​ (154,940) ​ ​ — ​ ​ (8,799) ​ ​ 47,090 ​ ​ (116,649) ​ Income (loss) before income taxes ​ ​ (138,005) ​ ​ — ​ ​ 217,571 ​ ​ (82,484) ​ ​ (2,918) ​ Provision for income tax benefit ​ ​ 16,453 ​ ​ — ​ ​ — ​ ​ — ​ ​ 16,453 ​ Net income (loss) and comprehensive income (loss) including noncontrolling interests ​ ​ (121,552) ​ ​ — ​ ​ 217,571 ​ ​ (82,484) ​ ​ 13,535 ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 135,087 ​ ​ 135,087 ​ Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation ​ $ (121,552) ​ ​ — ​ ​ 217,571 ​ ​ (217,571) ​ ​ (121,552) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Operations and Comprehensive Income ​ Six Months Ended June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Revenue and other: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Natural gas sales ​ $ 1,210,638 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,210,638 ​ Natural gas liquids sales ​ 617,648 ​ — ​ — ​ — ​ 617,648 ​ Oil sales ​ ​ 97,114 ​ ​ — ​ ​ — ​ ​ — ​ ​ 97,114 ​ Commodity derivative fair value gains ​ ​ 251,059 ​ ​ — ​ ​ — ​ ​ — ​ ​ 251,059 ​ Gathering, compression, water handling and treatment ​ ​ — ​ ​ — ​ ​ 218,360 ​ ​ (213,881) ​ ​ 4,479 ​ Marketing ​ ​ 154,266 ​ ​ — ​ ​ — ​ ​ — ​ ​ 154,266 ​ Other income ​ ​ 3,518 ​ ​ — ​ ​ — ​ ​ (1,651) ​ ​ 1,867 ​ Total revenue and other ​ ​ 2,334,243 ​ ​ — ​ ​ 218,360 ​ ​ (215,532) ​ ​ 2,337,071 ​ Operating expenses: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Lease operating ​ ​ 83,826 ​ ​ — ​ ​ 64,818 ​ ​ (66,055) ​ ​ 82,589 ​ Gathering, compression, processing, and transportation ​ ​ 1,101,849 ​ ​ — ​ ​ — ​ ​ (110,486) ​ ​ 991,363 ​ Production and ad valorem taxes ​ ​ 65,706 ​ ​ — ​ ​ — ​ ​ 940 ​ ​ 66,646 ​ Marketing ​ ​ 300,623 ​ ​ — ​ ​ — ​ ​ — ​ ​ 300,623 ​ Exploration ​ ​ 440 ​ ​ — ​ ​ — ​ ​ — ​ ​ 440 ​ Impairment of oil and gas properties ​ ​ 212,243 ​ ​ — ​ ​ — ​ ​ — ​ ​ 212,243 ​ Impairment of gathering systems and facilities ​ ​ — ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 6,982 ​ Depletion, depreciation, and amortization ​ ​ 460,796 ​ ​ — ​ ​ 21,707 ​ ​ — ​ ​ 482,503 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Accretion of asset retirement obligations ​ ​ 1,831 ​ ​ — ​ ​ 63 ​ ​ — ​ ​ 1,894 ​ General and administrative ​ ​ 92,290 ​ ​ — ​ ​ 18,793 ​ ​ (499) ​ ​ 110,584 ​ Contract termination and rig stacking ​ ​ 13,964 ​ ​ — ​ ​ — ​ ​ — ​ ​ 13,964 ​ Accretion of contingent acquisition consideration ​ ​ — ​ ​ — ​ ​ 1,928 ​ ​ (1,928) ​ ​ — ​ Total operating expenses ​ ​ 2,334,519 ​ ​ — ​ ​ 114,291 ​ ​ (178,028) ​ ​ 2,270,782 ​ Operating income (loss) ​ ​ (276) ​ ​ — ​ ​ 104,069 ​ ​ (37,504) ​ ​ 66,289 ​ Other income (expenses): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Equity in earnings of unconsolidated affiliates ​ ​ 4,999 ​ ​ 10,403 ​ ​ 12,264 ​ ​ — ​ ​ 27,666 ​ Interest expense, net ​ ​ (109,299) ​ ​ — ​ ​ (16,815) ​ ​ — ​ ​ (126,114) ​ 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) ​ ​ 1,116,426 ​ ​ 210,740 ​ ​ (4,551) ​ ​ (15,021) ​ ​ 1,307,594 ​ Income before income taxes ​ ​ 1,116,150 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 1,373,883 ​ Provision for income tax expense ​ ​ (305,959) ​ ​ — ​ ​ — ​ ​ — ​ ​ (305,959) ​ Net income and comprehensive income including noncontrolling interests ​ ​ 810,191 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 1,067,924 ​ Net income and comprehensive income attributable to noncontrolling interests ​ ​ — ​ ​ — ​ ​ — ​ ​ 46,993 ​ ​ 46,993 ​ Net income and comprehensive income attributable to Antero Resources Corporation ​ $ 810,191 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (99,518) ​ ​ 1,020,931 ​
Schedule of condensed consolidated statement of cash flows	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Cash Flows ​ Six Months Ended June 30, 2018 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Cash flows provided by (used in) operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net income (loss) including noncontrolling interests ​ $ (121,552) ​ ​ — ​ ​ 217,571 ​ ​ (82,484) ​ ​ 13,535 ​ Adjustment to reconcile net income (loss) to net cash provided by operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depletion, depreciation, amortization, and accretion ​ ​ 398,751 ​ ​ — ​ ​ 68,933 ​ ​ — ​ ​ 467,684 ​ Accretion of contingent acquisition consideration ​ ​ (7,821) ​ ​ — ​ ​ 7,821 ​ ​ — ​ ​ — ​ Impairment of oil and gas properties ​ ​ 184,973 ​ ​ — ​ ​ — ​ ​ — ​ ​ 184,973 ​ Impairment of gathering systems and facilities ​ ​ 4,470 ​ ​ — ​ ​ 4,614 ​ ​ (583) ​ ​ 8,501 ​ Commodity derivative fair value gains ​ ​ (77,773) ​ ​ — ​ ​ — ​ ​ — ​ ​ (77,773) ​ Gains on settled commodity derivatives ​ ​ 197,225 ​ ​ — ​ ​ — ​ ​ — ​ ​ 197,225 ​ Marketing derivative fair value gains ​ ​ (94,124) ​ ​ — ​ ​ — ​ ​ — ​ ​ (94,124) ​ Gains on settled marketing derivatives ​ ​ 94,158 ​ ​ — ​ ​ — ​ ​ — ​ ​ 94,158 ​ Deferred income tax benefit ​ ​ (16,453) ​ ​ — ​ ​ — ​ ​ — ​ ​ (16,453) ​ Gain on sale of assets ​ ​ — ​ ​ — ​ ​ (583) ​ ​ 583 ​ ​ — ​ Equity-based compensation expense ​ ​ 28,149 ​ ​ — ​ ​ 12,078 ​ ​ — ​ ​ 40,227 ​ Equity in earnings (loss) of consolidated subsidiaries ​ ​ 47,054 ​ ​ — ​ ​ — ​ ​ (47,054) ​ ​ — ​ Equity in earnings of unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (17,126) ​ ​ — ​ ​ (17,126) ​ Distributions of earnings from unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ 17,895 ​ ​ — ​ ​ 17,895 ​ Distributions from Antero Midstream Partners LP ​ ​ 74,647 ​ ​ — ​ ​ — ​ ​ (74,647) ​ ​ — ​ Other ​ ​ 547 ​ ​ — ​ ​ 1,385 ​ ​ — ​ ​ 1,932 ​ Changes in current assets and liabilities ​ ​ 14,510 ​ ​ — ​ ​ (157) ​ ​ 3,933 ​ ​ 18,286 ​ Net cash provided by operating activities ​ ​ 726,761 ​ ​ — ​ ​ 312,431 ​ ​ (200,252) ​ ​ 838,940 ​ Cash flows provided by (used in) investing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Additions to unproved properties ​ ​ (87,861) ​ ​ — ​ ​ — ​ ​ — ​ ​ (87,861) ​ Drilling and completion costs ​ ​ (887,459) ​ ​ — ​ ​ — ​ ​ 134,678 ​ ​ (752,781) ​ Additions to water handling and treatment systems ​ ​ — ​ ​ — ​ ​ (49,054) ​ ​ (9,073) ​ ​ (58,127) ​ Additions to gathering systems and facilities ​ ​ — ​ ​ — ​ ​ (206,753) ​ ​ — ​ ​ (206,753) ​ Additions to other property and equipment ​ ​ (3,502) ​ ​ — ​ ​ — ​ ​ — ​ ​ (3,502) ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (56,297) ​ ​ — ​ ​ (56,297) ​ Change in other assets ​ ​ 2,051 ​ ​ — ​ ​ (9,077) ​ ​ — ​ ​ (7,026) ​ Net cash used in investing activities ​ ​ (976,771) ​ ​ — ​ ​ (321,181) ​ ​ 125,605 ​ ​ (1,172,347) ​ Cash flows provided by (used in) financing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Borrowings (repayments) on bank credit facility, net ​ ​ 270,000 ​ ​ — ​ ​ 215,000 ​ ​ — ​ ​ 485,000 ​ Distributions to noncontrolling interests in Antero Midstream Partners LP ​ ​ — ​ ​ — ​ ​ (193,670) ​ ​ 74,647 ​ ​ (119,023) ​ Employee tax withholding for settlement of equity compensation awards ​ ​ (6,649) ​ ​ — ​ ​ (1,318) ​ ​ — ​ ​ (7,967) ​ Other ​ ​ (2,336) ​ ​ — ​ ​ (100) ​ ​ — ​ ​ (2,436) ​ Net cash provided by financing activities ​ ​ 261,015 ​ ​ — ​ ​ 19,912 ​ ​ 74,647 ​ ​ 355,574 ​ Net increase in cash and cash equivalents ​ ​ 11,005 ​ ​ — ​ ​ 11,162 ​ ​ — ​ ​ 22,167 ​ Cash and cash equivalents, beginning of period ​ ​ 20,078 ​ ​ — ​ ​ 8,363 ​ ​ — ​ ​ 28,441 ​ Cash and cash equivalents, end of period ​ $ 31,083 ​ ​ — ​ ​ 19,525 ​ ​ — ​ ​ 50,608 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Condensed Consolidating Statement of Cash Flows ​ Six Months Ended June 30, 2019 ​ (In thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Parent ​ Guarantor ​ Non-Guarantor ​ Eliminations ​ Consolidated ​ Cash flows provided by (used in) operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Net income including noncontrolling interests ​ $ 810,191 ​ ​ 210,740 ​ ​ 99,518 ​ ​ (52,525) ​ ​ 1,067,924 ​ Adjustment to reconcile net income to net cash provided by operating activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depletion, depreciation, amortization, and accretion ​ ​ 462,627 ​ ​ — ​ ​ 21,770 ​ ​ — ​ ​ 484,397 ​ Impairment of oil and gas properties ​ ​ 212,243 ​ ​ — ​ ​ — ​ ​ — ​ ​ 212,243 ​ Impairment of gathering systems and facilities ​ ​ — ​ ​ — ​ ​ 6,982 ​ ​ — ​ ​ 6,982 ​ Commodity derivative fair value gains ​ ​ (251,059) ​ ​ — ​ ​ — ​ ​ — ​ ​ (251,059) ​ Gains on settled commodity derivatives ​ ​ 141,791 ​ ​ — ​ ​ — ​ ​ — ​ ​ 141,791 ​ Deferred income tax expense ​ ​ 304,963 ​ ​ — ​ ​ — ​ ​ — ​ ​ 304,963 ​ Loss on sale of assets ​ ​ 951 ​ ​ — ​ ​ — ​ ​ — ​ ​ 951 ​ Equity-based compensation expense ​ ​ 12,975 ​ ​ — ​ ​ 2,477 ​ ​ — ​ ​ 15,452 ​ Equity in earnings of affiliates ​ ​ (15,021) ​ ​ — ​ ​ — ​ ​ 15,021 ​ ​ — ​ Equity in earnings of unconsolidated affiliates ​ ​ (4,999) ​ ​ (10,403) ​ ​ (12,264) ​ ​ — ​ ​ (27,666) ​ Distributions/dividends of earnings from unconsolidated affiliates ​ ​ 47,922 ​ ​ — ​ ​ 12,605 ​ ​ — ​ ​ 60,527 ​ 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 ​ ​ (43,002) ​ ​ — ​ ​ 750 ​ ​ 47,922 ​ ​ 5,670 ​ Changes in current assets and liabilities ​ ​ 134,740 ​ ​ — ​ ​ (10,573) ​ ​ 16,808 ​ ​ 140,975 ​ Net cash provided by operating activities ​ ​ 703,008 ​ ​ — ​ ​ 121,265 ​ ​ (67,165) ​ ​ 757,108 ​ Cash flows provided by (used in) investing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Additions to unproved properties ​ ​ (56,814) ​ ​ — ​ ​ — ​ ​ — ​ ​ (56,814) ​ Drilling and completion costs ​ ​ (700,653) ​ ​ — ​ ​ — ​ ​ 20,565 ​ ​ (680,088) ​ 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 ​ ​ (3,567) ​ ​ — ​ ​ (1,062) ​ ​ — ​ ​ (4,629) ​ Investments in unconsolidated affiliates ​ ​ — ​ ​ — ​ ​ (25,020) ​ ​ — ​ ​ (25,020) ​ Proceeds from the Antero Midstream Partners LP Transactions ​ ​ 296,611 ​ ​ — ​ ​ — ​ ​ — ​ ​ 296,611 ​ Change in other assets ​ ​ (1,617) ​ ​ — ​ ​ (3,357) ​ ​ — ​ ​ (4,974) ​ Proceeds from sale of assets ​ ​ 1,983 ​ ​ — ​ ​ — ​ ​ — ​ ​ 1,983 ​ Net cash used in investing activities ​ ​ (464,057) ​ ​ — ​ ​ (102,225) ​ ​ 20,696 ​ ​ (545,586) ​ Cash flows provided by (used in) financing activities: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Issuance of senior notes ​ ​ — ​ ​ — ​ ​ 650,000 ​ ​ — ​ ​ 650,000 ​ Borrowings (repayments) on bank credit facility, net ​ ​ (235,379) ​ ​ — ​ ​ 90,379 ​ ​ — ​ ​ (145,000) ​ 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 ​ ​ (2,266) ​ ​ — ​ ​ (29) ​ ​ — ​ ​ (2,295) ​ Other ​ ​ (515) ​ ​ — ​ ​ (845) ​ ​ — ​ ​ (1,360) ​ Net cash provided by (used in) financing activities ​ ​ (238,951) ​ ​ — ​ ​ 600,492 ​ ​ 46,469 ​ ​ 408,010 ​ 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	Jun. 30, 2018	Jun. 30, 2019	Mar. 12, 2019	Dec. 31, 2018
Basis of Presentation
Other comprehensive income (loss)		$ 0
Accounts Payable
Basis of Presentation
Bank Overdrafts			$ 6		$ 10
Revenue distributions payable
Basis of Presentation
Bank Overdrafts			$ 32		$ 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) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Oil and Gas Properties
Exploration			$ 0	$ 0
Impairment of oil and gas properties	$ 130,999	$ 134,437	212,243	184,973
Impairment of oil and gas properties for leases expired or expected to expire			186,000	$ 185,000
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Earnings per share
Basic weighted average number of shares outstanding	309,062	316,992	308,879	316,733
Diluted weighted average number of shares outstanding	309,137	316,992	309,082	316,733
Restricted stock and restricted stock unit
Earnings per share
Add: Dilutive effect of non-vested restricted stock units	33		48
Weighted Average Anti-dilutive Awards	2,284	2,899	1,877	3,088
Stock options
Earnings per share
Weighted Average Anti-dilutive Awards	538	639	554	646
Performance share unit awards
Earnings per share
Add: Dilutive effect of non-vested restricted stock units	42		155
Weighted Average Anti-dilutive Awards	2,592	1,860	1,996	1,556

Deconsolidation of Antero Mid_3

Deconsolidation of Antero Midstream Partners LP - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	Mar. 12, 2019	Mar. 11, 2019	Jun. 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	158,400,000
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	Jun. 30, 2019	Mar. 12, 2019	Dec. 31, 2018	Jun. 30, 2018
Deconsolidation
Current assets	$ 713,049		$ 806,613
Property and equipment, net	10,915,402		13,869,915
Other noncurrent assets	34,883		47,125
Total assets	17,330,880		15,519,464	$ 15,690,607
Current liabilities	1,221,107		853,540
Long-term debt	3,602,379		5,461,688
Other noncurrent liabilities	57,965		63,098
Total liabilities	$ 8,991,180		$ 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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue
Revenues from contracts with customers	$ 969,477	$ 934,118	$ 2,084,145	$ 1,845,548
Income from derivatives and other sources	330,187	55,226	252,926	171,897
Total revenue	1,299,664	989,344	2,337,071	2,017,445
Natural gas sales
Disaggregation of Revenue
Revenues from contracts with customers	553,372	473,540	1,210,638	971,203
Oil sales
Disaggregation of Revenue
Revenues from contracts with customers	49,062	38,873	97,114	69,146
Marketing
Disaggregation of Revenue
Revenues from contracts with customers	63,080	160,202	154,266	304,591
Other income
Disaggregation of Revenue
Revenues from contracts with customers	1,760		1,867
Exploration and production | Natural gas sales
Disaggregation of Revenue
Revenues from contracts with customers	553,372	473,540	1,210,638	971,203
Exploration and production | Natural gas liquids sales (ethane)
Disaggregation of Revenue
Revenues from contracts with customers	30,374	32,687	65,890	59,762
Exploration and production | Natural gas liquids sales (C3+ NGLs)
Disaggregation of Revenue
Revenues from contracts with customers	273,589	223,298	551,758	430,393
Exploration and production | Oil sales
Disaggregation of Revenue
Revenues from contracts with customers	49,062	38,873	97,114	69,146
Gathering and compression | Gathering and compression
Disaggregation of Revenue
Revenues from contracts with customers		4,263	3,972	8,408
Water handling and treatment | Water handling and treatment
Disaggregation of Revenue
Revenues from contracts with customers		1,255	507	2,045
Marketing | Marketing
Disaggregation of Revenue
Revenues from contracts with customers	$ 63,080	$ 160,202	$ 154,266	$ 304,591

Revenue - Transaction Price All

Revenue - Transaction Price Allocation and Contract Balances (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Revenue
Original expected duration	true
Receivables from contracts with customers	$ 309	$ 475

Equity Method Investments (Deta

Equity Method Investments (Details) $ in Thousands	Mar. 12, 2019item	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)
Investments in unconsolidated affiliates
Balance at beginning of period					$ 433,642
Investments					25,020
Equity in earnings (loss) of unconsolidated affiliates		$ 13,585	$ 9,264		27,666	$ 17,126
Distributions of earnings from unconsolidated affiliates					(60,527)	$ (17,895)
Elimination of intercompany profit					11,928
Effects of deconsolidation					1,529,474
Balance at end of period		1,967,203		$ 1,967,203	1,967,203
Stonewall
Investments in unconsolidated affiliates
Balance at beginning of period					68,103
Equity in earnings (loss) of unconsolidated affiliates					1,894
Distributions of earnings 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 of earnings 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					15,402
Distributions of earnings from unconsolidated affiliates					(47,922)
Elimination of intercompany profit					11,928
Effects of deconsolidation					1,987,795
Balance at end of period		1,967,203		1,967,203	1,967,203
Balance Sheet
Current assets		115,367		115,367	115,367
Noncurrent assets		6,653,642		6,653,642	6,653,642
Total assets		6,769,009		6,769,009	6,769,009
Current liabilities		237,504		237,504	237,504
Noncurrent liabilities		2,559,146		2,559,146	2,559,146
Stockholders' equity		3,972,359		3,972,359	3,972,359
Total liabilities and equity		$ 6,769,009		6,769,009	$ 6,769,009
Statement of Operations
Revenues				309,726
Operating expenses				168,056
Income from operations				141,670
Net income attributable to the equity method investments				$ 92,471
Antero Midstream Corporation | Antero Midstream Corporation
Equity Method Investments
Ownership percentage		31.30%		31.30%	31.30%
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	Jun. 30, 2019	Dec. 31, 2018
Accrued Liabilities
Accrued capital expenditures	$ 62,631	$ 113,237
Accrued gathering, compression, processing, and transportation expenses	147,797	148,032
Accrued marketing expenses	47,018	67,082
Accrued interest expense	31,599	43,444
Other accrued liabilities	69,635	93,275
Total accrued liabilities	$ 358,680	$ 465,070

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Thousands	Oct. 26, 2017	Jun. 30, 2019	Dec. 31, 2018	Dec. 21, 2016	Mar. 17, 2015	Sep. 18, 2014	May 06, 2014	Nov. 05, 2013
Long- term Debt
Net unamortized premium		$ 1,095	$ 1,241
Net unamortized debt issuance costs		(23,716)	(26,700)
Long-term debt		3,602,379	5,461,688
Credit Facility
Long- term Debt
Bank credit facility long-term debt		175,000	405,000
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		$ 175,000	$ 405,000
Weighted average interest rate (as a percent)		3.69%	3.95%
Outstanding letters of credit		$ 701,000	$ 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
Long-term notes payable		$ 1,000,000	1,000,000
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
Long-term notes payable		$ 1,100,000	1,100,000
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
Long-term notes payable		$ 750,000	750,000
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	600,000	$ 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%
Antero Midstream Partners LP
Long- term Debt
Net unamortized debt issuance costs			(7,853)
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Asset Retirement Obligations
Asset retirement obligations - beginning of period			$ 58,979
Obligations settled			(153)
Obligations incurred for wells drilled and producing properties acquired			807
Accretion expense	$ 918	$ 700	1,894	$ 1,390
Effect of deconsolidation of Antero Midstream Partners LP			(7,518)
Asset retirement obligations - end of period	$ 54,009		$ 54,009

Equity-Based Compensation (Deta

Equity-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 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	5,753,433		5,753,433
Equity based compensation expense recognized	$ 6,549	$ 19,071	$ 15,452	$ 40,227
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	$ 2,624	10,231	$ 6,600	23,675
Stock options
Stock-based compensation expense
Equity based compensation expense recognized	45	495	389	976
Performance share unit awards
Stock-based compensation expense
Equity based compensation expense recognized	2,666	3,490	5,628	6,001
Antero Midstream Partners Phantom Unit Awards
Stock-based compensation expense
Equity based compensation expense recognized	949	4,341	2,075	8,559
Equity awards issued to directors
Stock-based compensation expense
Equity based compensation expense recognized	$ 265	$ 514	$ 760	$ 1,016
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 - USD ($) $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2019
Number of shares
Total awarded and unvested at the beginning of the period (in shares)	1,712,485
Granted (in shares)	1,568,617
Vested (in shares)	(674,312)
Forfeited (in shares)	(190,525)
Total awarded and unvested at the end of the period (in shares)	2,416,265
Weighted average grant date fair value
Total awarded and unvested at the beginning of the period (in dollars per share)	$ 24.57
Granted (in dollars per share)	8.69
Vested (in dollars per share)	28.04
Forfeited (in dollars per share)	18.05
Total awarded and unvested at the end of the period (in dollars per share)	$ 13.81
Additional equity compensation to be recognized over the remaining period	$ 29
Weighted average period for recognizing unrecognized stock-based compensation expense	2 years 8 months 12 days

Equity-Based Compensation - Sto

Equity-Based Compensation - Stock Options (Details) - Stock options - USD ($) $ / shares in Units, $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Stock options
Outstanding at the beginning of the period (in shares)	579,617
Options forfeited (in shares)	(46,062)
Outstanding at the end of the period (in shares)	533,555	579,617
Vested or expected to vest (in shares)	533,555
Exercisable (in shares)	533,555
Weighted average exercise price
Outstanding at the beginning of the period (in dollars per share)	$ 50.55
Options forfeited (in dollars per share)	50
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	5 years 3 months 14 days	5 years 9 months 21 days
Vested or expected to vest	5 years 3 months 14 days
Exercisable	5 years 3 months 14 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) $ / shares in Units, $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019USD ($)$ / sharesshares	Dec. 31, 2018$ / sharesshares
Performance share unit awards
Number of units
Total awarded and unvested at the beginning of the period (in shares) | shares	1,767,299
Granted (in shares) | shares	1,416,378
Vested (in shares) | shares	(31,944)
Forfeited (in shares) | shares	(342,161)
Total awarded and unvested at the end of the period (in shares) | shares	2,809,572	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
Vested (in dollars per share)	27.38
Forfeited (in dollars per share)	32.72
Total awarded and unvested at the end of the period (in dollars per share)	$ 16.95	$ 26.36
Additional disclosures
Additional equity compensation to be recognized over the remaining period | $	$ 26
Weighted average period for recognizing unrecognized stock-based compensation expense	2 years 1 month 6 days
Weighted-average assumptions used to calculate fair value of performance share units granted
Weighted average fair value of awards granted (in dollars per share)	$ 9.26
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	6 Months Ended
	Mar. 12, 2019	Jun. 30, 2019	Jun. 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)	(317,651)
Forfeited (in shares)	(20,338)	(18,906)
Total awarded and unvested at the end of the period (in shares)	564,781	732,343	732,343
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	14.58
Vested (in dollars per share)	32.44	14.06
Forfeited (in dollars per share)	26.73	13.86
Total awarded and unvested at the end of the period (in dollars per share)	$ 27.59	$ 14.82	$ 14.82
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	8,393	8,393
Additional equity compensation to be recognized over the remaining period		$ 9,000	$ 9,000
Weighted average period for recognizing unrecognized stock-based compensation expense			2 years 1 month 6 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)			1,568,617
Vested (in shares)			(674,312)
Forfeited (in shares)			(190,525)
Total awarded and unvested at the end of the period (in shares)		2,416,265	2,416,265
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)			8.69
Vested (in dollars per share)			28.04
Forfeited (in dollars per share)			18.05
Total awarded and unvested at the end of the period (in dollars per share)		$ 13.81	$ 13.81
Aggregate intrinsic value
Outstanding at the beginning of the period	$ 16,080		$ 16,080
Outstanding at the end of the period		$ 13,362	13,362
Additional equity compensation to be recognized over the remaining period		$ 29,000	$ 29,000
Weighted average period for recognizing unrecognized stock-based compensation expense			2 years 8 months 12 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	Jun. 30, 2019	Dec. 31, 2018
Recurring | Level 2 market data
Financial Instruments
Fair value of senior notes	$ 3.3	$ 3.9

Derivative Instruments - Commod

Derivative Instruments - Commodity derivatives (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)MMBTU / dMT$ / MMBTU$ / bblbbl	Dec. 31, 2018USD ($)
Derivatives not designated as hedges for accounting purposes | NYMEX | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	1,575,000
Weighted average index price ceiling price	3.30
Weighted average index price floor price	2.50
Derivatives not designated as hedges for accounting purposes | NYMEX | Three months ending December 31, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	1,575,000
Weighted average index price ceiling price	3.52
Weighted average index price floor price	2.50
Derivatives not designated as hedges for accounting purposes | Mont Belvieu-Propane
Derivative Instruments
Mont Belvieu Propane index price (as a percent)	50.00%
Derivatives not designated as hedges for accounting purposes | Natural gas liquids | Mont Belvieu-Propane
Derivative Instruments
Notional amount (Bbls/day) | bbl	500
Commodity derivative
Derivative Instruments
Gross amounts on balance sheet | $	$ 729,664	$ 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 | $	$ 9,000
Swaps | NYMEX | Three months ending September 30, 2019
Derivative Instruments
Weighted average index price	3.32
Swaps | NYMEX | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price	3.45
Swaps | NYMEX | Year ending December 31, 2020
Derivative Instruments
Weighted average index price	2.87
Swaps | NYMEX | Year Ending December 31, 2021
Derivative Instruments
Weighted average index price	2.88
Swaps | NYMEX | Year ending December 31, 2022
Derivative Instruments
Weighted average index price	3
Swaps | NYMEX | Year ending December 31, 2023
Derivative Instruments
Weighted average index price	2.91
Swaps | Argus Butane ARA | Three months ending September 30, 2019
Derivative Instruments
Weighted average index price	330.25
Swaps | Argus Butane FEI | Three months ending September 30, 2019
Derivative Instruments
Weighted average index price	370
Swaps | Propane Argus ARA | Three months ending September 30, 2019
Derivative Instruments
Weighted average index price	328.17
Swaps | Propane Argus FEI | Three months ending September 30, 2019
Derivative Instruments
Weighted average index price	383.41
Swaps | NYMEX-WTI | Three months ending September 30, 2019
Derivative Instruments
Weighted average index price	61.83
Swaps | NYMEX-WTI | Three months ending December 31, 2019
Derivative Instruments
Weighted average index price | $ / bbl	61.83
Swaps | NYMEX-WTI | Year ending December 31, 2020
Derivative Instruments
Weighted average index price | $ / bbl	59.03
Swaps | Natural gas | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	755,000
Swaps | Natural gas | Three months ending December 31, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	755,000
Swaps | Natural gas | Year ending December 31, 2020
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	60,000
Swaps | Natural gas | Year Ending December 31, 2021
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	40,000
Swaps | Natural gas | Year ending December 31, 2022
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	60,000
Swaps | Natural gas | Year ending December 31, 2023
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	50,000
Swaps | Natural gas | NYMEX | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	755,000
Swaps | Natural gas | NYMEX | Three months ending December 31, 2019
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	755,000
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	1,010,000
Swaps | Natural gas | NYMEX | Year ending December 31, 2022
Derivative Instruments
Notional amount (MMBtu/day) | MMBTU / d	850,000
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 September 30, 2019
Derivative Instruments
Notional amount (MT/day) | MT	1,024
Swaps | Natural gas liquids | Argus Butane ARA | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MT/day) | MT	242
Swaps | Natural gas liquids | Argus Butane FEI | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MT/day) | MT	24
Swaps | Natural gas liquids | Propane Argus ARA | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MT/day) | MT	484
Swaps | Natural gas liquids | Propane Argus FEI | Three months ending September 30, 2019
Derivative Instruments
Notional amount (MT/day) | MT	274
Swaps | Oil | Three months ending September 30, 2019
Derivative Instruments
Notional amount (Bbls/day) | bbl	5,000
Swaps | Oil | Three months ending December 31, 2019
Derivative Instruments
Notional amount (Bbls/day) | bbl	5,000
Swaps | Oil | NYMEX | Three months ending September 30, 2019
Derivative Instruments
Notional amount (Bbls/day) | bbl	5,000
Swaps | Oil | NYMEX | Year ending December 31, 2020
Derivative Instruments
Notional amount (Bbls/day) | bbl	5,000
Swaps | Oil | NYMEX-WTI | Three months ending December 31, 2019
Derivative Instruments
Notional amount (Bbls/day) | bbl	5,000
Swaps | Oil | NYMEX-WTI | Year ending December 31, 2020
Derivative Instruments
Notional amount (Bbls/day) | bbl	5,000

Derivative Instruments (Details

Derivative Instruments (Details) - Swaps	Jun. 30, 2019MMBTU / d$ / MMBTU
Year ending December 31, 2020 | Hedged differential
Derivative [Line Items]
Differential hedging price | $ / MMBTU	0.353
Year Ending December 31, 2021 | Hedged differential
Derivative [Line Items]
Differential hedging price | $ / MMBTU	0.414
Year ending December 31, 2022 | Hedged differential
Derivative [Line Items]
Differential hedging price | $ / MMBTU	0.515
Year ending December 31, 2023 | Hedged differential
Derivative [Line Items]
Differential hedging price | $ / MMBTU	0.525
Year ending December 31, 2024 | Hedged differential
Derivative [Line Items]
Differential hedging price | $ / MMBTU	0.530
Natural gas | Year ending December 31, 2020
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	60,000
Natural gas | Year Ending December 31, 2021
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	40,000
Natural gas | Year ending December 31, 2022
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	60,000
Natural gas | Year ending December 31, 2023
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	50,000
Natural gas | Year ending December 31, 2024
Derivative [Line Items]
Notional amount (MMBtu/day) | MMBTU / d	50,000

Derivative Instruments - Fair v

Derivative Instruments - Fair value (Details) $ in Thousands	Jun. 30, 2019USD ($)	Mar. 31, 2019item	Dec. 31, 2018USD ($)item
Fair value of derivative instruments
Current portion of fair value of derivative assets	$ 346,894		$ 245,263
Noncurrent portion of fair value of derivative assets	369,548		362,169
Current portion of fair value of derivative liabilities	274		532
Commodity derivative
Fair value of derivative instruments
Total asset derivatives	716,442		607,432
Total liability derivatives	274		532
Derivatives not designated as hedges for accounting purposes
Fair value of derivative instruments
Total asset derivatives	716,442		607,432
Total liability derivatives	274		532
Net derivatives	716,168		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	346,894		245,263
Noncurrent portion of fair value of derivative assets	369,548		362,169
Current portion of fair value of derivative liabilities	$ 274		$ 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	Jun. 30, 2019	Dec. 31, 2018
Commodity derivative assets
Gross amounts on balance sheet	$ 729,664	$ 658,830
Gross amounts offset on balance sheet	(13,222)	(51,398)
Total asset derivatives	716,442	607,432
Commodity derivative liabilities
Gross amounts on balance sheet	(13,496)	(51,930)
Gross amounts offset on balance sheet	13,222	51,398
Total liability derivatives	$ (274)	$ (532)

Derivative Instruments - Fair_2

Derivative Instruments - Fair value gains (losses) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Summary of realized and unrealized gains (losses) on derivative instruments
Commodity derivative fair value gains (losses)	$ 328,427	$ 55,336	$ 251,059	$ 77,773
Marketing derivative fair value gains		(110)		94,124
Revenue
Summary of realized and unrealized gains (losses) on derivative instruments
Commodity derivative fair value gains (losses)	$ 328,427	55,336	$ 251,059	77,773
Marketing derivative fair value gains		(110)		$ 94,124
Maximum
Summary of realized and unrealized gains (losses) on derivative instruments
Marketing derivative fair value gains		$ 1,000

Leases (Details)

Leases (Details)	6 Months Ended
	Jun. 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	Jun. 30, 2019USD ($)
Lease Assets
Operating leases right-of-use assets	$ 3,330,795
Finance leases, right of use assets	3,650
Finance leases, accumulated amortization	9,000
Short-term lease liabilities, operating leases	412,143
Long-term lease liabilities, operating leases	2,918,652
Total lease liabilities, operating leases	3,330,795
Short-term lease liabilities, finance leases	1,548
Long-term lease liabilities, finance leases	2,102
Total	3,650
Vehicles
Lease Assets
Operating leases right-of-use assets	5,627
Finance leases, right of use assets	2,819
Other office and field equipment
Lease Assets
Operating leases right-of-use assets	430
Finance leases, right of use assets	831
Processing plants
Lease Assets
Operating leases right-of-use assets	1,587,374
Drilling and completion rigs
Lease Assets
Operating leases right-of-use assets	115,034
Gas gathering lines and compressor stations
Lease Assets
Operating leases right-of-use assets	1,580,130
Gas gathering lines and compressor stations | Antero Midstream Corporation
Lease Assets
Finance leases, accumulated amortization	1,400,000
Office space
Lease Assets
Operating leases right-of-use assets	$ 42,200

Leases - Supplemental Informati

Leases - Supplemental Information Related to Leases (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Leases
Total Lease Expense	$ 224,025	$ 422,617
Capitalized operating leases	53,000	108,000
Short-term lease costs		74,000
Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases	207,244	357,564
Cash paid for amounts included in the measurement of lease liabilities: Investing cash flows from operating leases	46,532	98,898
Cash paid for amounts included in the measurement of lease liabilities for operating leases	253,776	456,462
Cash paid for amounts included in the measurement of lease liabilities: Financing cash flows from financing leases	873	1,664
Cash paid for amounts included in the measurement of lease liabilities for finance leases	873	1,664
Leased assets obtained in exchange for new operating lease liabilities		3,345,549
Gathering, compression, water handling and treatment
Leases
Total Lease Expense	218,542	406,389
General and administrative
Leases
Total Lease Expense	2,810	5,536
Contract termination and rig stacking
Leases
Total Lease Expense	2,673	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	Jun. 30, 2019USD ($)
Future minimum payments for operating lease liabilities
Remainder of 2019	$ 206,320
2020	396,473
2021	349,212
2022	359,759
2023	377,790
2024	392,323
Thereafter	1,248,918
Total lease payments	3,330,795
Total lease liabilities, operating leases	3,330,795
Future minimum payments for financing lease liabilities
Remainder of 2019	99
2020	869
2021	1,294
2022	1,388
Total lease payments	3,650
Total	3,650
Future minimum payments for total lease liabilities
Remainder of 2019	206,419
2020	397,342
2021	350,506
2022	361,147
2023	377,790
2024	392,323
Thereafter	1,248,918
Total lease payments	3,334,445
Total	$ 3,334,445

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)	Jun. 30, 2019
Leases
Weighted-average remaining lease term: Operating lease	8 years 6 months
Weighted-average discount rate: Operating lease	6.00%
Weighted-average remaining lease term: Finance lease	2 years 2 months 12 days
Weighted-average discount rate: Finance lease	5.50%

Leases - Related party disclosu

Leases - Related party disclosure (Details) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)
Leases
Amount included within accounts payable, related parties	$ 98,570	$ 98,570
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	$ 163,000	$ 315,000
Amount included within accounts payable, related parties	$ 59,000	$ 59,000

Commitments (Details)

Commitments (Details) $ in Millions	Jun. 30, 2019USD ($)
Future minimum payments
Remainder of 2019	$ 799
2020	1,579
2021	1,505
2022	1,460
2023	1,459
2024	1,433
Thereafter	9,121
Total	17,356
Firm transportation
Future minimum payments
Remainder of 2019	558
2020	1,122
2021	1,098
2022	1,045
2023	1,033
2024	993
Thereafter	7,807
Total	13,656
Gas processing, gathering and compression
Future minimum payments
Remainder of 2019	27
2020	54
2021	54
2022	54
2023	48
2024	48
Thereafter	64
Total	349
Land payment obligations
Future minimum payments
Remainder of 2019	8
2020	6
2021	3
Total	17
Leases, including imputed interest
Future minimum payments
Remainder of 2019	206
2020	397
2021	350
2022	361
2023	378
2024	392
Thereafter	1,250
Total	$ 3,334

Contingencies (Details)

Contingencies (Details)

Jun. 20, 2019USD ($)

Jan. 31, 2019USD ($)

Feb. 01, 2018MMBTU / d

Jan. 01, 2018MMBTU / d

Jul. 31, 2017MMBTU / d

Jan. 31, 2018MMBTU / d

Nov. 30, 2017MMBTU / d

Jun. 30, 2019USD ($)MMBTU / dcontractlawsuit

Nov. 30, 2018MMBTU / d

Jun. 30, 2018USD ($)

Mar. 31, 2018USD ($)

Mar. 31, 2017USD ($)

West Virginia activities | Settled Litigation

Contingencies

Settlement amount

$ 3,150,000

Doddridge County, Tyler County and Ritchie County, West Virginia | Pending Litigation | Minimum

Contingencies

Damages sought

$ 100,000

SJGC

Contingencies

Natural gas long term purchase contract volume (in MMBtu)/day | MMBTU / d

80,000

WGL

Contingencies

Natural gas long term purchase contract volume increase after specified events (in MMBtu)/day | MMBTU / d

530,000

Damages awarded

$ 95,900,000

WGL | Pending Litigation

Contingencies

Damages sought

$ 109,000,000

$ 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 lawsuits | lawsuit

2

Number of long term gas contracts | contract

2

Damages sought

$ 88,000,000

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	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Contract Termination and Rig Stacking
Costs for delay or cancelation of drilling and completion contracts with third-party contractors	$ 5,604	$ 13,964

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Sales and revenues:
Sales and revenues	$ 1,297,950	$ 989,344	$ 2,330,775	$ 2,017,445
Sales and revenues	1,299,664	989,344	2,337,071	2,017,445
Operating expenses:
Impairment of oil and gas properties	130,999	134,437	212,243	184,973
Impairment of gathering systems and facilities		8,501	6,982	8,501
Depletion, depreciation, and amortization	242,302	238,050	482,503	466,294
General and administrative	42,382	61,687	110,584	121,717
Other operating expenses	176,294	241,482	384,518	465,619
Total operating expenses	1,199,668	1,022,107	2,270,782	1,903,714
Operating income (loss)	99,996	(32,763)	66,289	113,731
Equity in earnings (loss) of unconsolidated affiliates	13,585	9,264	27,666	17,126
Investments in unconsolidated affiliates	1,967,203		1,967,203		$ 433,642
Segment assets	17,330,880	15,690,607	17,330,880	15,690,607	$ 15,519,464
Capital expenditures for segment assets	342,253	563,061	814,186	1,109,024
Marketing
Sales and revenues:
Sales and revenues			154,266
Operating expenses:
Other operating expenses			300,623
Total operating expenses			300,623
Operating income (loss)			(146,357)
Segment assets	25,361		25,361
Antero Midstream Corporation
Sales and revenues:
Sales and revenues			50
Operating expenses:
Impairment of gathering systems and facilities			7,576
Depletion, depreciation, and amortization			44,097
General and administrative			54,431
Other operating expenses			4,795
Total operating expenses			188,509
Operating income (loss)			121,217
Equity in earnings (loss) of unconsolidated affiliates			16,503
Investments in unconsolidated affiliates	1,186,161		1,186,161
Segment assets	6,769,009		6,769,009
Capital expenditures for segment assets			141,190
Operating segments
Sales and revenues:
Sales and revenues				2,017,445
Operating segments | Exploration and production
Sales and revenues:
Sales and revenues	1,234,824	823,734	2,176,459	1,608,277
Sales and revenues	1,236,584	828,913	2,179,977	1,619,331
Operating expenses:
Impairment of oil and gas properties	130,999	134,437	212,243	184,973
Depletion, depreciation, and amortization	242,302	201,393	460,796	396,981
General and administrative	42,382	46,662	92,290	93,082
Other operating expenses	38,755	27,023	82,892	54,371
Total operating expenses	1,062,129	851,535	2,033,896	1,587,034
Operating income (loss)	174,455	(22,622)	146,081	32,297
Equity in earnings (loss) of unconsolidated affiliates	13,585		15,402
Investments in unconsolidated affiliates	1,967,203		1,967,203
Segment assets	17,305,519	13,381,044	17,305,519	13,381,044
Capital expenditures for segment assets	342,253	506,055	761,034	978,822
Operating segments | Marketing
Sales and revenues:
Sales and revenues	63,080	160,092		398,715
Sales and revenues	63,080	160,092	154,266	398,715
Operating expenses:
Other operating expenses	137,539	213,420		409,159
Total operating expenses	137,539	213,420		409,159
Operating income (loss)	(74,459)	(53,328)		(10,444)
Segment assets	25,361	61,684	25,361	61,684
Operating segments | Antero Midstream Corporation
Sales and revenues:
Sales and revenues	46	5,518		10,453
Sales and revenues	255,618	250,975	309,726	480,566
Operating expenses:
Impairment of gathering systems and facilities	594	8,501		8,501
Depletion, depreciation, and amortization	36,447	36,657		69,313
General and administrative	34,622	15,494		29,949
Other operating expenses	3,504	4,986		9,910
Total operating expenses	138,027	140,256		258,531
Operating income (loss)	117,591	110,719		222,035
Equity in earnings (loss) of unconsolidated affiliates	13,623	9,264		17,126
Investments in unconsolidated affiliates	1,186,161		1,186,161
Segment assets	6,769,009	3,293,101	6,769,009	3,293,101
Capital expenditures for segment assets	125,185	130,925		264,880
Elimination of intersegment transaction
Sales and revenues:
Sales and revenues	1,714	(250,636)	6,296	(481,167)
Sales and revenues	(255,618)	(250,636)	(306,898)	(481,167)
Operating expenses:
Impairment of gathering systems and facilities	(594)		(594)
Depletion, depreciation, and amortization	(36,447)		(22,390)
General and administrative	(34,622)	(469)	(36,137)	(1,314)
Other operating expenses	(3,504)	(3,947)	(3,792)	(7,821)
Total operating expenses	(138,027)	(183,104)	(252,246)	(351,010)
Operating income (loss)	(117,591)	(67,532)	(54,652)	(130,157)
Equity in earnings (loss) of unconsolidated affiliates	(13,623)		(4,239)
Investments in unconsolidated affiliates	(1,186,161)		(1,186,161)
Segment assets	(6,769,009)	(1,045,222)	(6,769,009)	(1,045,222)
Capital expenditures for segment assets	(125,185)	(73,919)	(88,038)	(134,678)
Elimination of intersegment transaction | Exploration and production
Sales and revenues:
Sales and revenues	1,760	5,179	3,518	11,054
Elimination of intersegment transaction | Antero Midstream Corporation
Sales and revenues:
Sales and revenues	255,572	245,457	309,676	470,113
Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	566,834	307,786	991,363	599,724
Gathering, compression, water handling and treatment | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold			15,233
Gathering, compression, water handling and treatment | Operating segments | Exploration and production
Operating expenses:
Cost of goods and services sold	566,834	409,708	1,101,849	794,053
Gathering, compression, water handling and treatment | Operating segments | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold	12,311	12,400		23,768
Gathering, compression, water handling and treatment | Elimination of intersegment transaction
Operating expenses:
Cost of goods and services sold	(12,311)	(114,322)	(125,719)	(218,097)
Lease operating
Operating expenses:
Cost of goods and services sold	40,857	30,164	82,589	56,886
Lease operating | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold			62,377
Lease operating | Operating segments | Exploration and production
Operating expenses:
Cost of goods and services sold	40,857	32,312	83,826	63,574
Lease operating | Operating segments | Antero Midstream Corporation
Operating expenses:
Cost of goods and services sold	50,549	62,218		117,090
Lease operating | Elimination of intersegment transaction
Operating expenses:
Cost of goods and services sold	$ (50,549)	$ (64,366)	$ (63,614)	$ (123,778)

Subsidiary Guarantors - Balance

Subsidiary Guarantors - Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Accounts receivable, net	$ 49,994		$ 51,073
Accrued revenue	308,761		474,827
Derivative instruments	346,894		245,263
Other current assets	7,400		35,450
Total current assets	713,049		806,613
Unproved properties	1,585,355		1,767,600
Proved properties	13,357,733		12,705,672
Water handling and treatment systems			1,013,818
Gathering systems and facilities	17,825		2,470,708
Other property and equipment	69,676		65,842
Property and equipment, gross	15,030,589		18,023,640
Less accumulated depletion, depreciation, and amortization	(4,115,187)		(4,153,725)
Property and equipment, net	10,915,402		13,869,915
Operating leases right-of-use assets	3,330,795
Derivative instruments	369,548		362,169
Investment in consolidated affiliates	1,967,203		433,642
Investments in unconsolidated affiliates	1,967,203		433,642
Other assets	34,883		47,125
Total assets	17,330,880		15,519,464	$ 15,690,607
Liabilities and Stockholders' Equity
Accounts payable	44,758		66,289
Accounts payable, related parties	98,570
Accrued liabilities	358,680		465,070
Revenue distributions payable	301,032		310,827
Derivative instruments	274		532
Short-term lease liabilities	413,691		2,459
Other current liabilities	4,102		8,363
Total current liabilities	1,221,107		853,540
Long-term debt	3,602,379		5,461,688
Deferred income tax liability	1,188,975		650,788
Long-term lease liabilities	2,920,754		2,873
Other liabilities	57,965		63,098
Total liabilities	8,991,180		7,031,987
Common stock	3,091		3,086
Additional paid-in capital	6,138,130		6,485,174
Accumulated earnings	2,198,479		1,177,548
Total stockholders' equity	8,339,700		7,665,808
Noncontrolling interests in consolidated subsidiary			821,669
Total equity	8,339,700	$ 8,292,798	8,487,477	$ 8,802,911	$ 8,921,098	$ 8,876,136
Total liabilities and equity	17,330,880		15,519,464
Reportable legal entity | Parent (Antero)
Current assets:
Accounts receivable, net	49,994		49,529
Intercompany receivables			383
Accrued revenue	308,761		474,827
Derivative instruments	346,894		245,263
Other current assets	7,400		13,937
Total current assets	713,049		783,939
Unproved properties	1,585,355		1,767,600
Proved properties	13,357,733		13,306,585
Gathering systems and facilities	17,825		17,825
Other property and equipment	69,676		65,770
Property and equipment, gross	15,030,589		15,157,780
Less accumulated depletion, depreciation, and amortization	(4,115,187)		(3,654,392)
Property and equipment, net	10,915,402		11,503,388
Operating leases right-of-use assets	3,330,795
Derivative instruments	369,548		362,169
Investment in consolidated affiliates	1,341,780		(740,031)
Contingent acquisition consideration			114,995
Investments in unconsolidated affiliates	625,423
Other assets	34,883		31,200
Total assets	17,330,880		12,055,660
Liabilities and Stockholders' Equity
Accounts payable	44,758		44,917
Accounts payable, related parties	298,907
Intercompany payable			111,620
Accrued liabilities	358,680		392,949
Revenue distributions payable	301,032		310,827
Derivative instruments	274		532
Short-term lease liabilities	413,691		2,459
Other current liabilities	4,102		2,162
Total current liabilities	1,421,444		865,466
Long-term debt	3,602,379		3,829,541
Deferred income tax liability	1,188,975		650,788
Long-term lease liabilities	2,920,754		2,873
Other liabilities	57,965		55,017
Total liabilities	9,191,517		5,403,685
Common stock	3,091		3,086
Additional paid-in capital	6,138,130		5,471,341
Accumulated earnings	1,998,142		1,177,548
Total stockholders' equity			6,651,975
Total equity	8,139,363		6,651,975
Total liabilities and equity	17,330,880		12,055,660
Reportable legal entity | Guarantor Subsidiaries
Current assets:
Accounts receivable, net	200,337
Total current assets	200,337
Investments in unconsolidated affiliates	1,341,780
Total assets	1,542,117
Liabilities and Stockholders' Equity
Additional paid-in capital	1,341,780
Accumulated earnings	200,337
Total equity	1,542,117
Total liabilities and equity	1,542,117
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:
Accounts receivable, net	(200,337)
Intercompany receivables			(115,761)
Total current assets	(200,337)		(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	(1,341,780)		740,031
Contingent acquisition consideration			(114,995)
Total assets	(1,542,117)		(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	(1,341,780)		1,013,833
Total stockholders' equity			(677,675)
Noncontrolling interests in consolidated subsidiary			821,669
Total equity	(1,341,780)		143,994
Total liabilities and equity	$ (1,542,117)		$ (82,613)

Subsidiary Guarantors - Stateme

Subsidiary Guarantors - Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue and other:
Revenues from contracts with customers	$ 969,477		$ 934,118		$ 2,084,145	$ 1,845,548
Commodity derivative fair value gains (losses)	328,427		55,336		251,059	77,773
Marketing derivative gains			(110)			94,124
Loss on sale of assets	951				951
Total revenue	1,299,664		989,344		2,337,071	2,017,445
Operating expenses:
Production and ad valorem taxes	30,968		25,891		66,646	51,714
Impairment of oil and gas properties	130,999		134,437		212,243	184,973
Impairment of gathering systems and facilities			8,501		6,982	8,501
Depletion, depreciation, and amortization	242,302		238,050		482,503	466,294
Accretion of asset retirement obligations	918		700		1,894	1,390
General and administrative	42,382		61,687		110,584	121,717
Contract termination and rig stacking	5,604				13,964
Total operating expenses	1,199,668		1,022,107		2,270,782	1,903,714
Operating income (loss)	99,996		(32,763)		66,289	113,731
Equity in earnings (loss) of unconsolidated affiliates	13,585		9,264		27,666	17,126
Interest expense, net	(54,164)		(69,349)		(126,114)	(133,775)
Gain on deconsolidation of Antero Midstream Partners LP					1,406,042
Total other expenses	(40,579)		(60,085)		1,307,594	(116,649)
Income (loss) before income taxes	59,417		(92,848)		1,373,883	(2,918)
Provision for income tax (expense) benefit	(17,249)		25,573		(305,959)	16,453
Net income (loss) and comprehensive income (loss) including noncontrolling interests	42,168	$ 1,025,756	(67,275)	$ 80,810	1,067,924	13,535
Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests			69,110		46,993	135,087
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	42,168		(136,385)		1,020,931	(121,552)
Natural gas sales
Revenue and other:
Revenues from contracts with customers	553,372		473,540		1,210,638	971,203
Natural gas liquids sales
Revenue and other:
Revenues from contracts with customers	303,963		255,985		617,648	490,155
Oil sales
Revenue and other:
Revenues from contracts with customers	49,062		38,873		97,114	69,146
Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers			5,518		4,479	10,453
Operating expenses:
Cost of goods and services sold	566,834		307,786		991,363	599,724
Marketing
Revenue and other:
Revenues from contracts with customers	63,080		160,202		154,266	304,591
Operating expenses:
Cost of goods and services sold	137,539		213,420		300,623	409,159
Exploration
Operating expenses:
Cost of goods and services sold	314		1,471		440	3,356
Lease operating
Operating expenses:
Cost of goods and services sold	40,857		30,164		82,589	56,886
Other income
Revenue and other:
Revenues from contracts with customers	1,760				1,867
Reportable legal entity | Parent (Antero)
Revenue and other:
Commodity derivative fair value gains (losses)	328,427		55,336		251,059	77,773
Marketing derivative gains			(110)			94,124
Loss on sale of assets	951				951
Total revenue	1,299,664		989,005		2,334,243	2,018,046
Operating expenses:
Production and ad valorem taxes	30,968		24,886		65,706	49,693
Impairment of oil and gas properties	130,999		134,437		212,243	184,973
Impairment of gathering systems and facilities			4,470			4,470
Depletion, depreciation, and amortization	242,302		201,617		460,796	397,429
Accretion of asset retirement obligations	918		666		1,831	1,322
General and administrative	42,382		46,662		92,290	93,082
Contract termination and rig stacking	5,604				13,964
Accretion of contingent acquisition consideration						(7,821)
Total operating expenses	1,199,668		1,069,649		2,334,519	2,001,111
Operating income (loss)	99,996		(80,644)		(276)	16,935
Equity in earnings (loss) of unconsolidated affiliates	13,585				4,999
Interest expense, net	(54,164)		(54,388)		(109,299)	(107,886)
Equity in earnings (loss) of consolidated subsidiaries			(26,926)		15,021	(47,054)
Gain on deconsolidation of Antero Midstream Partners LP					1,205,705
Total other expenses	(40,579)		(81,314)		1,116,426	(154,940)
Income (loss) before income taxes	59,417		(161,958)		1,116,150	(138,005)
Provision for income tax (expense) benefit	(17,249)		25,573		(305,959)	16,453
Net income (loss) and comprehensive income (loss) including noncontrolling interests	42,168		(136,385)		810,191	(121,552)
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation	42,168		(136,385)		810,191	(121,552)
Reportable legal entity | Parent (Antero) | Natural gas sales
Revenue and other:
Revenues from contracts with customers	553,372		473,540		1,210,638	971,203
Reportable legal entity | Parent (Antero) | Natural gas liquids sales
Revenue and other:
Revenues from contracts with customers	303,963		255,985		617,648	490,155
Reportable legal entity | Parent (Antero) | Oil sales
Revenue and other:
Revenues from contracts with customers	49,062		38,873		97,114	69,146
Reportable legal entity | Parent (Antero) | Gathering, compression, water handling and treatment
Operating expenses:
Cost of goods and services sold	566,834		409,708		1,101,849	794,053
Reportable legal entity | Parent (Antero) | Marketing
Revenue and other:
Revenues from contracts with customers	63,080		160,202		154,266	304,591
Operating expenses:
Cost of goods and services sold	137,539		213,420		300,623	409,159
Reportable legal entity | Parent (Antero) | Exploration
Operating expenses:
Cost of goods and services sold	314		1,471		440	3,356
Reportable legal entity | Parent (Antero) | Lease operating
Operating expenses:
Cost of goods and services sold	40,857		32,312		83,826	63,574
Reportable legal entity | Parent (Antero) | Other income
Revenue and other:
Revenues from contracts with customers	$ 1,760		5,179		3,518	11,054
Reportable legal entity | Guarantor Subsidiaries
Operating expenses:
Equity in earnings (loss) of unconsolidated affiliates					10,403
Gain on deconsolidation of Antero Midstream Partners LP					200,337
Total other expenses					210,740
Income (loss) before income taxes					210,740
Net income (loss) and comprehensive income (loss) including noncontrolling interests					210,740
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation					210,740
Reportable legal entity | Non-Guarantor Subsidiaries
Revenue and other:
Loss on sale of assets			(583)			(583)
Total revenue			250,975		218,360	480,566
Operating expenses:
Production and ad valorem taxes			1,005			2,021
Impairment of gathering systems and facilities			4,614		6,982	4,614
Depletion, depreciation, and amortization			36,433		21,707	68,865
Accretion of asset retirement obligations			34		63	68
General and administrative			15,494		18,793	29,949
Accretion of contingent acquisition consideration			3,947		1,928	7,821
Total operating expenses			136,145		114,291	254,196
Operating income (loss)			114,830		104,069	226,370
Equity in earnings (loss) of unconsolidated affiliates			9,264		12,264	17,126
Interest expense, net			(14,628)		(16,815)	(25,925)
Total other expenses			(5,364)		(4,551)	(8,799)
Income (loss) before income taxes			109,466		99,518	217,571
Net income (loss) and comprehensive income (loss) including noncontrolling interests			109,466		99,518	217,571
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation			109,466		99,518	217,571
Reportable legal entity | Non-Guarantor Subsidiaries | Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers			250,392		218,360	479,983
Operating expenses:
Cost of goods and services sold			12,400			23,768
Reportable legal entity | Non-Guarantor Subsidiaries | Lease operating
Operating expenses:
Cost of goods and services sold			62,218		64,818	117,090
Eliminations
Revenue and other:
Loss on sale of assets			583			583
Total revenue			(250,636)		(215,532)	(481,167)
Operating expenses:
Production and ad valorem taxes					940
Impairment of gathering systems and facilities			(583)			(583)
General and administrative			(469)		(499)	(1,314)
Accretion of contingent acquisition consideration			(3,947)		(1,928)	(7,821)
Total operating expenses			(183,687)		(178,028)	(351,593)
Operating income (loss)			(66,949)		(37,504)	(129,574)
Interest expense, net			(333)			36
Equity in earnings (loss) of consolidated subsidiaries			26,926		(15,021)	47,054
Total other expenses			26,593		(15,021)	47,090
Income (loss) before income taxes			(40,356)		(52,525)	(82,484)
Net income (loss) and comprehensive income (loss) including noncontrolling interests			(40,356)		(52,525)	(82,484)
Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests			69,110		46,993	135,087
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation			(109,466)		(99,518)	(217,571)
Eliminations | Gathering, compression, water handling and treatment
Revenue and other:
Revenues from contracts with customers			(244,874)		(213,881)	(469,530)
Operating expenses:
Cost of goods and services sold			(114,322)		(110,486)	(218,097)
Eliminations | Lease operating
Operating expenses:
Cost of goods and services sold			(64,366)		(66,055)	(123,778)
Eliminations | Other income
Revenue and other:
Revenues from contracts with customers			$ (5,179)		$ (1,651)	$ (11,054)

Subsidiary Guarantors - Cash Fl

Subsidiary Guarantors - Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018
Cash flows provided by (used in) operating activities:
Net income including noncontrolling interests	$ 42,168	$ 1,025,756	$ (67,275)	$ 80,810	$ 1,067,924	$ 13,535
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, amortization, and accretion					484,397	467,684
Impairment of oil and gas properties	130,999		134,437		212,243	184,973
Impairment of gathering systems and facilities			8,501		6,982	8,501
Commodity derivative fair value (gains) losses	(328,427)		(55,336)		(251,059)	(77,773)
Gains on settled commodity derivatives					141,791	197,225
Marketing derivative fair value (gains) losses			110			(94,124)
Gains on settled marketing derivatives						94,158
Deferred income tax expense (benefit)					304,963	(16,453)
Gain on sale of assets	951				951
Equity-based compensation expense	6,549		19,071		15,452	40,227
Equity in earnings of unconsolidated affiliates	(13,585)		(9,264)		(27,666)	(17,126)
Distributions of earnings from unconsolidated affiliates					60,527	17,895
Gain on deconsolidation of Antero Midstream Partners LP					(1,406,042)
Other					5,670	1,932
Changes in current assets and liabilities					140,975	18,286
Net cash provided by operating activities					757,108	838,940
Cash flows provided by (used in) investing activities:
Additions to unproved properties					(56,814)	(87,861)
Drilling and completion costs					(680,088)	(752,781)
Additions to water handling and treatment systems					(24,416)	(58,127)
Additions to gathering systems and facilities					(48,239)	(206,753)
Additions to other property and equipment					(4,629)	(3,502)
Investments in unconsolidated affiliates					(25,020)	(56,297)
Proceeds from the Antero Midstream Partners LP Transactions					296,611
Change in other assets					(4,974)	(7,026)
Proceeds from sale of assets					1,983
Net cash used in investing activities					(545,586)	(1,172,347)
Cash flows provided by (used in) financing activities:
Issuance of senior notes					650,000
Borrowings (repayments) on bank credit facilities, net					(145,000)	485,000
Payments of deferred financing costs					(8,259)
Distributions to noncontrolling interests in Antero Midstream Partners LP					(85,076)	(119,023)
Employee tax withholding for settlement of equity compensation awards					(2,295)	(7,967)
Other					(1,360)	(2,436)
Net cash provided by financing activities					408,010	355,574
Effect of deconsolidation of Antero Midstream Partners LP					(619,532)
Net increase (decrease) in cash and cash equivalents						22,167
Cash and cash equivalents, beginning of period				28,441		28,441
Cash and cash equivalents, end of period			50,608			50,608
Reportable legal entity | Parent (Antero)
Cash flows provided by (used in) operating activities:
Net income including noncontrolling interests	42,168		(136,385)		810,191	(121,552)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, amortization, and accretion					462,627	398,751
Accretion of contingent acquisition consideration						(7,821)
Impairment of oil and gas properties	130,999		134,437		212,243	184,973
Impairment of gathering systems and facilities			4,470			4,470
Commodity derivative fair value (gains) losses	(328,427)		(55,336)		(251,059)	(77,773)
Gains on settled commodity derivatives					141,791	197,225
Marketing derivative fair value (gains) losses			110			(94,124)
Gains on settled marketing derivatives						94,158
Deferred income tax expense (benefit)					304,963	(16,453)
Gain on sale of assets	951				951
Equity-based compensation expense					12,975	28,149
Equity in earnings of consolidated subsidiaries			26,926		(15,021)	47,054
Equity in earnings of unconsolidated affiliates	$ (13,585)				(4,999)
Distributions of earnings from unconsolidated affiliates					47,922
Gain on deconsolidation of Antero Midstream Partners LP					(1,205,705)
Distributions from subsidiaries					94,391	74,647
Other					(43,002)	547
Changes in current assets and liabilities					134,740	14,510
Net cash provided by operating activities					703,008	726,761
Cash flows provided by (used in) investing activities:
Additions to unproved properties					(56,814)	(87,861)
Drilling and completion costs					(700,653)	(887,459)
Additions to other property and equipment					(3,567)	(3,502)
Proceeds from the Antero Midstream Partners LP Transactions					296,611
Change in other assets					(1,617)	2,051
Proceeds from sale of assets					1,983
Net cash used in investing activities					(464,057)	(976,771)
Cash flows provided by (used in) financing activities:
Borrowings (repayments) on bank credit facilities, net					(235,379)	270,000
Payments of deferred financing costs					(791)
Employee tax withholding for settlement of equity compensation awards					(2,266)	(6,649)
Other					(515)	(2,336)
Net cash provided by financing activities					(238,951)	261,015
Net increase (decrease) in cash and cash equivalents						11,005
Cash and cash equivalents, beginning of period				20,078		20,078
Cash and cash equivalents, end of period			31,083			31,083
Reportable legal entity | Guarantor Subsidiaries
Cash flows provided by (used in) operating activities:
Net income including noncontrolling interests					210,740
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Equity in earnings of unconsolidated affiliates					(10,403)
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 including noncontrolling interests			109,466		99,518	217,571
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, amortization, and accretion					21,770	68,933
Accretion of contingent acquisition consideration			3,947		1,928	7,821
Impairment of gathering systems and facilities			4,614		6,982	4,614
Gain on sale of assets			(583)			(583)
Equity-based compensation expense					2,477	12,078
Equity in earnings of unconsolidated affiliates			(9,264)		(12,264)	(17,126)
Distributions of earnings from unconsolidated affiliates					12,605	17,895
Other					750	1,385
Changes in current assets and liabilities					(10,573)	(157)
Net cash provided by operating activities					121,265	312,431
Cash flows provided by (used in) investing activities:
Additions to water handling and treatment systems					(24,547)	(49,054)
Additions to gathering systems and facilities					(48,239)	(206,753)
Additions to other property and equipment					(1,062)
Investments in unconsolidated affiliates					(25,020)	(56,297)
Change in other assets					(3,357)	(9,077)
Net cash used in investing activities					(102,225)	(321,181)
Cash flows provided by (used in) financing activities:
Issuance of senior notes					650,000
Borrowings (repayments) on bank credit facilities, net					90,379	215,000
Payments of deferred financing costs					(7,468)
Distributions to noncontrolling interests in Antero Midstream Partners LP					(131,545)	(193,670)
Employee tax withholding for settlement of equity compensation awards					(29)	(1,318)
Other					(845)	(100)
Net cash provided by financing activities					600,492	19,912
Effect of deconsolidation of Antero Midstream Partners LP					(619,532)
Net increase (decrease) in cash and cash equivalents						11,162
Cash and cash equivalents, beginning of period				$ 8,363		8,363
Cash and cash equivalents, end of period			19,525			19,525
Eliminations
Cash flows provided by (used in) operating activities:
Net income including noncontrolling interests			(40,356)		(52,525)	(82,484)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Accretion of contingent acquisition consideration			(3,947)		(1,928)	(7,821)
Impairment of gathering systems and facilities			(583)			(583)
Gain on sale of assets			583			583
Equity in earnings of consolidated subsidiaries			$ (26,926)		15,021	(47,054)
Distributions from subsidiaries					(94,391)	(74,647)
Other					47,922
Changes in current assets and liabilities					16,808	3,933
Net cash provided by operating activities					(67,165)	(200,252)
Cash flows provided by (used in) investing activities:
Drilling and completion costs					20,565	134,678
Additions to water handling and treatment systems					131	(9,073)
Net cash used in investing activities					20,696	125,605
Cash flows provided by (used in) financing activities:
Distributions to noncontrolling interests in Antero Midstream Partners LP					46,469	74,647
Net cash provided by financing activities					$ 46,469	$ 74,647