Extraction Oil & Gas (XOG) 10-Q 11 May 20 2020 Q1 Quarterly report Financial data

Cover

Cover - shares	3 Months Ended
	Mar. 31, 2020	May 08, 2020
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	001-37907
Entity Registrant Name	EXTRACTION OIL & GAS, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-1473923
Entity Address, Address Line One	370 17th Street
Entity Address, Address Line Two	Suite 5300
Entity Address, City or Town	Denver,
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80202
City Area Code	720
Local Phone Number	557-8300
Title of 12(b) Security	Common Stock, par value $0.01
Trading Symbol	XOG
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		138,135,046
Amendment Flag	false
Entity Central Index Key	0001655020
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Amendment Description

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)	Mar. 31, 2020	Dec. 31, 2019
Current Assets:
Cash and cash equivalents	$ 31,993,000	$ 32,382,000
Accounts receivable
Trade	49,878,000	32,009,000
Oil, natural gas and NGL sales	38,850,000	105,103,000
Inventory, prepaid expenses and other	34,494,000	36,702,000
Commodity derivative asset	164,330,000	17,554,000
Total Current Assets	319,545,000	223,750,000
Property and Equipment (successful efforts method), at cost:
Proved oil and gas properties	4,676,967,000	4,530,934,000
Unproved oil and gas properties	417,021,000	524,214,000
Wells in progress	154,981,000	149,733,000
Less: accumulated depletion, depreciation, amortization and impairment charges	(3,057,098,000)	(2,985,983,000)
Net oil and gas properties	2,191,871,000	2,218,898,000
Gathering systems and facilities, net of accumulated depreciation	0	315,777,000
Other property and equipment, net of accumulated depreciation	72,589,000	72,542,000
Net Property and Equipment	2,264,460,000	2,607,217,000
Non-Current Assets:
Commodity derivative asset	88,783,000	13,229,000
Other non-current assets	30,600,000	82,761,000
Total Non-Current Assets	119,383,000	95,990,000
Total Assets	2,703,388,000	2,926,957,000
Current Liabilities:
Accounts payable and accrued liabilities	163,057,000	190,864,000
Accounts Payable and Accrued Liabilities, Related Party	46,777,000	0
Revenue payable	104,702,000	108,493,000
Production taxes payable	115,556,000	115,489,000
Commodity derivative liability	716,000	1,998,000
Accrued interest payable	18,042,000	20,625,000
Asset retirement obligations	15,328,000	27,058,000
Total Current Liabilities	464,178,000	464,527,000
Non-Current Liabilities:
Credit facility	470,000,000	470,000,000
Senior Notes, net of unamortized debt issuance costs	1,086,347,000	1,085,777,000
Production taxes payable	119,675,000	98,740,000
Commodity derivative liability	0	108,000
Other non-current liabilities	59,689,000	54,579,000
Asset retirement obligations	78,445,000	68,850,000
Deferred tax liability	2,200,000	0
Total Non-Current Liabilities	1,816,356,000	1,778,054,000
Total Liabilities	2,280,534,000	2,242,581,000
Commitments and Contingencies—Note 13
Series A Convertible Preferred Stock, $0.01 par value; 50,000,000 shares authorized, 185,280 issued and outstanding	182,157,000	175,639,000
Stockholders' Equity:
Common stock, $0.01 par value; 900,000,000 share authorized; 137,891,740 and 137,657,922 issued and outstanding, respectively	1,336,000	1,336,000
Additional paid-in capital	170,138,000	170,138,000
Additional paid-in capital	2,143,670,000	2,156,383,000
Accumulated deficit	(1,734,171,000)	(1,743,208,000)
Total Extraction Oil & Gas, Inc. Stockholders' Equity	240,697,000	244,373,000
Noncontrolling interest	0	264,364,000
Total Stockholders' Equity	240,697,000	508,737,000
Total Liabilities and Stockholders' Equity	$ 2,703,388,000	$ 2,926,957,000

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - $ / shares	Mar. 31, 2020	Dec. 31, 2019
Series A Convertible Preferred Stock
Convertible Preferred Stock, par value (in dollars per share)	$ 0.01	$ 0.01
Convertible Preferred Stock, shares authorized (in shares)	50,000,000	50,000,000
Convertible Preferred Stock, shares issued (in shares)	185,280	185,280
Convertible Preferred Stock, shares outstanding (in shares)	185,280	185,280
Common stock, par value and other disclosures
Common stock, Par value per share (in dollars per share)	$ 0.01	$ 0.01
Common Stock, shares authorized (in shares)	900,000,000	900,000,000
Common Stock, shares issued (in shares)	137,891,740	137,891,740
Common Stock, shares outstanding (in shares)	137,657,922	137,657,922
Treasury Stock, Shares	38,859,078	38,859,078

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Revenues:
Revenues	$ 165,187,000	$ 221,917,000
Operating Expenses:
Lease operating expense	30,390,000	21,857,000
Production taxes	13,454,000	18,129,000
Exploration and abandonment expenses	112,480,000	6,194,000
Depletion, depreciation, amortization and accretion	76,051,000	118,770,000
Impairment of long lived assets	775,000	8,248,000
Gain on sale of property and equipment	0	(222,000)
General and administrative expense	10,596,000	27,652,000
Other Cost and Expense, Operating	52,575,000	0
Total Operating Expenses	323,042,000	210,993,000
Operating Income (Loss)	(157,855,000)	10,924,000
Other Income (Expense):
Commodity derivatives gain (loss)	263,015,000	(122,091,000)
Loss on deconsolidation of Elevation Midstream, LLC	(73,139,000)	0
Interest expense	(21,358,000)	(13,008,000)
Other income	574,000	1,143,000
Total Other Income (Expense)	169,092,000	(133,956,000)
Income (Loss) Before Income Taxes	11,237,000	(123,032,000)
Income tax (expense) benefit	(2,200,000)	29,000,000
Net Loss	9,037,000	(94,032,000)
Net income attributable to noncontrolling interest	6,160,000	3,975,000
Net Income (Loss) Attributable to Extraction Oil & Gas, Inc.	(2,877,000)	98,007,000
Adjustments to reflect Series A Preferred Stock dividends and accretion of discount	(6,518,000)	(4,317,000)
Net Loss Available to Common Shareholders, Basic and Diluted	$ (3,641,000)	$ (102,324,000)
Earnings Per Common Share
Basic and diluted (in dollars per share)	$ (0.03)	$ (0.60)
Weighted Average Common Shares Outstanding
Basic and diluted (in shares)	137,726	170,702
Oil sales
Revenues:
Revenues	$ 124,219,000	$ 165,424,000
Natural gas sales
Revenues:
Revenues	22,302,000	35,892,000
NGL sales
Revenues:
Revenues	17,193,000	20,601,000
Transporting And Gathering
Revenues:
Revenues	1,473,000	0
Operating Expenses:
Transportation and gathering	22,786,000	10,365,000
Natural Gas, Midstream [Member]
Operating Expenses:
Transportation and gathering	$ 3,935,000	$ 0

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY - USD ($) shares in Thousands	Total	Common Stock	Treasury Stock	Additional Paid in Capital	Accumulated Deficit	Extraction Oil & Gas, Inc. Stockholders' Equity	Noncontrolling Interest
Balance at beginning of period (in units or shares) at Dec. 31, 2018		176,210	4,543
Balance at beginning of period at Dec. 31, 2018	$ 1,894,686,000	$ 1,678,000	$ (32,737,000)	$ 2,153,661,000	$ (375,788,000)	$ 1,746,814,000	$ 147,872,000
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Preferred Units commitment fees and dividends paid-in-kind	(3,975,000)			(3,975,000)		(3,975,000)	(3,975,000)
Preferred Units issuance costs	10,000						10,000
Series A Preferred Stock dividends	(2,721,000)			(2,721,000)		(2,721,000)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,596,000			1,596,000		1,596,000
Share-based compensation (in shares)		0
Stock-based compensation	13,008,000					13,008,000
Restricted stock issued, net of tax withholdings	(454,000)			(454,000)		(454,000)
Repurchased of common stock (in shares)			(7,824)
Repurchase of common stock	(32,212,000)	$ (77,000)	$ (32,135,000)			(32,212,000)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		270
Net loss	(94,032,000)			0	(94,032,000)	(94,032,000)
Balance at end of period (in units or shares) at Mar. 31, 2019		176,480	12,367
Balance at end of period at Mar. 31, 2019	1,776,669,000	$ 1,601,000	$ (64,872,000)	2,157,923,000	(469,820,000)	1,624,832,000	151,837,000
Balance at beginning of period (in units or shares) at Dec. 31, 2019		176,517	38,859
Balance at beginning of period at Dec. 31, 2019	508,737,000	$ 1,336,000	$ (170,138,000)	2,156,383,000	(1,743,208,000)	244,373,000	264,364,000
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Preferred Units commitment fees and dividends paid-in-kind	(6,160,000)			(6,160,000)		(6,160,000)	(6,160,000)
Series A Preferred Stock dividends	(4,748,000)			(4,748,000)		(4,748,000)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,770,000			1,770,000		1,770,000
Restricted stock issued, net of tax withholdings	(35,000)			(35,000)		(35,000)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		234
Net loss	9,037,000				9,037,000	9,037,000
Effect of Deconsolidation of An Entity	(270,524,000)						(270,524,000)
Balance at end of period (in units or shares) at Mar. 31, 2020		176,751	38,859
Balance at end of period at Mar. 31, 2020	$ 240,697,000	$ 1,336,000	$ (170,138,000)	$ 2,143,670,000	$ (1,734,171,000)	$ 240,697,000	$ 0

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Cash flows from operating activities:
Net loss	$ 9,037,000	$ (94,032,000)
Reconciliation of net income (loss) to net cash provided by operating activities:
Depletion, depreciation, amortization and accretion	76,051,000	118,770,000
Abandonment and impairment of unproved properties	106,928,000	3,893,000
Impairment of long lived assets	775,000	8,248,000
Gain on sale of property and equipment	0	(222,000)
Gain on repurchase of 2026 Senior Notes	0	(7,317,000)
Amortization of debt issuance costs	1,242,000	1,498,000
Non-cash lease expense	4,871,000	2,486,000
Increase (Decrease) in Contract with Customer, Asset	8,465,000	0
Commodity derivatives (gain) loss	(263,015,000)	122,091,000
Settlements on commodity derivatives	24,932,000	(3,538,000)
Earnings in unconsolidated subsidiaries	(480,000)	(338,000)
Loss on deconsolidation of Elevation Midstream, LLC	(73,139,000)	0
Distributions from unconsolidated subsidiaries	0	1,751,000
Deferred income tax expense (benefit)	2,200,000	(29,000,000)
Stock-based compensation	0	13,008,000
Changes in current assets and liabilities:
Accounts receivable—trade	(9,127,000)	11,908,000
Accounts receivable—oil, natural gas and NGL sales	66,253,000	2,981,000
Inventory, prepaid expenses and other	584,000	136,000
Accounts payable and accrued liabilities	(7,699,000)	(10,638,000)
Increase (Decrease) in Accounts Payable and Accrued Liabilities, Related Party	46,777,000	0
Revenue payable	(1,690,000)	(21,506,000)
Production taxes payable	21,002,000	22,919,000
Accrued interest payable	(2,583,000)	(4,429,000)
Asset retirement expenditures	(10,563,000)	(4,558,000)
Net cash provided by operating activities	147,099,000	134,111,000
Cash flows from investing activities:
Oil and gas property additions	(143,000,000)	(188,027,000)
Sale of property and equipment	12,117,000	16,521,000
Gathering systems and facilities additions, net of cost reimbursements	4,193,000	(49,175,000)
Other property and equipment additions	(2,980,000)	(8,213,000)
Investment in unconsolidated subsidiaries	(10,033,000)	(4,929,000)
Distributions from unconsolidated subsidiary, return of capital	0	1,448,000
Net cash used in investing activities	(139,703,000)	(232,375,000)
Cash flows from financing activities:
Borrowings under credit facility	70,000,000	65,000,000
Repayments under credit facility	(70,000,000)	(25,000,000)
Repurchase of 2026 Senior Notes	0	(28,460,000)
Repurchase of common stock	0	(32,212,000)
Payment of employee payroll withholding taxes	(35,000)	(454,000)
Dividends on Series A Preferred Stock	0	(2,721,000)
Debt and equity issuance costs	(22,000)	(94,000)
Preferred Unit issuance costs	0	10,000
Net cash used in financing activities	(57,000)	(23,951,000)
Effect of deconsolidation of Elevation Midstream, LLC	(7,728,000)	0
Decrease in cash and cash equivalents	(389,000)	(122,215,000)
Cash, cash equivalents at beginning of period	32,382,000	234,986,000
Cash, cash equivalents at end of the period	31,993,000	112,771,000
Supplemental cash flow information:
Property and equipment included in accounts payable and accrued liabilities	99,602,000	143,168,000
Cash paid for interest	24,865,000	25,265,000
Accretion of beneficial conversion feature of Series A Preferred Stock	1,770,000	1,596,000
Preferred Units commitment fees and dividends paid-in-kind	6,160,000	3,975,000
Series A Preferred Stock Dividends	$ 4,748,000	$ 0

Business and Organization

Business and Organization	3 Months Ended
	Mar. 31, 2020
Limited Liability Company or Limited Partnership, Business Organization and Operations [Abstract]
Business and Organization	Business and Organization Extraction Oil & Gas, Inc. (the "Company" or "Extraction") is an independent oil and gas company focused on the acquisition, development and production of oil, natural gas and natural gas liquids (“NGLs”) reserves in the Rocky Mountain region, primarily in the Wattenberg Field of the Denver-Julesburg Basin (the "DJ Basin") of Colorado, as well as the construction and support of midstream assets to gather and process crude oil and gas production. Extraction is a public company listed for trading on the NASDAQ Global Select Market under the symbol "XOG." Deconsolidation of Elevation Midstream, LLC Elevation Midstream, LLC ("Elevation"), a Delaware limited liability company, is focused on the construction and operation of gathering systems and facilities to serve the development of acreage in the Company’s Hawkeye and Southwest Wattenberg areas. Midstream assets of Elevation are represented as the gathering systems and facilities line item within the condensed consolidated balance sheets. During the first quarter of 2020, Elevation's non-controlling interest owner, which owns 100% of Elevation's preferred stock, per contractual agreement, expanded Elevation's then five member board of managers by four seats and filled them with managers of their choosing (the "Board Expansion"). Because Extraction had the right to appoint only three of the managers of Elevation before and after Board Expansion, Extraction determined the Company had lost voting control of Elevation, and on March 16, 2020 deconsolidated Elevation and began accounting for the entity as an equity method investment. Though Extraction determined control of Elevation was lost under the voting interest model of consolidation, the Company also determined significant influence was not lost due to (1) Extraction owning 100% of the common stock, (2) Extraction appointing three of the nine managers of Elevation and (3) Extraction's continuing involvement in the day-to-day operation of Elevation through a management services agreement. Because Extraction also determined the Company is not the primary beneficiary, Elevation Midstream, LLC is not a variable interest entity. Extraction elected the fair value option to remeasure the Elevation equity method investment and determined it had no fair value. The Company recorded a $73.1 million loss on deconsolidation of the investment in the condensed consolidated statements of operations for the three months ended March 31, 2020. Also, as of March 31, 2020, Elevation determined certain gathering systems and facilities were impaired by $50.3 million as a result of the abandonment of certain projects. In accordance with Accounting Standards Codification Topic 323-10-35-20: Investments—equity method and joint ventures , Extraction discontinued applying the equity method investment for Elevation as the impairment charge would have reduced the investment below zero. On May 1, 2020, Elevation's board of managers issued 1,530,000,000 common units at a price of $0.01 per unit to certain of Elevation's members other than Extraction (the "Capital Raise"). The Capital Raise caused Extraction's ownership of Elevation to be diluted to less than 0.01%. As a result of the Capital Raise, beginning in May 2020 Extraction will account for Elevation under the cost method of accounting. The Company reserves all rights related to actions taken by Elevation’s board of managers.

Basis of Presentation, Signific

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements	3 Months Ended
	Mar. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements	Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements Basis of Presentation The unaudited condensed consolidated financial statements include the accounts of the Company, including its wholly owned subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation. The financial statements included herein were prepared from the records of the Company in accordance with generally accepted accounting principles in the United States (“GAAP”) and the Securities and Exchange Commission rules and regulation for interim financial reporting. In the opinion of management, all adjustments, consisting primarily of normal recurring accruals that are considered necessary for a fair statement of the unaudited condensed consolidated financial information, have been included. However, operating results for the period presented are not necessarily indicative of the results that may be expected for a full year. Interim condensed consolidated financial statements and the year-end balance sheets do not include all of the information and notes required by GAAP for audited annual consolidated financial statements. These unaudited condensed consolidated financial statements should be read in conjunction with the Company’s audited consolidated financial statements and notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2019 (“Annual Report”). Significant Accounting Policies The significant accounting policies followed by the Company are set forth in Note 2 to the Company’s consolidated financial statements in its Annual Report and are supplemented by the notes to the unaudited condensed consolidated financial statements in this report. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes included in the Company’s Annual Report. Revenue — Contract Balances The Company has a certain revenue contract with an initial term beginning on November 1, 2016 and continuing until October 31, 2020 after which the contract begins an automatic month-to-month renewal unless terminated by either party giving notice at least 180 days prior to the effective termination date but in no event can either party give such notice earlier than November 1, 2020. Based on the accounting treatment pursuant to ASC 606 - Revenue from Contracts with Customers, the contract term ends on April 30, 2021 because it may be terminated by either party with no penalty effective as of such date. The contract term impacts the amount of consideration that can be included in the transaction price. Generally, under the Company's various sales contracts, the Company invoices customers once its performance obligations have been satisfied, at which point payment is unconditional. For the three months ended March 31, 2020, the Company allocated $8.5 million to a satisfied performance obligation recognized within oil sales under ASC 606. As of March 31, 2020, the Company estimated a performance obligation under ASC 606 of $46.2 million, of which $3.9 million is recorded in accounts payable and accrued liabilities and $42.3 million is recorded in other non-current liabilities. A corresponding asset was recorded in the amount of $13.0 million, of which $12.1 million is recorded in inventory, prepaid expenses and other and $0.9 million is recorded in other non-current assets. The asset will be amortized into revenue over the contractual term of the contract, and the liability will be relieved if a deficiency payment is made to the counterparty or when the Company's minimum volume commitments are fulfilled. Other Operating Expenses Other operating expenses were $52.6 million for the three months ended March 31, 2020. This amount is primarily made up of a $46.8 million loss contingency from an alleged breach in contract stemming from a purported failure to complete the pipeline extensions connecting certain wells to the Badger central gathering facility prior to April 1, 2020. Please see Note 13—Commitments and Contingencies for further details. Also included in this amount is a $5.8 million charge to income for expenses related to a workforce reduction in February 2020. Impairment of Oil and Gas Properties The Company identified an impairment triggering event for its proved oil and gas properties as of March 31, 2020 due to the significant decrease in oil and gas prices during the first quarter of 2020. As such, the Company performed a quantitative assessment as of March 31, 2020, and proved property in its northern field was impaired. For the three months ended March 31, 2020 and 2019, the Company recognized $0.8 million and $8.2 million, respectively, in impairment expense on its proved oil and gas properties related to impairment of assets in its northern field. The fair value did not exceed the Company's carrying amount associated with its proved oil and gas properties in its northern field. The Company did not have any proved property impairment in its Core DJ Basin field, primarily because of the $1.3 billion impairment charge that was recorded in the fourth quarter of 2019. Of the Company's $112.5 million in exploration and abandonment expenses for the three months ended March 31, 2020, $106.9 million was lease abandonment expense. Unproved oil and gas properties consist of costs to acquire unevaluated leases as well as costs to acquire unproved reserves. The Company evaluates significant unproved oil and gas properties for impairment based on remaining lease term, drilling results, reservoir performance, seismic interpretation or future plans to develop acreage. When successful wells are drilled on undeveloped leaseholds, unproved property costs are reclassified to proved properties and depleted on a unit-of-production basis. Impairment expense and lease extension payments for unproved properties is reported in exploration and abandonment expenses in the condensed consolidated statements of operations. Recent Accounting Pronouncements In June 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-13, Financial Instruments—Credit Losses. In May 2019, ASU No. 2016-13 was subsequently amended by ASU No. 2019-04, Codification Improvements to Topic 326, Financial Instruments—Credit Losses and ASU No. 2019-05, Financial Instruments—Credit Losses (Topic 326): Targeted Transition Relief. ASU No. 2016-13, as amended, affects trade receivables, financial assets and certain other instruments that are not measured at fair value through net income. This ASU replaced the incurred loss approach with an expected loss model for instruments measured at amortized cost and was effective for financial statements issued for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. ASU No. 2016-13 will be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Company adopted this ASU on January 1, 2020, and the adoption did not have a material impact on the consolidated financial statements and related disclosures. In August 2018, the FASB issued ASU No. 2018-13, which removes or modifies current fair value disclosures and adds additional disclosures. The update to the guidance is the result of the FASB's test of the principles developed in its disclosure effectiveness project, which is designed to improve the effectiveness of disclosures in the notes to the financial statements. The disclosures that have been removed or modified may be applied immediately with retrospective application. For public entities, the new guidance was effective for fiscal years beginning after December 15, 2019, including interim reporting periods within that reporting period. The Company adopted this ASU on January 1, 2020, and the adoption did not have a material impact on the consolidated financial statements and related disclosures. In August 2018, the FASB issued ASU No. 2018-15, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software and hosting arrangements that include an internal-use software license. For public entities, the guidance is effective for fiscal years beginning after December 15, 2019, including interim reporting periods within that reporting period. The Company adopted this ASU on January 1, 2020 which did not have a material impact on the consolidated financial statements and related disclosures as capitalized costs for internal-use software were not material as of March 31, 2020. Other than as disclosed above or in the Company’s Annual Report, there are no other accounting standards applicable to the Company as of March 31, 2020 and through the date of this filing that would have a material effect on the Company’s unaudited condensed consolidated financial statements and related disclosures that have been issued but not yet adopted by the Company.

Acquisitions

Acquisitions	3 Months Ended
	Mar. 31, 2020
Business Combinations [Abstract]
Acquisitions	Divestitures February 2020 Divestiture In February 2020, the Company completed the sale of certain non-operated producing properties for aggregate sales proceeds of approximately $12.2 million, subject to customary purchase price adjustments. No gain or loss was recognized for the February 2020 Divestiture. The Company continues to explore divestitures as part of our ongoing initiative to divest non-strategic assets. December 2019 Divestiture In December 2019, the Company completed the sale of certain non-operated producing properties for aggregate sales proceeds of approximately $10.0 million, subject to customary purchase price adjustments. No gain or loss was recognized for the December 2019 Divestiture. August 2019 Divestiture In August 2019, the Company completed the sale of certain non-operated producing properties for aggregate sales proceeds of approximately $22.0 million, subject to customary purchase price adjustments. No gain or loss was recognized for the August 2019 Divestiture. March 2019 Divestiture

Going Concern

Going Concern	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Going Concern	Going Concern The Company depends on cash flows from operating activities and, as necessary and available, borrowings under its senior secured revolving credit facility (the “revolving credit facility”) to fund its capital expenditures and working capital requirements. Additionally, the Company historically has used proceeds from the issuance of equity and debt securities in the capital markets and from sales or other monetizations of assets to fund its capital expenditures and working capital requirements. The market price for oil, natural gas and NGLs decreased significantly beginning in the first quarter of 2020, continuing into the second quarter of 2020. The decrease in the market price for the Company’s production directly reduces the Company’s cash flow from operations and indirectly impacts its other potential sources of funds described above. The Company has reduced its 2020 upstream capital budget and as a result expects to suspend drilling in the second half of 2020 and does not see production returning to historical levels for the foreseeable future. As discussed in Note 5—Long-Term Debt , lenders under the revolving credit facility elected to reduce the borrowing base and elected commitments to $650.0 million from $950.0 million on April 27, 2020, and the Company borrowed all of its remaining available capacity under the revolving credit facility. As a result of the reduction of the borrowing base and elected commitments, it is probable that the Company will not meet the financial covenants under the revolving credit facility for the three months ended June 30, 2020 when assuming the Company’s current financial forecast. If the Company does not obtain a waiver of its financial covenants for the three months ended June 30, 2020, the lenders under the revolving credit facility will be able to accelerate maturity of the debt. Any acceleration of the obligations under the revolving credit facility would result in a cross-default and potential acceleration of the maturity of the Company’s other outstanding long-term debt amounting to approximately $1.1 billion. These defaults create uncertainty associated with the Company’s ability to repay its outstanding long-term debt obligations as they become due and creates a substantial doubt over the Company’s ability to continue as a going concern. As a result of the impacts to the Company’s financial position resulting from declining commodity price conditions and in consideration of the substantial amount of long-term debt and preferred stock outstanding, the Company has engaged advisors to assist with the evaluation of strategic alternatives, which may include, but not be limited to, seeking a restructuring, amendment or refinancing of existing debt through a private restructuring or reorganization under Chapter 11 of the Bankruptcy Code. However, there can be no assurances that the Company will be able to successfully restructure its indebtedness, improve its financial position or complete any strategic transactions. As a result of these uncertainties and the likelihood of a restructuring or reorganization, management has concluded that there is substantial doubt regarding the Company’s ability to continue as a going concern. The consolidated financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets and satisfaction of liabilities and commitments in the normal course of business. The consolidated financial statements do not reflect any adjustments that might result if the Company is unable to continue as a going concern.

Long Term Debt

Long Term Debt	3 Months Ended
	Mar. 31, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt The Company’s long-term debt consisted of the following (in thousands): March 31, December 31, Credit facility due August 16, 2022 (or an earlier time as set forth in the credit facility) $ 470,000 $ 470,000 2024 Senior Notes due May 15, 2024 400,000 400,000 2026 Senior Notes due February 1, 2026 700,189 700,189 Unamortized debt issuance costs on Senior Notes (13,842) (14,412) Total long-term debt 1,556,347 1,555,777 Less: current portion of long-term debt — — Total long-term debt, net of current portion $ 1,556,347 $ 1,555,777 Credit Facility In August 2017, the Company entered into an amendment and restatement of its existing credit facility (prior to amendment and restatement, the "Prior Credit Facility"), to provide aggregate commitments of $1.5 billion with a syndicate of banks, which is subject to a borrowing base. The credit facility matures on the earlier of (a) August 16, 2022, (b) April 15, 2021, if (and only if) (i) the Series A Preferred Stock have not been converted into common equity or redeemed prior to April 15, 2021 (the Company can redeem the Series A Preferred Stock at any time), and (ii) prior to April 15, 2021, the maturity date of the Series A Preferred Stock has not been extended to a date that is no earlier than six months after August 16, 2022 or (c) the earlier termination in whole of the commitments under the credit facility. No principal payments are generally required until the credit agreement matures or in the event that the borrowing base falls below the outstanding balance. As of March 31, 2020, the credit facility had a maximum credit amount of $1.5 billion, subject to a borrowing base and elected commitments of $950.0 million. As of March 31, 2020 and December 31, 2019, the Company had outstanding borrowings of $470.0 million and had standby letters of credit of $49.5 million which reduces the availability of the undrawn borrowing base. At March 31, 2020, the undrawn balance under the credit facility was $480.0 million before letters of credit. The amount available to be borrowed under the Company’s revolving credit facility is subject to a borrowing base that is redetermined semiannually on each May 1 and November 1, and will depend on the volumes of the Company’s proved oil and gas reserves, commodity prices, estimated cash flows from these reserves and other information deemed relevant by the administrative agent under the Company’s revolving credit facility. Additionally, the undrawn balance may be constrained by the Company's quantitative covenants under the credit facility, including the current ratio and ratio of consolidated debt less cash balances to its consolidated EBITDAX, at the next required quarterly compliance date. On April 27, 2020, the lenders under our revolving credit facility provided notice to the Company that they had completed the redetermination scheduled to occur on May 1, 2020, and via this redetermination, our borrowing base had been reduced from $950.0 million to $650.0 million. As of May 11, 2020, following this redetermination, the Company had outstanding borrowings of $600.5 million and had standby letters of credit of $49.5 million, which reduce the availability of the undrawn borrowing base. As of the date of this filing, the available balance under the credit facility was zero. Principal amounts borrowed on the credit facility will be payable on the maturity date. We may repay any amounts borrowed prior to the maturity date without any premium or penalty other than customary LIBOR breakage costs. Amounts repaid under the credit facility may be re-borrowed from time to time, subject to the terms of the facility. Interest on the credit facility is payable at one of the following two variable rates as selected by the Company: a base rate based on the Prime Rate or the Eurodollar rate, based on LIBOR. Either rate is adjusted upward by an applicable margin, based on the utilization percentage of the facility as outlined in the pricing grid below. Additionally, the credit facility provides for a commitment fee of 0.375% to 0.50%, depending on borrowing base usage. The grid below shows the Base Rate Margin and Eurodollar Margin depending on the applicable Borrowing Base Utilization Percentage (as defined in the credit facility) as of the date of this filing: Borrowing Base Utilization Grid Eurodollar Base Rate Commitment Borrowing Base Utilization Percentage Utilization Margin Margin Fee Rate Level 1 <25% 1.50 % 0.50 % 0.38 % Level 2 ≥ 25% < 50% 1.75 % 0.75 % 0.38 % Level 3 ≥ 50% < 75% 2.00 % 1.00 % 0.50 % Level 4 ≥ 75% < 90% 2.25 % 1.25 % 0.50 % Level 5 ≥90% 2.50 % 1.50 % 0.50 % The credit facility contains representations, warranties, covenants, conditions and defaults customary for transactions of this type, including but not limited to: (i) limitations on liens and incurrence of debt covenants; (ii) limitations on dividends, distributions, redemptions and restricted payments covenants; (iii) limitations on investments, loans and advances covenants; and (iv) limitations on the sale of property, mergers, consolidations and other similar transactions covenants. Additionally, the credit facility limits the Company entering into hedges in excess of 85% of its anticipated production volumes. The credit facility also contains financial covenants requiring the Company to comply on the last day of each quarter with a current ratio of its restricted subsidiaries’ current assets (includes availability under the revolving credit facility and unrestricted cash and excludes derivative assets) to its restricted subsidiaries’ current liabilities (excludes obligations under the revolving credit facility, senior notes and certain derivative liabilities), of not less than 1.0 to 1.0 and to maintain, on the last day of each quarter, a ratio of its restricted subsidiaries’ debt less cash balances to its restricted subsidiaries EBITDAX (EBITDAX is defined as net income adjusted for interest expense, income tax expense/benefit, DD&A, exploration and abandonment expenses as well as certain non-recurring cash and non-cash charges and income (such as stock-based compensation expense, unrealized gains/losses on commodity derivatives and impairment of long-lived assets and goodwill), subject to pro forma adjustments for non-ordinary course acquisitions and divestitures) for the four fiscal quarter periods most recently ended, of not greater than 4.0 to 1.0 as of the last day of such fiscal quarter. As of March 31, 2020, the Company was in compliance with the covenants under the credit agreement. The Company’s 2020 capital program remains focused on generating free cash flow with an emphasis on strengthening liquidity and the balance sheet as the Company works to pay down debt. However, factors including those outside of the Company’s control may prevent maintaining compliance with such covenants, including commodity price declines and the Company's inability to access capital markets, to access the asset sale market or to execute on its business plan. Additionally, as a result of the reduction of the borrowing base and elected commitments described above, it is probable that the Company will not meet the financial covenants under the revolving credit facility for the three months ended June 30, 2020 under the Company’s current financial forecast. The Company may seek covenant relief from the lenders under the revolving credit facility, and if the Company does not obtain a waiver of its financial covenants for the three months ended June 30, 2020, the lenders under the revolving credit facility will be able to declare all outstanding principal and interest to be due and payable, and the lenders under the credit agreement could terminate their commitments to loan money and could foreclose against the assets collateralizing their borrowings. Any acceleration of the obligations under the revolving credit facility would result in a cross-default and potential acceleration of the maturity of the Company’s other outstanding long-term debt. Any borrowings under the credit facility are collateralized by substantially all of the assets of the Company and certain of its subsidiaries, including oil and gas properties, personal property and the equity interests of those subsidiaries of the Company. The Company has entered into oil and natural gas hedging transactions with several counterparties that are also lenders under the credit facility. The Company’s obligations under these hedging contracts are secured by the collateral securing the credit facility. Elevation is an unrestricted subsidiary, which is no longer consolidated or controlled by the Company, and the assets and credit of Elevation are not available to satisfy the debts and other obligations of the Company or its other subsidiaries. 2024 Senior Notes In August 2017, the Company issued at par $400.0 million principal amount of 7.375% Senior Notes due May 15, 2024 (the "2024 Senior Notes" and the offering, the "2024 Senior Notes Offering"). The 2024 Senior Notes bear an annual interest rate of 7.375%. The interest on the 2024 Senior Notes is payable on May 15 and November 15 of each year which commenced on November 15, 2017. The Company received net proceeds of approximately $392.6 million after deducting fees. The Company's 2024 Senior Notes are its senior unsecured obligations and rank equally in right of payment with all of its other senior indebtedness and senior to any of its subordinated indebtedness. The Company's 2024 Senior Notes are fully and unconditionally guaranteed on a senior unsecured basis by certain of the Company's current subsidiaries and by certain future restricted subsidiaries that guarantees its indebtedness under a credit facility (the "2024 Senior Notes Guarantors"). The 2024 Senior Notes are effectively subordinated to all of the Company's secured indebtedness (including all borrowings and other obligations under its revolving credit facility) to the extent of the value of the collateral securing such indebtedness, and structurally subordinated in right of payment to all existing and future indebtedness and other liabilities (including trade payables) of any of its future subsidiaries that do not guarantee the 2024 Senior Notes. The 2024 Senior Notes also contain affirmative and negative covenants that, among other things, limit the Company's and the 2024 Senior Notes Guarantors' ability to make investments; declare or pay any dividend or make any other payment to holders of the Company’s or any of its 2024 Senior Notes Guarantors’ equity interests; repurchase or redeem any equity interests of the Company; repurchase or redeem subordinated indebtedness; incur additional indebtedness or issue preferred stock; create liens; sell assets; enter into agreements that restrict dividends or other payments by restricted subsidiaries; consolidate, merge or transfer all or substantially all of the assets of the Company; engage in transactions with the Company's affiliates; engage in any business other than the oil and gas business; and create unrestricted subsidiaries. The indenture governing the 2024 Senior Notes also contains customary events of default. Upon the occurrence of events of default arising from certain events of bankruptcy or insolvency, the 2024 Senior Notes shall become due and payable immediately without any declaration or other act of the trustee or the holders of the 2024 Senior Notes. Upon the occurrence of certain other events of default, the trustee or the holders of at least 25% in aggregate principal amount of the then outstanding 2024 Senior Notes may declare all outstanding 2024 Senior Notes to be due and payable immediately. 2026 Senior Notes In January 2018, the Company issued at par $750.0 million principal amount of 5.625% Senior Notes due February 1, 2026 (the "2026 Senior Notes" and together with the 2024 Senior Notes, the "Senior Notes" and the offering of the 2026 Senior Notes, the "2026 Senior Notes Offering"). The 2026 Senior Notes bear an annual interest rate of 5.625%. The interest on the 2026 Senior Notes is payable on February 1 and August 1 of each year commencing on August 1, 2018. The Company received net proceeds of approximately $737.9 million after deducting fees. The Company's 2026 Senior Notes are the Company's senior unsecured obligations and rank equally in right of payment with all of the Company's other senior indebtedness and senior to any of the Company's subordinated indebtedness. The Company's 2026 Senior Notes are fully and unconditionally guaranteed on a senior unsecured basis by certain of the Company's current subsidiaries and by certain future restricted subsidiaries that guarantee the Company's indebtedness under a credit facility (the "2026 Senior Notes Guarantors"). The 2026 Senior Notes are effectively subordinated to all of the Company's secured indebtedness (including all borrowings and other obligations under the Company's revolving credit facility) to the extent of the value of the collateral securing such indebtedness, and structurally subordinated in right of payment to all existing and future indebtedness and other liabilities (including trade payables) of certain of the Company's future restricted subsidiaries that do not guarantee the 2026 Senior Notes. The 2026 Senior Notes also contain affirmative and negative covenants that, among other things, limit the Company's and the 2026 Senior Notes Guarantors' ability to make investments; declare or pay any dividend or make any other payment to holders of the Company's or any of its 2026 Senior Notes Guarantors' equity interests; repurchase or redeem any equity interests of the Company; repurchase or redeem subordinated indebtedness; incur additional indebtedness or issue preferred stock; create liens; sell assets; enter into agreements that restrict dividends or other payments by restricted subsidiaries; consolidate, merge or transfer all or substantially all of the assets of the Company; engage in transactions with the Company’s affiliates; engage in any business other than the oil and gas business; and create unrestricted subsidiaries. The indenture governing the 2026 Senior Notes also contains customary events of default. Upon the occurrence of events of default arising from certain events of bankruptcy or insolvency, the 2026 Senior Notes shall become due and payable immediately without any declaration or other act of the trustee or the holders of the 2026 Senior Notes. Upon the occurrence of certain other events of default, the trustee or the holders of at least 25% in aggregate principal amount of the then outstanding 2026 Senior Notes may declare all outstanding 2026 Senior Notes to be due and payable immediately. Debt Issuance Costs As of March 31, 2020, the Company had debt issuance costs, net of accumulated amortization, of $2.2 million related to its credit facility which has been reflected on the Company's condensed consolidated balance sheets within the line item other non-current assets. As of March 31, 2020, the Company had debt issuance costs net of accumulated amortization of $13.8 million related to its 2024 and 2026 Senior Notes which have been reflected on the Company's condensed consolidated balance sheets within the line item Senior Notes, net of unamortized debt issuance costs. Debt issuance costs include origination, legal, engineering, and other fees incurred in connection with the Company’s credit facility and Senior Notes. For the three months ended March 31, 2020 and March 31, 2019, the Company recorded amortization expense related to the debt issuance costs of $1.2 million and $1.5 million, respectively. Interest Incurred on Long-Term Debt For the three months ended March 31, 2020, the Company incurred interest expense on long-term debt of $22.3 million as compared to $20.8 million for the three months ended March 31, 2019. For the three months ended March 31, 2020, the Company capitalized interest expense on long term debt of $2.1 million as compared to $2.0 million for the three months ended March 31, 2019, which has been reflected in the Company’s consolidated financial statements. Senior Note Repurchase Program On January 4, 2019, the Board of Directors authorized a program to repurchase up to $100.0 million of the Company’s Senior Notes (the “Senior Notes Repurchase Program”). The Company’s Senior Notes Repurchase Program is subject to restrictions under our credit facility and does not obligate it to acquire any specific nominal amount of Senior Notes. For the three months ended March 31, 2020, the Company did not repurchase any Senior Notes. For the three months ended March 31, 2019, the Company repurchased a nominal value of $35.8 million for $28.5 million in connection with the Senior Notes Repurchase Program. Interest expense for the three months ended March 31, 2019 included a $7.3 million gain on debt repurchase related to the Company's Senior Note Repurchase Program.

Commodity Derivative Instrument

Commodity Derivative Instruments	3 Months Ended
	Mar. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Instruments	Commodity Derivative Instruments The Company has entered into commodity derivative instruments, as described below. The Company has utilized swaps, put options and call options to reduce the effect of price changes on a portion of the Company’s future oil and natural gas production. A swap has an established fixed price. When the settlement price is below the fixed price, the counterparty pays the Company an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume. When the settlement price is above the fixed price, the Company pays its counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume. A put option has an established floor price. The buyer of the put option pays the seller a premium to enter into the put option. When the settlement price is below the floor price, the seller pays the buyer an amount equal to the difference between the settlement price and the strike price multiplied by the hedged contract volume. When the settlement price is above the floor price, the put option expires worthless. Some of the Company’s purchased put options have deferred premiums. For the deferred premium puts, the Company agrees to pay a premium to the counterparty at the time of settlement. A call option has an established ceiling price. The buyer of the call option pays the seller a premium to enter into the call option. When the settlement price is above the ceiling price, the seller pays the buyer an amount equal to the difference between the settlement price and the strike price multiplied by the hedged contract volume. When the settlement price is below the ceiling price, the call option expires worthless. The Company combines swaps, purchased put options, purchased call options, sold put options and sold call options in order to achieve various hedging strategies. Some examples of the Company’s hedging strategies are collars which include purchased put options and sold call options, three-way collars which include purchased put options, sold put options and sold call options, and enhanced swaps, which include either sold put options or sold call options with the associated premiums rolled into an enhanced fixed price swap. The objective of the Company’s use of commodity derivative instruments is to achieve more predictable cash flows in an environment of volatile oil and gas prices and to manage its exposure to commodity price risk. While the use of these commodity derivative instruments limits the downside risk of adverse price movements, such use may also limit the Company’s ability to benefit from favorable price movements. The Company may, from time to time, add incremental derivatives to hedge additional production, restructure existing derivative contracts or enter into new transactions to modify the terms of current contracts in order to realize the current value of the Company’s existing positions. The Company does not enter into derivative contracts for speculative purposes. To reduce the impact of fluctuations in oil and natural gas prices on our revenues, we have periodically entered into commodity derivative contracts with respect to certain of our oil and natural gas production through various transactions that limit the downside of future prices received. We plan to continue our practice of entering into such transactions to reduce the impact of commodity price volatility on our cash flow from operations. Future transactions may include price swaps whereby we will receive a fixed price for our production and pay a variable market price to the contract counterparty. Additionally, we may enter into collars, whereby we receive the excess, if any, of the fixed floor over the floating rate or pay the excess, if any, of the floating rate over the fixed ceiling price. These hedging activities are intended to support oil prices at targeted levels and to manage our exposure to oil price fluctuations. The use of derivatives involves the risk that the counterparties to such instruments will be unable to meet the financial terms of such contracts. The Company’s derivative contracts are currently with nine counterparties, all but one of whom are lenders under our credit agreement. The Company has netting arrangements with the counterparties that provide for the offset of payables against receivables from separate derivative arrangements with the counterparties in the event of contract termination. The derivative contracts may be terminated by a non-defaulting party in the event of default by one of the parties to the agreement. There is no credit risk related contingent features or circumstances in which the features could be triggered in derivative instruments that are in a net liability position at the end of the reporting period. The Company’s commodity derivative contracts as of March 31, 2020 are summarized below: 2020 2021 2022 2023 NYMEX WTI Crude Swaps: Notional volume (Bbl) 2,800,000 4,200,000 1,020,000 900,000 Weighted average fixed price ($/Bbl) $ 59.75 $ 57.10 $ 54.84 $ 54.87 NYMEX WTI Crude Purchased Puts: Notional volume (Bbl) 5,300,000 3,600,000 — — Weighted average purchased put price ($/Bbl) $ 54.83 $ 54.17 $ — $ — NYMEX WTI Crude Purchased Calls: Notional volume (Bbl) 250,000 — — — Weighted average purchased call price ($/Bbl) $ 57.06 $ — $ — $ — NYMEX WTI Crude Sold Calls: Notional volume (Bbl) 6,250,000 3,600,000 — — Weighted average sold call price ($/Bbl) $ 61.94 $ 61.93 $ — $ — NYMEX WTI Crude Sold Puts: Notional volume (Bbl) 8,100,000 7,800,000 600,000 600,000 Weighted average sold put price ($/Bbl) $ 43.08 $ 43.27 $ 43.00 $ 43.00 NYMEX HH Natural Gas Swaps: Notional volume (MMBtu) 27,000,000 — — — Weighted average fixed price ($/MMBtu) $ 2.75 $ — $ — $ — CIG Basis Gas Swaps: Notional volume (MMBtu) 34,200,000 2,400,000 — — Weighted average fixed basis price ($/MMBtu) $ (0.61) $ (0.57) $ — $ — The following tables detail the fair value of the Company’s derivative instruments, including the gross amounts and adjustments made to net the derivative instruments for the presentation in the condensed consolidated balance sheets (in thousands): As of March 31, 2020 Location on Balance Sheet Gross Amounts of Recognized Assets and Liabilities Gross Amounts Offsets in the Balance Sheet (1) Net Amounts of Assets and Liabilities Presented in the Balance Sheet Gross Amounts not Offset in the Balance Sheet (2) Net Amounts (3) Current assets $ 293,761 $ (129,431) $ 164,330 $ (716) $ 252,397 Non-current assets 127,705 (38,922) 88,783 — — Current liabilities (130,147) 129,431 (716) 716 — Non-current liabilities (38,922) 38,922 — — — As of December 31, 2019 Location on Balance Sheet Gross Amounts of Recognized Assets and Liabilities Gross Amounts Offsets in the Balance Sheet (1) Net Amounts of Assets and Liabilities Presented in the Balance Sheet Gross Amounts not Offset in the Balance Sheet (2) Net Amounts (3) Current assets $ 48,605 $ (31,051) $ 17,554 $ — $ 30,783 Non-current assets 38,034 (24,805) 13,229 — — Current liabilities (33,049) 31,051 (1,998) — (2,106) Non-current liabilities (24,913) 24,805 (108) — — (1) Agreements are in place that allow for the financial right of offset for derivative assets and derivative liabilities at settlement or in the event of a default under the agreements. (2) Netting for balance sheet presentation is performed by current and non-current classification. This adjustment represents amounts subject to an enforceable master netting arrangement, which are not netted on the condensed consolidated balance sheets. There are no amounts of related financial collateral received or pledged. (3) Net amounts are not split by current and non-current. All counterparties in a net asset position are shown in the current asset line, and all counterparties in a net liability position are shown in the current liability line item. The table below sets forth the commodity derivatives gain (loss) for the three months ended March 31, 2020 and 2019 (in thousands). Commodity derivatives gain (loss) are included under the other income (expense) line item in the condensed consolidated statements of operations. For the Three Months Ended March 31, 2020 2019 Commodity derivatives gain (loss) $ 263,015 $ (122,091)

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Company follows accounting for asset retirement obligations in accordance with ASC 410, Asset Retirement and Environmental Obligations , which requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it was incurred if a reasonable estimate of fair value could be made. The Company’s asset retirement obligations primarily represent the estimated present value of the amounts expected to be incurred to plug, abandon and remediate producing and shut-in wells at the end of their productive lives in accordance with applicable local, state and federal laws, and applicable lease terms. The Company determines the estimated fair value of its asset retirement obligations by calculating the present value of estimated cash flows related to plugging and abandonment liabilities. The significant inputs used to calculate such liabilities include estimates of costs to be incurred, the Company’s credit adjusted discount rates, inflation rates and estimated dates of abandonment. The asset retirement liability is accreted to its present value each period and the capitalized asset retirement costs are depleted with proved oil and gas properties using the unit of production method. The following table summarizes the activities of the Company’s asset retirement obligations for the period indicated (in thousands): For the Three Months Ended March 31, 2020 Balance beginning of period $ 95,908 Liabilities incurred or acquired 192 Liabilities settled (10,787) Revisions in estimated cash flows 6,638 Accretion expense 1,822 Balance end of period $ 93,773

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements ASC 820, Fair Value Measurement and Disclosure , establishes a hierarchy for inputs used in measuring fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used when available. Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in pricing the asset or liability developed based on the best information available in the circumstances. The hierarchy is broken down into three levels based on the reliability of the inputs as follows: • Level 1: Quoted prices are available in active markets for identical assets or liabilities; • Level 2: Quoted prices in active markets for similar assets and liabilities that are observable for the asset or liability; • Level 3: Unobservable pricing inputs that are generally less observable from objective sources, such as discounted cash flow models or valuations. The financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. There were no transfers between levels during any periods presented below. The following table presents the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2020 and December 31, 2019 by level within the fair value hierarchy (in thousands): Fair Value Measurement at March 31, 2020 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 253,113 $ — $ 253,113 Financial Liabilities: Commodity derivative liabilities $ — $ 716 $ — $ 716 Fair Value Measurement at December 31, 2019 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 30,783 $ — $ 30,783 Financial Liabilities: Commodity derivative liabilities $ — $ 2,106 $ — $ 2,106 The following methods and assumptions were used to estimate the fair value of the assets and liabilities in the tables above: Commodity Derivative Instruments The Company determines its estimate of the fair value of derivative instruments using a market based approach that takes into account several factors, including quoted market prices in active markets, implied market volatility factors, quotes from third parties, the credit rating of each counterparty, and the Company's own credit rating. In consideration of counterparty credit risk, the Company assessed the possibility of whether each counterparty to the derivative would default by failing to make any contractually required payments. Additionally, the Company considers that it is of substantial credit quality and has the financial resources and willingness to meet its potential repayment obligations associated with the derivative transactions. Derivative instruments utilized by the Company consist of swaps, put options and, call options. The oil and natural gas derivative markets are highly active. Although the Company’s derivative instruments are valued using public indices, the instruments themselves are traded with third party counterparties and are not openly traded on an exchange. As such, the Company has classified these instruments as Level 2. Fair Value of Financial Instruments The Company's financial instruments consist primarily of cash and cash equivalents, accounts receivable, accounts payable, commodity derivative instruments (discussed above) and long-term debt. The carrying values of cash and cash equivalents, accounts receivable and accounts payable are representative of their fair values due to their short-term maturities. The carrying amount of the Company’s credit facility approximated fair value as it bears interest at variable rates over the term of the loan. The fair values of the 2024 Senior Notes and 2026 Senior Notes were derived from available market data. As such, the Company has classified the 2024 Senior Notes and 2026 Senior Notes as Level 2. Please refer to Note 5—Long-Term Debt for further information. The Company’s policy is to recognize transfers between levels at the end of the period. This disclosure (in thousands) does not impact the Company's financial position, results of operations or cash flows. At March 31, 2020 At December 31, 2019 Carrying Amount Fair Value Carrying Amount Fair Value Credit Facility $ 470,000 $ 470,000 $ 470,000 $ 470,000 2024 Senior Notes (1) $ 395,075 $ 68,000 $ 394,824 $ 250,000 2026 Senior Notes (2) $ 691,272 $ 119,032 $ 690,953 $ 420,113 (1) The carrying amount of the 2024 Senior Notes includes unamortized debt issuance costs of $4.9 million and $5.2 million as of March 31, 2020 and December 31, 2019, respectively. (2) The carrying amount of the 2026 Senior Notes includes unamortized debt issuance costs of $8.9 million and $9.2 million as of March 31, 2020 and December 31, 2019, respectively. Non-Recurring Fair Value Measurements The Company applies the provisions of the fair value measurement standard on a non-recurring basis to its non-financial assets and liabilities, including proved property. These assets and liabilities are not measured at fair value on a recurring basis, but are subject to fair value adjustments when facts and circumstances arise that indicate a need for remeasurement.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company computes an estimated annual effective tax rate (“AETR”) each quarter based on the current and forecasted operating results. The income tax expense or benefit associated with the interim period is computed using the most recent estimated AETR applied to the year-to-date ordinary income or loss, plus the tax effect of any significant or infrequently occurring items recorded during the interim period. The computation of the estimated AETR at each interim period requires certain estimates and significant judgements including, but not limited to, the expected operating income (loss) for the year, projections of the proportion of income earned and taxed in various jurisdictions, permanent differences and the likelihood of recovering deferred tax assets generated in the current year. The accounting estimates used to compute the provision for income taxes may change as new events occur, more experience is obtained, and additional information becomes known or as the tax environment changes. The effective combined U.S. federal and state income tax rate for the three months ended March 31, 2020 and 2019 was 19.6% and 23.6%, respectively. The effective rate for the three months ended March 31, 2020 and 2019 differs from the amount that would be provided by applying the statutory U.S. federal income tax rate of 21% to pre-tax income due to (i) the effect of a full valuation allowance in effect at March 31, 2020 and (ii) the effects of state taxes, permanent taxable differences, and income attributable to non-controlling interest for the three months ended March 31, 2019. Before accounting for a naked credit deferred tax liability, net tax expense for the three months ended March 31, 2020 was reduced to zero due to the valuation allowance. The naked credit deferred tax liability results in tax expense of $2.2 million for the three months ended March 31, 2020. The Company considers whether some portion, or all, of the deferred tax assets (“DTAs”) will be realized based on a more likely than not standard of judgment. The ultimate realization of DTAs is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. At December 31, 2019, the Company had a valuation allowance totaling $246.1 million against its DTAs resulting from prior year cumulative financial losses, oil and gas impairments, and significant net operating losses for U.S. federal and state income tax. The Company assesses the appropriateness of its valuation allowance on a quarterly basis. As of March 31, 2020, there was no change in the Company’s assessment of the realizability of its DTAs, except for a naked credit deferred tax liability.

Unit and Stock-Based Compensati

Unit and Stock-Based Compensation	3 Months Ended
	Mar. 31, 2020
Share-based Payment Arrangement [Abstract]
Unit and Stock-Based Compensation	Stock-Based Compensation Extraction Long Term Incentive Plan In October 2016, the Company’s board of directors adopted the Extraction Oil & Gas, Inc. 2016 Long Term Incentive Plan (the “2016 Plan” or “LTIP”), pursuant to which employees, consultants and directors of the Company and its affiliates performing services for the Company are eligible to receive awards. The 2016 Plan provides for the grant of stock options, stock appreciation rights, restricted stock, restricted stock units, bonus stock, dividend equivalents, other stock-based awards, substitute awards, annual incentive awards and performance awards intended to align the interests of participants with those of stockholders. In May 2019, the Company's stockholders approved the amendment and restatement of the Company's 2016 Long Term Incentive Plan. The amended and restated 2016 Long Term Incentive Plan provides a total reserve of 32.2 million shares of common stock for issuance pursuant to awards under the LTIP. Extraction has granted awards under the LTIP to certain directors, officers and employees, including stock options, restricted stock units, performance stock awards, performance stock units, performance cash awards and cash awards. Restricted Stock Units Restricted stock units granted under the LTIP (“RSUs”) generally vest over either a one or three-year service period, with 100% vesting in year one or 25%, 25% and 50% of the units vesting in year one two The Company recorded $0.8 million of stock-based compensation costs related to RSUs for the three months ended March 31, 2020 as compared to $6.9 million for the three months ended March 31, 2019. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of March 31, 2020, there was $8.3 million of total unrecognized compensation cost related to the unvested RSUs granted to certain directors, officers and employees that is expected to be recognized over a weighted average period of 2.2 years. The following table summarizes the RSU activity from January 1, 2020 through March 31, 2020 and provides information for RSUs outstanding at the dates indicated. Number of Shares Weighted Average Grant Date Non-vested RSUs at January 1, 2020 2,635,765 $ 8.32 Granted 1,252,000 $ 0.31 Forfeited (351,679) $ 9.44 Vested (356,008) $ 14.23 Non-vested RSUs at March 31, 2020 3,180,078 $ 4.38 Performance Stock Awards The Company granted performance stock awards ("PSAs") to certain executives under the LTIP in October 2017, March 2018, April 2019 and March 2020. The number of shares of the Company's common stock that may be issued to settle these various PSAs ranges from zero to two times the number of PSAs awarded. PSA's that settle in cash are presented as liability based awards. Generally, the shares issued for PSAs are determined based on the satisfaction of a time-based vesting schedule and a weighting of one or more of the following: (i) absolute total stockholder return ("ATSR"), (ii) relative total stockholder return ("RTSR"), as compared to the Company's peer group and (iii) cash return on capital invested ("CROCI") or return on invested capital ("ROIC") measured over a three-year period and vest in their entirety at the end of the three-year measurement period. Any PSAs that have not vested at the end of the applicable measurement period are forfeited. The vesting criterion that is associated with the RTSR is based on a comparison of the Company's total shareholder return for the measurement period compared to that of a group of peer companies for the same measurement period. As the ATSR and RTSR vesting criteria are linked to the Company's share price, they each are considered a market condition for purposes of calculating the grant-date fair value of the awards. The vesting criterion that is associated with the CROCI and ROIC are considered a performance condition for purposes of calculating the grant-date fair value of the awards. The fair value of the PSAs was measured at the grant date with a stochastic process method using a Monte Carlo simulation. A stochastic process is a mathematically defined equation that can create a series of outcomes over time. Those outcomes are not deterministic in nature, which means that by iterating the equations multiple times, different results will be obtained for those iterations. In the case of the Company's PSAs, the Company cannot predict with certainty the path its stock price or the stock prices of its peer will take over the performance period. By using a stochastic simulation, the Company can create multiple prospective stock pathways, statistically analyze these simulations, and ultimately make inferences regarding the most likely path the stock price will take. As such, because future stock prices are stochastic, or probabilistic with some direction in nature, the stochastic method, specifically the Monte Carlo Model, is deemed an appropriate method by which to determine the fair value of the PSAs. Significant assumptions used in this simulation include the Company's expected volatility, risk-free interest rate based on U.S. Treasury yield curve rates with maturities consistent with the measurement period as well as the volatilities for each of the Company's peers. The Company recorded a credit of $0.8 million of stock-based compensation costs related to PSAs for the three months ended March 31, 2020 as compared to $1.5 million of stock-based compensation costs related to PSAs for the three months ended March 31, 2019. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of March 31, 2020, there was $5.2 million of total unrecognized compensation cost related to the unvested PSAs granted to certain executives that is expected to be recognized over a weighted average period of 2.3 years. The following table summarizes the PSA activity from January 1, 2020 through March 31, 2020 and provides information for PSAs outstanding at the dates indicated. Number of Shares (1) Weighted Average Grant Date Non-vested PSAs at January 1, 2020 2,863,190 $ 7.72 Granted 5,952,700 $ 0.29 Forfeited — $ — Vested — $ — Non-vested PSAs at March 31, 2020 8,815,890 $ 2.70 (1) The number of awards assumes that the associated maximum vesting condition is met at the target amount. The final number of shares of the Company's common stock issued may vary depending on the performance multiplier, which ranges from zero to one for the 2017 and 2018 grants and ranges from zero to two for the 2019 and 2020 grants, depending on the level of satisfaction of the vesting condition. Stock Options Expense on the stock options is recognized on a straight-line basis over the service period of the award less awards forfeited. The fair value of the stock options was measured at the grant date using the Black-Scholes valuation model. The Company utilizes the "simplified" method to estimate the expected term of the stock options granted as there is limited historical exercise data available in estimating the expected term of the stock options. Expected volatility is based on the volatility of the historical stock prices of the Company’s peer group. The risk-free rates are based on the yields of U.S. Treasury instruments with comparable terms. A dividend yield and forfeiture rate of zero were assumed. Stock options granted under the LTIP vest ratably over three years and are exercisable immediately upon vesting through the tenth anniversary of the grant date. To fulfill options exercised, the Company will issue new shares. The Company recorded no stock-based compensation costs related to stock options for the three months ended March 31, 2020, as compared to $3.8 million for the three months ended March 31, 2019. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of March 31, 2020, there are no remaining unrecognized compensation costs related to the stock options granted to certain executives. There was no stock option activity from January 1, 2020 through March 31, 2020. However, as of March 31, 2020, there was approximately 5.2 million outstanding and exercisable stock options with a weighted-average exercise price of $18.50. Incentive Restricted Stock Units Officers of the Company contributed 2.7 million shares of common stock to Extraction Employee Incentive, LLC (“Employee Incentive”), which is owned solely by certain officers of the Company. Employee Incentive issued restricted stock units (“Incentive RSUs”) to certain employees. Incentive RSUs vested over a three year service period, with 25%, 25% and 50% of the units vesting in year one two The Company recorded no stock-based compensation costs related to Incentive RSUs for the three months ended March 31, 2020. The Company recorded $0.8 million of stock-based compensation costs related to Incentive RSUs for the three months ended March 31, 2019. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of March 31, 2020, there are no remaining unrecognized compensation costs related to the Incentive RSUs granted to certain employees.

Equity

Equity	3 Months Ended
	Mar. 31, 2020
Equity [Abstract]
Equity	Equity Series A Preferred Stock The holders of our Series A Preferred Stock (the "Series A Preferred Holders") are entitled to receive a cash dividend of 5.875% per year, payable quarterly in arrears, and we have the ability to pay such quarterly dividends in kind at a dividend rate of 10% per year (decreased proportionately to the extent such quarterly dividends are partially paid in cash). We have paid the quarterly dividends in kind since the fourth quarter of 2019, and expect to pay future quarterly dividends in kind. The Series A Preferred Stock is convertible into shares of our common stock at the election of the Series A Preferred Holders at a conversion ratio per share of Series A Preferred Stock of 61.9195. Until the three-year anniversary of the closing of the IPO, we could elect to convert the Series A Preferred Stock at a conversion ratio per share of Series A Preferred Stock of 61.9195, but only if the closing price of our common stock had traded at or above a certain premium to our initial offering price, such premium to decrease with time. On October 15, 2019, the three year anniversary had passed for the Series A Preferred Stock to convert into our common stock. We can now redeem the Series A Preferred Stock at any time for the liquidation preference, which is $194.7 million. In certain situations, including a change of control, the Series A Preferred Stock may be redeemed for cash in an amount equal to the greater of (i) 135% of the liquidation preference of the Series A Preferred Stock and (ii) a 17.5% annualized internal rate of return on the liquidation preference of the Series A Preferred Stock. The Series A Preferred Stock matures on October 15, 2021, at which time they are mandatorily redeemable for cash at the liquidation preference to the extent there are legally available funds to do so. For more information, see the Company’s Annual Report. Elevation Common Units On May 1, 2020, Elevation's board of managers issued 1,530,000,000 common units at a price of $0.01 per unit to certain of Elevation's members other than Extraction (the "Capital Raise"). The Capital Raise caused Extraction's ownership of Elevation to be diluted to less than 0.01%. As a result of the Capital Raise, beginning in May 2020 Extraction will account for Elevation under the cost method of accounting. The Company reserves all rights related to actions taken by Elevation’s board of managers. Elevation Preferred Units In July 2018 and July 2019, respectively, Elevation sold 150,000 and 100,000 of Elevation Preferred Units at a price of $990 per unit to a third party (the "Purchaser"). The aggregate liquidation preference when the units were sold was $150.0 million and $100.0 million, respectively. These Preferred Units represent the noncontrolling interest presented on the condensed consolidated balance sheets, condensed consolidated statements of operations and condensed consolidated statements of changes in stockholders' equity and noncontrolling interest. As of March 16, 2020, Elevation is a separate, deconsolidated entity and the assets and credit of Elevation are not available to satisfy the debts and other obligations of the Company or its other subsidiaries. As part of the July 2018 transaction, the Company committed to Elevation that it would drill at least 425 qualifying wells in the acreage dedicated to Elevation by December 31, 2023, subject to reductions if Extraction does not sell the full amount of additional Elevation Preferred Units to the Purchaser. Pursuant to the Fourth Amendment to the Elevation Gathering Agreements between Elevation and Extraction, this drilling commitment would be eliminated, if and only if all Elevation Preferred Units have been redeemed in full or are otherwise no longer outstanding. Please see Note 13—Commitments and Contingencies — Elevation Gathering Agreements for further details . Upon deconsolidation of Elevation Midstream, LLC as discussed in Note 1—Business and Organization , the $270.5 million Elevation preferred unit balance in the noncontrolling interest line item of the condensed consolidated balance sheets as of March 31, 2020 was removed. The amount comprises the line item effects of deconsolidation of Elevation Midstream, LLC on the condensed consolidated statements of changes in stockholders' equity and noncontrolling interest as of March 31, 2020. During the twenty-eight months following the July 3, 2018 Preferred Unit closing date, Elevation is required to pay the Purchaser a quarterly commitment fee payable in cash or in kind of 1.0% per annum on any undrawn amounts of such additional $250.0 million commitment. For the three months ended March 31, 2020 and 2019, respectively, Elevation recognized $0.6 million and $0.9 million of commitment fees paid-in-kind included under the Preferred Unit commitment fees and dividends paid-in-kind line item in the condensed consolidated statements of changes in stockholders' equity and noncontrolling interest.

Earnings (Loss) Per Share

Earnings (Loss) Per Share	3 Months Ended
	Mar. 31, 2020
Earnings Per Share [Abstract]
Earnings (Loss) per Share	Earnings (Loss) Per Share Basic earnings per share (“EPS”) includes no dilution and is computed by dividing net income (loss) available to common shareholders by the weighted average number of shares outstanding during the period. Diluted EPS reflects the potential dilution of securities that could share in the earnings of the Company. The Company uses the “if-converted” method to determine potential dilutive effects of the Company’s outstanding Series A Preferred Stock and the treasury method to determine the potential dilutive effects of outstanding restricted stock awards and stock options. The basic weighted average shares outstanding calculation is based on the actual days in which the shares were outstanding for the three months ended March 31, 2020 and 2019. The components of basic and diluted EPS were as follows (in thousands, except per share data): For the Three Months Ended March 31, 2020 2019 Basic and Diluted Income (Loss) Per Share Net income (loss) $ 9,037 $ (94,032) Less: Noncontrolling interest (6,160) (3,975) Less: Adjustment to reflect Series A Preferred Stock dividends (4,748) (2,721) Less: Adjustment to reflect accretion of Series A Preferred Stock discount (1,770) (1,596) Adjusted net loss available to common shareholders, basic and diluted $ (3,641) $ (102,324) Denominator: Weighted average common shares outstanding, basic and diluted (1) (2) 137,726 170,702 Loss Per Common Share Basic and diluted $ (0.03) $ (0.60) (1) For the three months ended March 31, 2020, 8,339,698 potentially dilutive shares, including restricted stock awards and stock options outstanding, were not included in the calculation above, as they had an anti-dilutive effect on EPS. Additionally, 11,472,445 common shares associated with the assumed conversion of Series A Preferred Stock were also excluded, as they would have had an anti-dilutive effect on EPS.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies General As is customary in the oil and gas industry, the Company may at times have commitments in place to reserve or earn certain acreage positions or wells. If the Company does not meet such commitments, the acreage positions or wells may be lost, or the Company may be required to pay damages if certain performance conditions are not met. Leases The Company has entered into operating leases for certain office facilities, compressors and office equipment. Maturities of operating lease liabilities associated with right-of-use assets and including imputed interest were as follows (in thousands): As of March 31, As of December 31, 2020 - remaining 13,653 2020 19,040 2021 5,247 2021 5,247 2022 2,211 2022 2,211 2023 2,246 2023 2,246 2024 2,301 2024 2,301 Thereafter 8,273 Thereafter 8,273 Total lease payments 33,931 Total lease payments 39,318 Less imputed interest (1) (4,264) Less imputed interest (1) (4,735) Present value of lease liabilities (2) $ 29,667 Present value of lease liabilities (2) $ 34,583 (1) Calculated using the estimated interest rate for each lease. (2) Of the total present value of lease liabilities as of March 31, 2020 and December 31, 2019, $15.2 million and $17.4 thousand, respectively, were recorded in accounts payable and accrued liabilities and $14.5 million and $17.2 thousand, respectively, were recorded in other non-current liabilities on the condensed consolidated balance sheets. Drilling Rigs As of March 31, 2020, the Company was subject to commitments on two drilling rigs contracted through May 2020 and February 2021. These costs are capitalized within proved oil and gas properties on the condensed consolidated balance sheets and are included as short-term lease costs. In the event of early termination of these contracts, the Company would be obligated to pay an aggregate amount of approximately $9.0 million as of March 31, 2020, as required under the terms of the contracts. Subsequent to March 31, 2020, the Company renegotiated the terms of the drilling rig contracts. After the modifications, in the event of early termination, the Company would be obligated to pay an aggregate amount of approximately $8.0 million as of May 6, 2020. Delivery Commitments As of March 31, 2020, the Company’s oil marketer is subject to a firm transportation agreement that commenced in November 2016 and has a ten-year term with a monthly minimum delivery commitment of 45,000 Bbl/d in year one, 55,800 Bbl/d in year two, 61,800 Bbl/d in years three through seven and 58,000 Bbl/d in years eight through ten. In May 2017, the Company amended its agreement with its oil marketer that requires it to sell all of its crude oil from an area of mutual interest in exchange for a make-whole provision that allows the Company to satisfy any minimum volume commitment deficiencies incurred by its oil marketer with future barrels of crude oil in excess of their minimum volume commitment during the contract term. In May 2019, the Company extended the term of this agreement through October 31, 2020 subject to an evergreen provision thereafter where either party can provide a six month notice of termination beginning November 1, 2020. Due to the contract termination date, the amount of consideration recognized in revenue is reduced. Please see Note 2—Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements — Revenue — Contract Balances . The Company has posted a letter of credit for this agreement in the amount of $40.0 million. The Company may be required to pay a shortfall fee for any volume deficiencies under these commitments. The aggregate remaining amount of estimated payments under these agreements is approximately $655.8 million. The Company has two long-term crude oil gathering commitments with a unconsolidated subsidiary, in which the Company had a minority ownership interest. Please see Note 1—Business and Organization for information related to the deconsolidation of Elevation Midstream, LLC. The first agreement commenced in November 2016 and has a term of ten years with a minimum volume commitment of an average of 9,167 Bbl/d in year one, 17,967 Bbl/d in year two, 18,800 Bbl/d for years three through five and 10,000 Bbl/d for years six through ten. The Company may be required to pay a shortfall fee for any volume deficiencies under this commitment. The second agreement commenced in July 2019 and has a term of ten years for an average of 3,200 Bbl/d in year one, 8,000 Bbl/d in year two, 14,000 Bbl/d in year three, 16,000 Bbl/d in years four through eight, 12,000 Bbl/d in year nine and 10,000 Bbl/d in year ten. The Company may be required to pay a shortfall fee for any volume deficiencies under this commitment. The aggregate remaining amount of estimated payments under these agreements is approximately $117.7 million. In February 2019, the Company entered into two long-term gas gathering and processing agreements with third-party midstream providers. One of the agreements additionally includes a long-term NGL sales commitment for take-in-kind NGLs from other processing agreements. The first agreement commenced in November 2019 and has a term of twenty years with a minimum volume commitment of 251 Bcf to be delivered within the first seven years. The annual commitments over seven years are to be delivered on an average 85,000 Mcf/d in year one, 125,000 Mcf/d in year two, 140,000 Mcf/d in year three, 118,000 Mcf/d in year four, 98,000 Mcf/d in year five, 70,000 Mcf/d in year six and 52,000 Mcf/d in year seven. The aggregate remaining amount of estimated payments under this agreement is approximately $299.3 million. The second agreement commenced on January 2020 and has a term of ten years with an annual minimum volume commitment of 13.0 Bcf in years one through ten. The second agreement also includes a commitment to sell take-in-kind NGLs of 4,000 Bbl/d in year one and 7,500 Bbl/d in years two through seven with the ability to roll up to a 10% shortfall in a given month to the subsequent month. The Company may be required to pay a shortfall fee for any volume deficiencies under these commitments, calculated based on the applicable gathering and processing fees and/or, with respect to the NGL commitment, the NGL transport cost. Under its current drilling plans, the Company expects to meet these volume commitments. The summary of these minimum volume commitments as of March 31, 2020, was as follows: Oil (MBbl) Gas (MMcf) Total (MBOE) 2020 - remaining 6,492 25,815 10,794 2021 9,797 46,540 17,554 2022 8,944 49,758 17,237 2023 9,490 41,850 16,465 2024 9,516 34,160 15,209 Thereafter 29,860 40,260 36,570 Total 74,099 238,383 113,829 In collaboration with several other producers and a midstream provider, on December 15, 2016 and August 7, 2017, the Company agreed to participate in expansions of natural gas gathering and processing capacity in the DJ Basin. The plan includes two new processing plants as well as the expansion of related gathering systems. The first plant commenced operations in August 2018 and the second plant commenced operations in July 2019. The Company’s share of these commitments will require an incremental 51.5 and 20.6 MMcf per day, respectively, over a baseline volume of 65 MMcf per day to be delivered after the plants' in-service dates for a period of seven years thereafter. The Company may be required to pay a shortfall fee for any incremental volume deficiency under these commitments. These contractual obligations can be reduced by the Company’s proportionate share of the collective volumes delivered to the plants by other third-party incremental volumes available to the midstream provider at the new facilities that are in excess of the total commitments. The Company is also required for the first three years of each contract to guarantee a certain target profit margin on these volumes sold. In July 2019, the Company entered into three long-term contracts to supply 125,000 dekatherms of residue gas per day for five years to a transportation company. While our production is expected to satisfy these contracts, the aggregate remaining amount of estimated commitment assuming no production is $31.0 million. The Company has posted a letter of credit for this agreement in the amount of $8.7 million. The aggregate remaining amount of estimated remaining payments under these agreements is $1,103.8 million. Elevation Gathering Agreements In November 2018, the Company entered into three long-term gathering agreements (the "Elevation Gathering Agreements") for gas, crude oil and produced water with Elevation. Under the agreements, the Company agreed to drill 100 wells in Broomfield and 325 wells in Hawkeye by December 31, 2023 if both facilities are to be built. Elevation has alleged that if the Company fails to complete the wells by the commitment deadline, then it would be in breach of the agreement and Elevation could attempt to assert damages against Extraction and its affiliates. During the first quarter of 2020, Elevation postponed indefinitely further development of gathering systems and facilities that were to be constructed to service the Company's acreage in Hawkeye and another project in the Southwest Wattenberg area. Due to the decision to not complete the Hawkeye facilities and based on the amount of capital invested, the drilling commitment now consists of 297 wells in the Broomfield area of operations. In April 2019, the Elevation Gathering Agreements were amended to provide for, among other amendments, the inclusion of additional gathering facilities in Elevation’s Badger facility. Pursuant to this amendment, Elevation has asserted that the additional gathering facilities were required to be completed by April 1, 2020 or, within 30 days of such date, Elevation could assert that Extraction must make a payment to Elevation in the amount of 135% of all costs incurred by Elevation as of such date for the development and construction of such additional gathering facilities. As of March 31, 2020, the costs incurred by Elevation for these additional gathering facilities totaled $34.7 million. The Company did not complete these additional gathering facilities by April 1, 2020, and Elevation has alleged that Extraction is in breach of the Elevation Gathering Agreements. On April 2, 2020, Elevation demanded payment of $46.8 million due to an alleged breach in contract stemming from a purported failure to complete the pipeline extensions connecting certain wells to the Badger central gathering facility prior to April 1, 2020. While the Company disputes that these amounts are due to Elevation, under ASC Topic 450 - Contingencies , the Company recorded the amount in accounts payable and accrued liabilities, related party on the condensed consolidated balance sheet as of March 31, 2020 and in other operating expenses on the condensed consolidated statements of operations. In December 2019, the Elevation Gathering Agreements were further amended to provide Elevation additional connection fees that are consistent with market terms (the "Connect Fees"). In the fourth quarter of 2019, the Company incurred $19.5 million for Connect Fees pursuant to the Elevation Gathering Agreements, and in the first quarter of 2020 the Company incurred and paid $23.5 million. The Company does not expect to incur additional Connect Fees for the year ending December 31, 2020. In March 2020, the Elevation Gathering Agreements were further amended to reset all gathering rates and eliminate existing minimum drilling commitment. This amendment will not become effective until after all Elevation Preferred Units have been redeemed in full or are otherwise no longer outstanding. Litigation and Legal Items The Company is involved in various legal proceedings and reviews the status of these proceedings on an ongoing basis and, from time to time, may settle or otherwise resolve these matters on terms and conditions that management believes are in the Company’s best interests. The Company has provided the necessary estimated accruals in the condensed consolidated balance sheets where deemed appropriate for litigation and legal related items that are ongoing and not yet concluded. Although the results cannot be known with certainty, the Company currently believes that the ultimate results of such proceedings will not have a material adverse effect on our business, financial position, results of operations or liquidity. Environmental. Due to the nature of the natural gas and oil industry, the Company is exposed to environmental risks. The Company has various policies and procedures to minimize and mitigate the risks from environmental contamination or with respect to environmental compliance issues. Liabilities are recorded when environmental damages resulting from past events are probable and the costs can be reasonably estimated. Except as discussed herein, the Company is not aware of any material environmental claims existing as of March 31, 2020 which have not been provided for or would otherwise have a material impact on our financial statements; however, there can be no assurance that current regulatory requirements will not change or that unknown potential past non-compliance with environmental laws, compliance matters or other environmental liabilities will not be discovered on our properties. Accrued environmental liabilities are recorded in accounts payable and accrued liabilities on the condensed consolidated balance sheets. The liability ultimately incurred with respect to a matter may exceed the related accrual. COGCC Notices of Alleged Violations (“NOAVs”). The Company has received NOAVs from the COGCC for alleged compliance violations that the Company has responded to. At this time, the COGCC has not alleged any specific penalty amounts in these matters. The Company does not believe that any penalties that could result from these NOAVs will have a material effect on our business, financial condition, results of operations or liquidity, but they may exceed $100,000. Midstream Connections. The Company had dedicated the production from some acreage to a certain midstream service provider. However, the Company was unable to connect well pads to the provider due to the inability to secure right of way access for building the connection pipeline. Because the acreage’s production was dedicated to the midstream provider, they have invoiced the Company for oil and gas handled by other midstream providers. The Company disputes these invoices based on force majeure and may have other contractual or legal defenses. The Company’s maximum exposure as of March 31, 2020 was $15.7 million. As of March 31, 2020, no contingent liability has been recorded as the amount of the loss cannot be reasonably estimated. Elevation Matador Facility. Under the Elevation LLC Agreement, the Company is required to complete the gathering facilities in Elevation’s Matador facility servicing the Company’s Hawkeye area by August 1, 2020. As part of the Company’s abandonment of further developing this Matador gathering system and facilities that were being constructed, Elevation has alleged that Extraction will be required to reimburse Elevation for all such expenditures on this project. Elevation is currently disputing certain costs related to this project with a third-party contractor that was working on the project. The Company’s maximum exposure as of March 31, 2020 was $20.7 million. As of March 31, 2020, no contingent liability has been recorded as the amount of the loss cannot be reasonably estimated. Elevation Gathering. As discussed above under Elevation Gathering Agreements , on April 2, 2020, Elevation demanded payment of $46.8 million due to an alleged breach in contract stemming from a purported failure to complete the pipeline extensions connecting certain wells to the Badger central gathering facility prior to April 1, 2020. While the Company disputes that these amounts are due to Elevation, under ASC Topic 450 - Contingencies

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2020
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions 2024 Senior Notes Several 5% stockholders of the Company were also holders of the 2024 Senior Notes. As of the initial issuance in August 2017 of the $400.0 million principal amount on the 2024 Senior Notes, such stockholders held $54.9 million. 2026 Senior Notes Several holders of the 2026 Senior Notes are also 5% stockholders of the Company. As of the initial issuance in January 2018 of the $750.0 million principal amount on the 2026 Senior Notes, such stockholders held $56.2 million. Elevation Midstream, LLC As discussed in Note 13—Commitments and Contingencies , on April 2, 2020, Elevation demanded payment of $46.8 million due to an alleged breach in contract stemming from a purported failure to complete the pipeline extensions connecting certain wells to the Badger central gathering facility prior to April 1, 2020. While the Company disputes that these amounts are due to Elevation, under ASC Topic 450 - Contingencies

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2020
Segment Reporting [Abstract]
Segment Reporting Disclosure [Text Block]	Segment Information Beginning in the fourth quarter of 2018, the Company had two operating segments, (i) the exploration, development and production of oil, natural gas and NGL (the "exploration and production segment") and (ii) the construction of and support of midstream assets to gather and process crude oil and gas production (the "gathering and facilities segment"). Elevation Midstream, LLC comprised the gathering and facilities segment. During the three months ending March 31, 2019, the Company’s gathering and facilities segment was in the construction phase and no revenue generating activities had commenced. Through March 16, 2020, the results of Elevation were included in the consolidated financial statements of Extraction. Effective March 17, 2020, the results of Elevation Midstream, LLC are no longer consolidated in Extraction's results; however, the Company’s segment disclosures include the gathering and facilities segment because it was consolidated through March 16, 2020. Please see Note 1—Business and Organization for further information related to the deconsolidation of Elevation Midstream, LLC. After March 31, 2020, Extraction will report as a single operating segment. The following table presents a reconciliation of Adjusted EBITDAX by segment to the GAAP financial measure of income (loss) before income taxes for the three months ended March 31, 2020 and 2019 (in thousands). For the Three Months Ended March 31, 2020 2019 Reconciliation of Adjusted EBITDAX to Income (Loss) Before Income Taxes Exploration and production segment EBITDAX $ 122,639 $ 138,339 Gathering and facilities segment EBITDAX 1,256 (152) Subtotal of Reportable Segments $ 123,895 $ 138,187 Less: Depletion, depreciation, amortization and accretion $ (76,051) $ (118,770) Impairment of long lived assets (775) (8,248) Other operating expenses (52,575) — Exploration and abandonment expenses (112,480) (6,194) Gain on sale of property and equipment — 222 Gain (loss) on commodity derivatives 263,015 (122,091) Settlements on commodity derivative instruments (39,295) 10,329 Premiums paid for derivatives that settled during the period — 9,549 Stock-based compensation expense — (13,008) Amortization of debt issuance costs (1,242) (1,497) Gain on repurchase of 2026 Senior Notes — 7,317 Interest expense (20,116) (18,828) Loss on deconsolidation of Elevation Midstream, LLC (73,139) — Income (Loss) Before Income Taxes $ 11,237 $ (123,032) Financial information of the Company's reportable segments was as follows for the three months ended March 31, 2020 and 2019 (in thousands). For the Three Months Ended March 31, 2020 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from third parties $ 163,714 $ 1,473 $ — $ 165,187 Revenues from Extraction — 4,513 (4,513) — Total Revenues $ 163,714 $ 5,986 $ (4,513) $ 165,187 Operating Expenses and Other Income (Expense): Direct operating expenses $ (70,924) $ (3,935) $ 4,294 $ (70,565) Depletion, depreciation, amortization and accretion (74,952) (1,099) — (76,051) Interest income 61 29 — 90 Interest expense (21,358) — — (21,358) Earnings in unconsolidated subsidiaries — 480 — 480 Subtotal Operating Expenses and Other Income (Expense): $ (167,173) $ (4,525) $ 4,294 $ (167,404) Segment Assets $ 2,703,388 $ — $ — $ 2,703,388 Capital Expenditures 155,441 (6,311) — 149,130 Investment in Equity Method Investees — — — — Segment EBITDAX 122,639 1,256 — 123,895 For the Three Months Ended March 31, 2019 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from third parties $ 221,917 $ — $ — $ 221,917 Revenues from Extraction — — — — Total Revenues $ 221,917 $ — $ — $ 221,917 Operating Expenses and Other Income (Expense): Direct operating expenses $ — $ — $ — $ — Depletion, depreciation, amortization and accretion (118,751) (19) — (118,770) Interest income 154 625 — 779 Interest expense (13,008) — — (13,008) Earnings in unconsolidated subsidiaries — 338 — 338 Subtotal Operating Expenses and Other Income (Expense): $ (131,605) $ 944 $ — $ (130,661) Segment Assets $ 3,813,513 $ 284,200 $ (714) $ 4,096,999 Capital Expenditures 158,622 58,863 — 217,485 Investment in Equity Method Investees — 17,555 — 17,555 Segment EBITDAX 138,339 (152) — 138,187

Basis of Presentation, Signif_2

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements (Policies)	3 Months Ended
	Mar. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation The unaudited condensed consolidated financial statements include the accounts of the Company, including its wholly owned subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation. The financial statements included herein were prepared from the records of the Company in accordance with generally accepted accounting principles in the United States (“GAAP”) and the Securities and Exchange Commission rules and regulation for interim financial reporting. In the opinion of management, all adjustments, consisting primarily of normal recurring accruals that are considered necessary for a fair statement of the unaudited condensed consolidated financial information, have been included. However, operating results for the period presented are not necessarily indicative of the results that may be expected for a full year. Interim condensed consolidated financial
Recent Accounting Pronouncements	Recent Accounting Pronouncements In June 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-13, Financial Instruments—Credit Losses. In May 2019, ASU No. 2016-13 was subsequently amended by ASU No. 2019-04, Codification Improvements to Topic 326, Financial Instruments—Credit Losses and ASU No. 2019-05, Financial Instruments—Credit Losses (Topic 326): Targeted Transition Relief. ASU No. 2016-13, as amended, affects trade receivables, financial assets and certain other instruments that are not measured at fair value through net income. This ASU replaced the incurred loss approach with an expected loss model for instruments measured at amortized cost and was effective for financial statements issued for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. ASU No. 2016-13 will be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Company adopted this ASU on January 1, 2020, and the adoption did not have a material impact on the consolidated financial statements and related disclosures. In August 2018, the FASB issued ASU No. 2018-13, which removes or modifies current fair value disclosures and adds additional disclosures. The update to the guidance is the result of the FASB's test of the principles developed in its disclosure effectiveness project, which is designed to improve the effectiveness of disclosures in the notes to the financial statements. The disclosures that have been removed or modified may be applied immediately with retrospective application. For public entities, the new guidance was effective for fiscal years beginning after December 15, 2019, including interim reporting periods within that reporting period. The Company adopted this ASU on January 1, 2020, and the adoption did not have a material impact on the consolidated financial statements and related disclosures. In August 2018, the FASB issued ASU No. 2018-15, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software and hosting arrangements that include an internal-use software license. For public entities, the guidance is effective for fiscal years beginning after December 15, 2019, including interim reporting periods within that reporting period. The Company adopted this ASU on January 1, 2020 which did not have a material impact on the consolidated financial statements and related disclosures as capitalized costs for internal-use software were not material as of March 31, 2020. Other than as disclosed above or in the Company’s Annual Report, there are no other accounting standards applicable to the Company as of March 31, 2020 and through the date of this filing that would have a material effect on the Company’s unaudited condensed consolidated financial statements and related disclosures that have been issued but not yet adopted by the Company.

Long Term Debt (Tables)

Long Term Debt (Tables)	3 Months Ended
	Mar. 31, 2020
Debt Instrument [Line Items]
Schedule of long-term debt	he Company’s long-term debt consisted of the following (in thousands): March 31, December 31, Credit facility due August 16, 2022 (or an earlier time as set forth in the credit facility) $ 470,000 $ 470,000 2024 Senior Notes due May 15, 2024 400,000 400,000 2026 Senior Notes due February 1, 2026 700,189 700,189 Unamortized debt issuance costs on Senior Notes (13,842) (14,412) Total long-term debt 1,556,347 1,555,777 Less: current portion of long-term debt — — Total long-term debt, net of current portion $ 1,556,347 $ 1,555,777
Schedule of Borrowing Base Utilization Grid	Borrowing Base Utilization Grid Eurodollar Base Rate Commitment Borrowing Base Utilization Percentage Utilization Margin Margin Fee Rate Level 1 <25% 1.50 % 0.50 % 0.38 % Level 2 ≥ 25% < 50% 1.75 % 0.75 % 0.38 % Level 3 ≥ 50% < 75% 2.00 % 1.00 % 0.50 % Level 4 ≥ 75% < 90% 2.25 % 1.25 % 0.50 % Level 5 ≥90% 2.50 % 1.50 % 0.50 %

Commodity Derivative Instrume_2

Commodity Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of commodity derivative contracts	The Company’s commodity derivative contracts as of March 31, 2020 are summarized below: 2020 2021 2022 2023 NYMEX WTI Crude Swaps: Notional volume (Bbl) 2,800,000 4,200,000 1,020,000 900,000 Weighted average fixed price ($/Bbl) $ 59.75 $ 57.10 $ 54.84 $ 54.87 NYMEX WTI Crude Purchased Puts: Notional volume (Bbl) 5,300,000 3,600,000 — — Weighted average purchased put price ($/Bbl) $ 54.83 $ 54.17 $ — $ — NYMEX WTI Crude Purchased Calls: Notional volume (Bbl) 250,000 — — — Weighted average purchased call price ($/Bbl) $ 57.06 $ — $ — $ — NYMEX WTI Crude Sold Calls: Notional volume (Bbl) 6,250,000 3,600,000 — — Weighted average sold call price ($/Bbl) $ 61.94 $ 61.93 $ — $ — NYMEX WTI Crude Sold Puts: Notional volume (Bbl) 8,100,000 7,800,000 600,000 600,000 Weighted average sold put price ($/Bbl) $ 43.08 $ 43.27 $ 43.00 $ 43.00 NYMEX HH Natural Gas Swaps: Notional volume (MMBtu) 27,000,000 — — — Weighted average fixed price ($/MMBtu) $ 2.75 $ — $ — $ — CIG Basis Gas Swaps: Notional volume (MMBtu) 34,200,000 2,400,000 — — Weighted average fixed basis price ($/MMBtu) $ (0.61) $ (0.57) $ — $ —
Schedule of fair value of derivative instruments in statement of financial position	The following tables detail the fair value of the Company’s derivative instruments, including the gross amounts and adjustments made to net the derivative instruments for the presentation in the condensed consolidated balance sheets (in thousands): As of March 31, 2020 Location on Balance Sheet Gross Amounts of Recognized Assets and Liabilities Gross Amounts Offsets in the Balance Sheet (1) Net Amounts of Assets and Liabilities Presented in the Balance Sheet Gross Amounts not Offset in the Balance Sheet (2) Net Amounts (3) Current assets $ 293,761 $ (129,431) $ 164,330 $ (716) $ 252,397 Non-current assets 127,705 (38,922) 88,783 — — Current liabilities (130,147) 129,431 (716) 716 — Non-current liabilities (38,922) 38,922 — — — As of December 31, 2019 Location on Balance Sheet Gross Amounts of Recognized Assets and Liabilities Gross Amounts Offsets in the Balance Sheet (1) Net Amounts of Assets and Liabilities Presented in the Balance Sheet Gross Amounts not Offset in the Balance Sheet (2) Net Amounts (3) Current assets $ 48,605 $ (31,051) $ 17,554 $ — $ 30,783 Non-current assets 38,034 (24,805) 13,229 — — Current liabilities (33,049) 31,051 (1,998) — (2,106) Non-current liabilities (24,913) 24,805 (108) — — (1) Agreements are in place that allow for the financial right of offset for derivative assets and derivative liabilities at settlement or in the event of a default under the agreements. (2) Netting for balance sheet presentation is performed by current and non-current classification. This adjustment represents amounts subject to an enforceable master netting arrangement, which are not netted on the condensed consolidated balance sheets. There are no amounts of related financial collateral received or pledged. (3) Net amounts are not split by current and non-current. All counterparties in a net asset position are shown in the current asset line, and all counterparties in a net liability position are shown in the current liability line item.
Schedule of commodity derivatives gain (loss) included in other income (expense)	The table below sets forth the commodity derivatives gain (loss) for the three months ended March 31, 2020 and 2019 (in thousands). Commodity derivatives gain (loss) are included under the other income (expense) line item in the condensed consolidated statements of operations. For the Three Months Ended March 31, 2020 2019 Commodity derivatives gain (loss) $ 263,015 $ (122,091)

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Schedule summarizing activities of asset retirement obligaions	The following table summarizes the activities of the Company’s asset retirement obligations for the period indicated (in thousands): For the Three Months Ended March 31, 2020 Balance beginning of period $ 95,908 Liabilities incurred or acquired 192 Liabilities settled (10,787) Revisions in estimated cash flows 6,638 Accretion expense 1,822 Balance end of period $ 93,773

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Schedule of financial assets and liabilities accounted for at fair value on a recurring basis	The following table presents the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2020 and December 31, 2019 by level within the fair value hierarchy (in thousands): Fair Value Measurement at March 31, 2020 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 253,113 $ — $ 253,113 Financial Liabilities: Commodity derivative liabilities $ — $ 716 $ — $ 716 Fair Value Measurement at December 31, 2019 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 30,783 $ — $ 30,783 Financial Liabilities: Commodity derivative liabilities $ — $ 2,106 $ — $ 2,106
Schedule of fair value of financial instruments	At March 31, 2020 At December 31, 2019 Carrying Amount Fair Value Carrying Amount Fair Value Credit Facility $ 470,000 $ 470,000 $ 470,000 $ 470,000 2024 Senior Notes (1) $ 395,075 $ 68,000 $ 394,824 $ 250,000 2026 Senior Notes (2) $ 691,272 $ 119,032 $ 690,953 $ 420,113

Unit and Stock-Based Compensa_2

Unit and Stock-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2020
Unit and Stock-Based Compensation
Schedule summarizing stock option activity	The following table summarizes the RSU activity from January 1, 2020 through March 31, 2020 and provides information for RSUs outstanding at the dates indicated. Number of Shares Weighted Average Grant Date Non-vested RSUs at January 1, 2020 2,635,765 $ 8.32 Granted 1,252,000 $ 0.31 Forfeited (351,679) $ 9.44 Vested (356,008) $ 14.23 Non-vested RSUs at March 31, 2020 3,180,078 $ 4.38
Schedule of non-vested restricted award activity	The following table summarizes the PSA activity from January 1, 2020 through March 31, 2020 and provides information for PSAs outstanding at the dates indicated. Number of Shares (1) Weighted Average Grant Date Non-vested PSAs at January 1, 2020 2,863,190 $ 7.72 Granted 5,952,700 $ 0.29 Forfeited — $ — Vested — $ — Non-vested PSAs at March 31, 2020 8,815,890 $ 2.70 (1) The number of awards assumes that the associated maximum vesting condition is met at the target amount. The final number of shares of the Company's common stock issued may vary depending on the performance multiplier, which ranges from zero to one for the 2017 and 2018 grants and ranges from zero to two for the 2019 and 2020 grants, depending on the level of satisfaction of the vesting condition.

Earnings (Loss) Per Share (Tabl

Earnings (Loss) Per Share (Tables)	3 Months Ended
	Mar. 31, 2020
Earnings Per Share [Abstract]
Earnings (Loss) Per Share	The components of basic and diluted EPS were as follows (in thousands, except per share data): For the Three Months Ended March 31, 2020 2019 Basic and Diluted Income (Loss) Per Share Net income (loss) $ 9,037 $ (94,032) Less: Noncontrolling interest (6,160) (3,975) Less: Adjustment to reflect Series A Preferred Stock dividends (4,748) (2,721) Less: Adjustment to reflect accretion of Series A Preferred Stock discount (1,770) (1,596) Adjusted net loss available to common shareholders, basic and diluted $ (3,641) $ (102,324) Denominator: Weighted average common shares outstanding, basic and diluted (1) (2) 137,726 170,702 Loss Per Common Share Basic and diluted $ (0.03) $ (0.60) (1) For the three months ended March 31, 2020, 8,339,698 potentially dilutive shares, including restricted stock awards and stock options outstanding, were not included in the calculation above, as they had an anti-dilutive effect on EPS. Additionally, 11,472,445 common shares associated with the assumed conversion of Series A Preferred Stock were also excluded, as they would have had an anti-dilutive effect on EPS.

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The Company has entered into operating leases for certain office facilities, compressors and office equipment. Maturities of operating lease liabilities associated with right-of-use assets and including imputed interest were as follows (in thousands): As of March 31, As of December 31, 2020 - remaining 13,653 2020 19,040 2021 5,247 2021 5,247 2022 2,211 2022 2,211 2023 2,246 2023 2,246 2024 2,301 2024 2,301 Thereafter 8,273 Thereafter 8,273 Total lease payments 33,931 Total lease payments 39,318 Less imputed interest (1) (4,264) Less imputed interest (1) (4,735) Present value of lease liabilities (2) $ 29,667 Present value of lease liabilities (2) $ 34,583 (1) Calculated using the estimated interest rate for each lease. (2) Of the total present value of lease liabilities as of March 31, 2020 and December 31, 2019, $15.2 million and $17.4 thousand, respectively, were recorded in accounts payable and accrued liabilities and $14.5 million and $17.2 thousand, respectively, were recorded in other non-current liabilities on the condensed consolidated balance sheets.

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2020
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	The following table presents a reconciliation of Adjusted EBITDAX by segment to the GAAP financial measure of income (loss) before income taxes for the three months ended March 31, 2020 and 2019 (in thousands). For the Three Months Ended March 31, 2020 2019 Reconciliation of Adjusted EBITDAX to Income (Loss) Before Income Taxes Exploration and production segment EBITDAX $ 122,639 $ 138,339 Gathering and facilities segment EBITDAX 1,256 (152) Subtotal of Reportable Segments $ 123,895 $ 138,187 Less: Depletion, depreciation, amortization and accretion $ (76,051) $ (118,770) Impairment of long lived assets (775) (8,248) Other operating expenses (52,575) — Exploration and abandonment expenses (112,480) (6,194) Gain on sale of property and equipment — 222 Gain (loss) on commodity derivatives 263,015 (122,091) Settlements on commodity derivative instruments (39,295) 10,329 Premiums paid for derivatives that settled during the period — 9,549 Stock-based compensation expense — (13,008) Amortization of debt issuance costs (1,242) (1,497) Gain on repurchase of 2026 Senior Notes — 7,317 Interest expense (20,116) (18,828) Loss on deconsolidation of Elevation Midstream, LLC (73,139) — Income (Loss) Before Income Taxes $ 11,237 $ (123,032) Financial information of the Company's reportable segments was as follows for the three months ended March 31, 2020 and 2019 (in thousands). For the Three Months Ended March 31, 2020 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from third parties $ 163,714 $ 1,473 $ — $ 165,187 Revenues from Extraction — 4,513 (4,513) — Total Revenues $ 163,714 $ 5,986 $ (4,513) $ 165,187 Operating Expenses and Other Income (Expense): Direct operating expenses $ (70,924) $ (3,935) $ 4,294 $ (70,565) Depletion, depreciation, amortization and accretion (74,952) (1,099) — (76,051) Interest income 61 29 — 90 Interest expense (21,358) — — (21,358) Earnings in unconsolidated subsidiaries — 480 — 480 Subtotal Operating Expenses and Other Income (Expense): $ (167,173) $ (4,525) $ 4,294 $ (167,404) Segment Assets $ 2,703,388 $ — $ — $ 2,703,388 Capital Expenditures 155,441 (6,311) — 149,130 Investment in Equity Method Investees — — — — Segment EBITDAX 122,639 1,256 — 123,895 For the Three Months Ended March 31, 2019 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from third parties $ 221,917 $ — $ — $ 221,917 Revenues from Extraction — — — — Total Revenues $ 221,917 $ — $ — $ 221,917 Operating Expenses and Other Income (Expense): Direct operating expenses $ — $ — $ — $ — Depletion, depreciation, amortization and accretion (118,751) (19) — (118,770) Interest income 154 625 — 779 Interest expense (13,008) — — (13,008) Earnings in unconsolidated subsidiaries — 338 — 338 Subtotal Operating Expenses and Other Income (Expense): $ (131,605) $ 944 $ — $ (130,661) Segment Assets $ 3,813,513 $ 284,200 $ (714) $ 4,096,999 Capital Expenditures 158,622 58,863 — 217,485 Investment in Equity Method Investees — 17,555 — 17,555 Segment EBITDAX 138,339 (152) — 138,187

Business and Organization Busin

Business and Organization Business and Organization (Details) - USD ($) $ / shares in Units, $ in Thousands	May 01, 2020	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Subsequent Event [Line Items]
Loss on deconsolidation of Elevation Midstream, LLC		$ (73,139)	$ 0
Common Stock, shares issued (in shares)		137,891,740		137,891,740
Subsequent Event [Member]
Subsequent Event [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	1,530,000,000
Sale of Stock, Price Per Share	$ 0.01

Organization, Consolidation and

Organization, Consolidation and Presentation of Financial Statements (Details) - USD ($) $ in Thousands	Apr. 02, 2020	Mar. 31, 2020	Mar. 31, 2019
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue, Performance Obligation, Amount Satisfied		$ 8,500
Revenue, Remaining Performance Obligation, Amount		46,200
Contract with Customer, Liability, Current		3,900
Contract with Customer, Liability, Noncurrent		42,300
Contract with Customer, Asset, Gross, Noncurrent		13,000
Contract with Customer, Asset, Net, Current		12,100
Contract with Customer, Asset, Net, Noncurrent		900
Results of Operations, Expense, Other		52,600
Other Operating Expense, Restructuring Activities		5,800
Exploration and abandonment expenses		112,480	$ 6,194
Abandonment and impairment of unproved properties		$ 106,928	$ 3,893
Elevation | Subsequent Event [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Administrative penalty	$ 46,800

Acquisitions - Acquisitions and

Acquisitions - Acquisitions and Divestitures (Details) $ in Millions	Aug. 22, 2019USD ($)	Feb. 29, 2020USD ($)	Dec. 31, 2019USD ($)	Mar. 31, 2019USD ($)a
Acquisitions
Proceeds from divestitures	$ 22	$ 12.2	$ 10	$ 22.4
Purchase price adjustments				5.9
Proceeds from divestitures, net				$ 16.5
Acres of real estate sold | a				5,000

Going Concern (Details)

Going Concern (Details) - USD ($) $ in Millions	Apr. 27, 2020	Apr. 26, 2020	Mar. 31, 2020
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 950
Subsequent Event [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 950	$ 650
Other Long-term Debt		$ 1,100

Long Term Debt - Components (De

Long Term Debt - Components (Details) - USD ($)	Mar. 31, 2020	Dec. 31, 2019	Aug. 07, 2018
Long-Term Debt
Line of credit, amount outstanding	$ 470,000,000	$ 470,000,000	$ 600,500,000
Unamortized debt issuance costs on Senior Notes	(13,842,000)	(14,412,000)
Total long-term debt	1,556,347,000	1,555,777,000
Less: current portion of long-term debt	0	0
Total long-term debt, net of current portion	1,556,347,000	1,555,777,000
Credit Facility
Long-Term Debt
Line of credit, amount outstanding	470,000,000	470,000,000
Second Lien Notes and Senior Notes
Long-Term Debt
Debt outstanding	400,000,000	400,000,000
Senior Notes due 2026
Long-Term Debt
Debt outstanding	$ 700,189,000	$ 700,189,000

Long Term Debt - Credit Facilit

Long Term Debt - Credit Facility (Details) - USD ($)	3 Months Ended
	Mar. 31, 2020	May 11, 2020	Apr. 27, 2020	Apr. 26, 2020	Dec. 31, 2019	Sep. 30, 2019	Jul. 31, 2019	Aug. 07, 2018
Long-Term Debt
Total commitments	$ 1,500,000,000
Line of Credit Facility, Maximum Borrowing Capacity	950,000,000
Line of credit, amount outstanding	470,000,000				$ 470,000,000			$ 600,500,000
Letters of credit outstanding							$ 8,700,000
Available credit under the facility	480,000,000
Subsequent Event [Member]
Long-Term Debt
Line of Credit Facility, Maximum Borrowing Capacity			$ 950,000,000	$ 650,000,000
Borrowing base		$ 0
Standby Letters of Credit
Long-Term Debt
Letters of credit outstanding						$ 49,500,000
Credit Facility
Long-Term Debt
Line of credit, amount outstanding	$ 470,000,000				$ 470,000,000
Credit Facility | Minimum
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.375%
Debt Covenant, Current ratio	1
Credit Facility | Maximum
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.50%
Hedging limit percentage	85.00%
Debt Covenant, Net Debt to EBITDAX ratio	4
Credit Facility | Borrowing Base, Utilization Level 1
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.38%
Credit Facility | Borrowing Base, Utilization Level 2
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.38%
Credit Facility | Borrowing Base, Utilization Level 3
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.50%
Credit Facility | Borrowing Base, Utilization Level 4
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.50%
Credit Facility | Borrowing Base, Utilization Level 5
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.50%
Credit Facility | LIBOR | Borrowing Base, Utilization Level 1
Variable interest rate terms and debt covenant ratios
Margin rate, percent	1.50%
Credit Facility | LIBOR | Borrowing Base, Utilization Level 2
Variable interest rate terms and debt covenant ratios
Margin rate, percent	1.75%
Credit Facility | LIBOR | Borrowing Base, Utilization Level 3
Variable interest rate terms and debt covenant ratios
Margin rate, percent	2.00%
Credit Facility | LIBOR | Borrowing Base, Utilization Level 4
Variable interest rate terms and debt covenant ratios
Margin rate, percent	2.25%
Credit Facility | LIBOR | Borrowing Base, Utilization Level 5
Variable interest rate terms and debt covenant ratios
Margin rate, percent	2.50%
Credit Facility | Base Rate | Borrowing Base, Utilization Level 1
Variable interest rate terms and debt covenant ratios
Margin rate, percent	0.50%
Credit Facility | Base Rate | Borrowing Base, Utilization Level 2
Variable interest rate terms and debt covenant ratios
Margin rate, percent	0.75%
Credit Facility | Base Rate | Borrowing Base, Utilization Level 3
Variable interest rate terms and debt covenant ratios
Margin rate, percent	1.00%
Credit Facility | Base Rate | Borrowing Base, Utilization Level 4
Variable interest rate terms and debt covenant ratios
Margin rate, percent	1.25%
Credit Facility | Base Rate | Borrowing Base, Utilization Level 5
Variable interest rate terms and debt covenant ratios
Margin rate, percent	1.50%

Long Term Debt - Senior Notes (

Long Term Debt - Senior Notes (Details) - USD ($)	1 Months Ended		3 Months Ended
	Jan. 31, 2018	Oct. 31, 2017	Mar. 31, 2020	Mar. 31, 2019
Long-Term Debt
Gain (Loss) on Repurchase of Debt Instrument			$ 0	$ 7,317,000
Senior Notes due 2024
Long-Term Debt
Face amount of debt			$ 400,000,000
Interest rate percentage		7.375%
Proceeds from debt, net of discounts and issuance costs		$ 392,600,000
Immediate Due and Payable clause, percentage of holdings		25.00%
Senior Notes due 2026
Long-Term Debt
Face amount of debt	$ 750,000,000
Interest rate percentage	5.625%
Proceeds from debt, net of discounts and issuance costs	$ 737,900,000
Immediate Due and Payable clause, percentage of holdings	25.00%

Long Term Debt - Debt Discount,

Long Term Debt - Debt Discount, Issuance Costs, Interest (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Jan. 04, 2019
Interest Incurred On Long Term Debt
Interest expense	$ 22.3
Interest costs capitalized	2.1	$ 2
Note Repurchase Program, Authorized Amount			$ 100
Note Repurchase Program, Amount Outstanding	35.8
Note Repurchase Program, Amount Repurchased	28.5
Credit Facility | Other non-current assets
Long-Term Debt
Accumulated amortization, debt issuance costs	2.2
Debt issuance costs	13.8
Second Lien Notes
Long-Term Debt
Amortization of debt discount	$ 1.2	1.5
Interest Incurred On Long Term Debt
Interest expense		$ 20.8

Commodity Derivative Instrume_3

Commodity Derivative Instruments - Summary of Contracts (Details)	3 Months Ended
	Mar. 31, 2020USD ($)MMBTUcontract$ / bbl$ / MMBTUbbl
Commodity derivative contracts
Derivative instruments in a net liability position with credit-risk-related contingent features | $	$ 0
Derivative Instrument, Number of Counterparies | contract	9
Crude | Swaps, 2018
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	2,800,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	59.75
Crude | Swap, 2019
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	4,200,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	57.10
Crude | Crude Swap 2021 [Member]
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	1,020,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	54.84
Crude | Crude Swap 2022 [Member]
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	900,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	54.87
Crude | Calls, 2018 | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	5,300,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	54.83
Crude | Calls, 2019 | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	3,600,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	54.17
Crude | Crude Purchased Puts 2021 [Member] | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	0
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	0
Crude | Purchased Calls 2020 [Member] | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	250,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	57.06
Crude | Puts, 2018 | Purchased
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	6,250,000
Weighted average put price (in $/Bbl or $/MMBtu)	61.94
Crude | Put Option2019 [Member] | Purchased
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	3,600,000
Weighted average put price (in $/Bbl or $/MMBtu)	61.93
Crude | Crude Sold Calls 2021 [Member] | Purchased
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	0
Weighted average put price (in $/Bbl or $/MMBtu)	0
Natural Gas | Swaps, 2018
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	8,100,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	43.08
Natural Gas | Swaps, 2018 | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	27,000,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu) | $ / MMBTU	2.75
Natural Gas | Swap, 2019
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	7,800,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	43.27
Natural Gas | Swap, 2019 | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	0
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu) | $ / MMBTU	0
Natural Gas | Puts, 2018 | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	34,200,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu) | $ / MMBTU	(0.61)
Natural Gas | Crude Sold Puts 2021 [Member]
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	600,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	43
Natural Gas | Put Option2019 [Member] | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	2,400,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu) | $ / MMBTU	(0.57)
Natural Gas | Crude Sold Puts 2022 [Member]
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	600,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	43

Commodity Derivative Instrume_4

Commodity Derivative Instruments - Gross and Net Fair Value (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Sep. 30, 2019
Current assets
Gross amounts and adjustments made for net derivative assets
Gross Amounts of Recognized Assets	$ 293,761	$ 48,605
Gross Amounts Offset in the Balance Sheet	(129,431)	(31,051)
Net Amounts of Assets Presented in the Balance Sheet	164,330	17,554
Gross Amounts not Offset in the Balance Sheet	(716)	0
Net Amounts	252,397	30,783
Non-current assets
Gross amounts and adjustments made for net derivative assets
Gross Amounts of Recognized Assets	127,705	38,034
Gross Amounts Offset in the Balance Sheet	(38,922)	(24,805)
Net Amounts of Assets Presented in the Balance Sheet	88,783	13,229
Gross Amounts not Offset in the Balance Sheet	0	0
Net Amounts	0	0
Current liabilities
Gross amounts and adjustments made for net derivative liabilities
Gross Amounts of Recognized Liabilities	(130,147)	(33,049)
Gross Amounts Offset in the Balance Sheet	129,431	31,051
Net Amounts of Liabilities Presented in the Balance Sheet	(716)	(1,998)
Gross Amounts not Offset in the Balance Sheet	716	0
Net Amounts	0	(2,106)
Non-current liabilities
Gross amounts and adjustments made for net derivative liabilities
Gross Amounts of Recognized Liabilities	(38,922)	(24,913)
Gross Amounts Offset in the Balance Sheet	38,922	24,805
Net Amounts of Liabilities Presented in the Balance Sheet	0	(108)
Gross Amounts not Offset in the Balance Sheet	0	0
Net Amounts	$ 0	$ 0

Commodity Derivative Instrume_5

Commodity Derivative Instruments - Gain (Loss) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Income (loss) on derivatives
Commodity derivatives gain (loss)	$ 263,015,000	$ (122,091,000)
Other income (expense)
Income (loss) on derivatives
Gain (Loss) on Price Risk Derivatives, Net	$ 263,015,000	$ (122,091,000)

Asset Retirement Obligations -

Asset Retirement Obligations - Summary (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2020USD ($)
Asset retirement obligations
Balance beginning of period	$ 95,908
Liabilities incurred or acquired	192
Liabilities settled	(10,787)
Revisions in estimated cash flows	6,638
Accretion expense	1,822
Balance end of period	$ 93,773

Fair Value Measurements - Recur

Fair Value Measurements - Recurring Basis (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Sep. 30, 2019
Fair Value Measurements
Impairment of Oil and Gas Properties	$ 800	$ 8,200
Recurring
Financial Assets:
Commodity derivative assets	253,113		$ 30,783
Financial Liabilities:
Commodity derivative liabilities	716		2,106
Recurring | Level 1
Financial Assets:
Commodity derivative assets	0		0
Financial Liabilities:
Commodity derivative liabilities	0		0
Recurring | Level 2
Financial Assets:
Commodity derivative assets	253,113		30,783
Financial Liabilities:
Commodity derivative liabilities	716		2,106
Recurring | Level 3
Financial Assets:
Commodity derivative assets	0		0
Financial Liabilities:
Commodity derivative liabilities	$ 0		$ 0

Fair Value Measurements - Finan

Fair Value Measurements - Financial Instruments (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Fair Value of Financial Instruments
Unamortized debt discount and debt issuance costs	$ 13,842	$ 14,412
Carrying Amount | Senior Notes due 2024
Fair Value of Financial Instruments
Long-term debt	395,075		$ 394,824
Unamortized debt discount and debt issuance costs	4,900		5,200
Carrying Amount | Senior Notes due 2026
Fair Value of Financial Instruments
Long-term debt	691,272		690,953
Unamortized debt discount and debt issuance costs	8,900		9,200
Fair value | Level 2 | Senior Notes due 2024
Fair Value of Financial Instruments
Long-term debt	68,000		250,000
Fair value | Level 2 | Senior Notes due 2026
Fair Value of Financial Instruments
Long-term debt	119,032		420,113
Line of Credit | Carrying Amount
Fair Value of Financial Instruments
Long-term debt	470,000		470,000
Line of Credit | Fair value | Level 2
Fair Value of Financial Instruments
Long-term debt	$ 470,000		$ 470,000

Fair Value Measurements - Nonre

Fair Value Measurements - Nonrecurring (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Impairment of Oil and Gas Properties	$ 0.8	$ 8.2

Income Taxes - Effective Tax Ra

Income Taxes - Effective Tax Rate (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Income Taxes
Effective combined U.S. federal and state income tax rate	19.60%	23.60%
Naked Credit Deferred Tax Liability, Tax Expense (Benefit)	$ 2.2
Deferred Tax Assets, Valuation Allowance			$ 246.1

Unit and Stock-Based Compensa_3

Unit and Stock-Based Compensation - Long Term Incentive Plan (Details) shares in Millions	May 31, 2019shares
2016 Long Term Incentive Plan
Share-based compensation
Total reserve	32.2

Unit and Stock-Based Compensa_4

Unit and Stock-Based Compensation - Long Term Incentive Plan Options (Details) - USD ($) $ in Thousands, shares in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Compensation costs
Share-based compensation expense	$ 0	$ 13,008
Stock Options
Number of Shares
Non-vested Stock Options at end of period (in shares)	5.2
2016 Long Term Incentive Plan | Stock Options
Compensation costs
Share-based compensation expense	$ 0	$ 3,800
Unrecognized compensation costs	$ 0

Unit and Stock-Based Compensa_5

Unit and Stock-Based Compensation - Long Term Incentive Plan RSUs (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Compensation costs
Share-based compensation expense	$ 0	$ 13,008
2016 Long Term Incentive Plan | Stock Options
Compensation costs
Share-based compensation expense	$ 0	3,800
2016 Long Term Incentive Plan | RSUs
Restricted Stock Units ("RSUs")
Forfeiture rate (as a percent)	0.00%
Compensation costs
Share-based compensation expense	$ 800	$ 6,900
Unrecognized compensation cost	$ 8,300
Weighted-average period for recognition, unvested awards	2 years 2 months 12 days
2016 Long Term Incentive Plan | Vesting Period One
Restricted Stock Units ("RSUs")
Vesting period, in years	1 year
2016 Long Term Incentive Plan | Vesting Period One | RSUs - One Year Vesting
Restricted Stock Units ("RSUs")
Vesting percentage	100.00%
2016 Long Term Incentive Plan | Vesting Period One | RSUs - Three Year Vesting
Restricted Stock Units ("RSUs")
Vesting percentage	25.00%
2016 Long Term Incentive Plan | Vesting Period Two
Restricted Stock Units ("RSUs")
Vesting period, in years	2 years
2016 Long Term Incentive Plan | Vesting Period Two | RSUs - Three Year Vesting
Restricted Stock Units ("RSUs")
Vesting percentage	25.00%
2016 Long Term Incentive Plan | Vesting Period Three | RSUs - Three Year Vesting
Restricted Stock Units ("RSUs")
Vesting percentage	50.00%

Unit and Stock-Based Compensa_6

Unit and Stock-Based Compensation - Long Term Incentive Plan RSUs Rollforward (Details) - 2016 Long Term Incentive Plan	3 Months Ended
	Mar. 31, 2020$ / sharesshares
RSUs
Number of Shares
Non-vested units at beginning of period (in shares) | shares	2,635,765
Granted (in shares) | shares	1,252,000
Forfeited (in shares) | shares	(351,679)
Vested (in shares) | shares	(356,008)
Non-vested units at end of period (in shares) | shares	3,180,078
Weighted Average Grant Date Fair Value
Non-vested units at beginning of period (in dollars per share) | $ / shares	$ 8.32
Granted (in dollars per share) | $ / shares	0.31
Forfeited (in dollars per share) | $ / shares	9.44
Vested (in dollars per share) | $ / shares	14.23
Non-vested units at end of period (in dollars per share) | $ / shares	$ 4.38
Performance Stock Awards
Number of Shares
Non-vested units at beginning of period (in shares) | shares	2,863,190
Granted (in shares) | shares	5,952,700
Forfeited (in shares) | shares	0
Vested (in shares) | shares	0
Non-vested units at end of period (in shares) | shares	8,815,890
Weighted Average Grant Date Fair Value
Non-vested units at beginning of period (in dollars per share) | $ / shares	$ 7.72
Granted (in dollars per share) | $ / shares	0.29
Forfeited (in dollars per share) | $ / shares	0
Vested (in dollars per share) | $ / shares	0
Non-vested units at end of period (in dollars per share) | $ / shares	$ 2.70

Unit and Stock-Based Compensa_7

Unit and Stock-Based Compensation - Incentive Restricted Stock Units (Details) - USD ($) $ in Thousands, shares in Millions	Jul. 17, 2017	Mar. 31, 2020	Mar. 31, 2019
Incentive Units
Share-based compensation expense		$ 0	$ 13,008
Compensation costs
Unit-based compensation		$ 0	13,008
Employee Incentive | Incentive RSUs | Vesting Period One
Incentive Units
Vesting percentage	25.00%	25.00%
Employee Incentive | Incentive RSUs | Vesting Period Two
Incentive Units
Vesting percentage	25.00%	25.00%
Employee Incentive | Incentive RSUs | Vesting Period Three
Incentive Units
Vesting percentage	25.00%	50.00%
Employee Incentive | Incentive RSUs | Vesting Period Four
Incentive Units
Vesting percentage	25.00%
Employee Incentive | Vesting Period One
Incentive Units
Vesting period, in years		1 year
Employee Incentive | Vesting Period Two
Incentive Units
Vesting period, in years		2 years
Employee Incentive | Incentive RSUs
Compensation costs
Unit-based compensation		$ 0	800
Officers | Employee Incentive | Employee Incentive | Common Stock
Incentive Units
Shares contributed to Extraction Employee Incentive, LLC		2.7
2016 Long Term Incentive Plan | Vesting Period One
Incentive Units
Vesting period, in years		1 year
2016 Long Term Incentive Plan | Vesting Period Two
Incentive Units
Vesting period, in years		2 years
2016 Long Term Incentive Plan | Stock Options
Incentive Units
Share-based compensation expense		$ 0	3,800
2016 Long Term Incentive Plan | RSUs
Incentive Units
Forfeiture rate (as a percent)		0.00%
Share-based compensation expense		$ 800	$ 6,900
Compensation costs
Unrecognized compensation cost		$ 8,300
Weighted-average period for recognition, unvested awards		2 years 2 months 12 days

Unit and Stock-Based Compensa_8

Unit and Stock-Based Compensation - RUAs (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Compensation costs
Unit-based compensation costs	$ 0	$ 13,008
2016 Long Term Incentive Plan | Stock Options
Compensation costs
Unit-based compensation costs	$ 0	$ 3,800

Unit and Stock-Based Compensa_9

Unit and Stock-Based Compensation Unit and Stock-Based Compensation - Performance Stock Awards (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation	$ 0	$ 13,008
Performance Stock Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation	(800)	$ 1,500
Unrecognized compensation cost	$ 5,200
Weighted-average period for recognition, unvested awards	2 years 3 months 18 days
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested, Number of Shares	5.2
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 18.50

Equity - Additional Information

Equity - Additional Information (Details) - USD ($) $ / shares in Units, $ in Thousands	May 01, 2020	Oct. 31, 2016	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019	Jul. 30, 2019	Jul. 10, 2019	Jul. 03, 2018
Class of Stock [Line Items]
Common Stock, shares issued (in shares)			137,891,740		137,891,740
Treasury Stock, Value, Acquired, Cost Method				$ 32,212
Preferred Units commitment fees and dividends paid-in-kind			$ 6,160	3,975
Common Stock
Class of Stock [Line Items]
Treasury Stock, Value, Acquired, Cost Method				77
Subsequent Event [Member]
Class of Stock [Line Items]
Sale of Stock, Price Per Share	$ 0.01
Sale of Stock, Number of Shares Issued in Transaction	1,530,000,000
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Preferred Stock, Liquidation Preference, Annualized Internal Rate of Return		17.50%
Convertible Preferred Stock, Shares Issued upon Conversion			61.9195
Preferred Stock, Redemption Price, Percentage of Liquidation Preference		135.00%
Preferred Stock, Liquidation Preference, Value			$ 194,700
Preferred Stock, Dividend Rate, Percentage		5.875%
Maximum | Series A Convertible Preferred Stock
Class of Stock [Line Items]
Dividends, Preferred Stock, Percentage Payable as Paid-in-kind		10.00%
Elevation Preferred Units [Member] | Securities Purchase Agreement [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Issued						100,000		150,000
Dividends, Preferred Stock, Paid-in-kind			5,500	3,100
Preferred Stock, Redemption Price Per Share								$ 990
Preferred Units, Commitment Fee Payable, Additional Commitment			250,000
Preferred Stock, Liquidation Preference, Value						$ 100,000	$ 150,000
Noncontrolling Interest, Amount Represented by Preferred Stock			$ 270,500
Commitment Fee Payable, Quarterly Commitment Fee, Cash or Paid-in-kind, Percent			1.00%
Preferred Units commitment fees and dividends paid-in-kind			$ 600	$ 900
Preferred Stock, Dividend Rate, Percentage			8.00%

Earnings (Loss) Per Share - Com

Earnings (Loss) Per Share - Components (Details) - USD ($) $ / shares in Units, shares in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Basic and Diluted EPS (in thousands, except per share data)
Net loss	$ 9,037,000	$ (94,032,000)
Net Income (Loss) Attributable to Noncontrolling Interest	(6,160,000)	(3,975,000)
Less: Adjustment to reflect Series A Preferred Stock dividends	4,748,000	2,721,000
Less: Adjustment to reflect Series A Preferred Stock dividends	1,770,000	1,596,000
Adjusted net loss available to common shareholders, basic and diluted	$ (3,641,000)	$ (102,324,000)
Denominator
Weighted average common shares outstanding, basic and diluted	137,726	170,702
Earnings Per Common Share
Basic and diluted (in dollars per share)	$ (0.03)	$ (0.60)

Earnings (Loss) Per Share - Exc

Earnings (Loss) Per Share - Excluded and Antidilutive Securities (Details) - shares	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Antidilutive Securities Excluded from Computation of Earnings Per Share
Securities excluded from diluted EPS calculation (in shares)	8,339,698	8,017,004
Series A Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share
Securities excluded from diluted EPS calculation (in shares)	11,472,445	11,472,445

Commitments and Contingencies -

Commitments and Contingencies - Future Minimum Lease Payments (Details) - USD ($)	Mar. 31, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
2020	$ 13,653,000	$ 19,040,000
2020	5,247,000	5,247,000
2021	2,211,000	2,211,000
2022	2,246,000	2,246,000
2023	2,301,000	2,301,000
Thereafter	8,273,000	8,273,000
Total lease payments	33,931,000	39,318,000
Less imputed interest	(4,264,000)	(4,735,000)
Present value of lease liabilities	29,667,000	34,583,000
Accounts Payable and Accrued Liabilities [Member]
Loss Contingencies [Line Items]
Present value of lease liabilities	15,200,000	17,400
Other Liabilities [Member]
Loss Contingencies [Line Items]
Present value of lease liabilities	$ 14,500,000	$ 17,200

Commitments and Contingencies_2

Commitments and Contingencies - Drilling Rigs (Details) - Drilling Rig Commitments $ in Millions	May 06, 2020USD ($)	Mar. 31, 2020USD ($)well
Drilling Rigs
Number of drilling rigs | well		2
Early termination obligation		$ 9
Subsequent Event [Member]
Drilling Rigs
Early termination obligation	$ 8

Commitments and Contingencies_3

Commitments and Contingencies - Commitments (Details) MBoe in Thousands, MBbls in Thousands	Apr. 02, 2020USD ($)	Jul. 07, 2017MMcf	Dec. 15, 2016MMcfBcf	Jul. 31, 2019USD ($)dekathermcontract	Feb. 28, 2019USD ($)MMcf / dbbl / d	Nov. 30, 2018rig	Mar. 31, 2020USD ($)MBoebbl / drigMMcfMBbls	Dec. 31, 2019USD ($)	Apr. 30, 2019USD ($)	Aug. 07, 2017processing_plant
Delivery and Gathering commitments
Letters of credit outstanding | $				$ 8,700,000
Aggregate estimated payments due | $				$ 31,000,000			$ 1,103,800,000
Gathering Commitment, Long Term Crude Oil, Remaining Fiscal Year | MBbls							6,492
Gathering Commitment, Long Term Crude Oil, Gas, Remaining Fiscal Year | MMcf							25,815,000
Gathering Commitment, Total Commitments, Remaining Fiscal Year | MBoe							10,794
Gathering Commitment, Long Term Crude Oil, Year Two | MBbls							9,797
Gathering Commitment, Long Term Crude Oil, Gas, Year Two | MMcf							46,540,000
Gathering Commitment, Total Commitments, Year Two | MBoe							17,554
Gathering Commitment, Long Term Crude Oil, Year Three | MBbls							8,944
Gathering Commitment, Long Term Crude Oil, Gas, Year Three | MMcf							49,758,000
Gathering Commitment, Total Commitments, Year Three | MBoe							17,237
Gathering Commitment, Long Term Crude Oil, Year Four | MBbls							9,490
Gathering Commitment, Long Term Crude Oil, Gas, Year Four | MMcf							41,850,000
Gathering Commitment, Total Commitments, Year Four | MBoe							16,465
Gathering Commitment, Long Term Crude Oil, Year Five | MBbls							9,516
Gathering Commitment, Long Term Crude Oil, Gas, Year Five | MMcf							34,160,000
Gathering Commitment, Total Commitments, Year Five | MBoe							15,209
Gathering Commitment, Long Term Crude Oil, Thereafter | MBbls							29,860
Gathering Commitment, Long Term Crude Oil, Gas, Thereafter | MMcf							40,260,000
Gathering Commitment, Total Commitments, Thereafter | MBoe							36,570
Gathering Commitment, Long Term Crude Oil | MBbls							74,099
Gathering Commitment, Long Term Crude Oil, Gas | MMcf							238,383,000
Gathering Commitment, Total Commitments | MBoe							113,829
Gathering commitment, number of contracts | contract				3
Gathering commitment, residual gas, amount per day | dekatherm				125,000
Residual gas commitment, term				5 years
Loss Contingency, Midstream, Maximum Exposure | $							$ 15,700,000
Long Term Crude Oil Delivery Commitment, November 2016, Ten Year Term
Delivery and Gathering commitments
Letters of credit outstanding | $									$ 40,000,000
Aggregate estimated payments due | $									$ 655,800,000
Long Term Crude Oil Delivery Commitment, November 2016, Ten Year Term | Minimum
Delivery and Gathering commitments
Delivery commitment, in barrels per day (Bpd), year one							45,000
Delivery commitment, in barrels per day (Bpd), year two							55,800
Delivery commitment, in barrels per day (Bpd), years three through seven							61,800
Delivery commitment, in barrels per day (Bpd), years eight through ten							58,000
Long Term Crude Oil Delivery Commitment July2019 Ten Year Term [Member]
Delivery and Gathering commitments
Delivery commitment, in barrels per day (Bpd), year one							9,167
Delivery commitment, in barrels per day (Bpd), year two							17,967
Number of Delivery Commitments | rig							2
Delivery Commitment, Long Term Crude Oil, Year Six Through Ten							10,000
Delivery Commitment, Long Term Crude Oil, Year Three Through Five							18,800
Long Term Crude Oil Gathering Commitments [Member]
Delivery and Gathering commitments
Delivery commitment, in barrels per day (Bpd), year one							3,200
Delivery commitment, in barrels per day (Bpd), year two							8,000
Aggregate estimated payments due | $							$ 117,700,000
Delivery commitment, in barrels per day (Bpd), years four through eight							16,000
Delivery commitment, in barrels per day (Bpd), year ten							10,000
Delivery commitment, in barrels per day (Bpd), year nine							12,000
Delivery Commitment, in barrels per day (Bpd), year three							14,000
Natural Gas Gathering and Processing Expansion Commitment
Delivery and Gathering commitments
Delivery Commitment, Long Term Take In Kind Gas Gather Agreements, Year One					4,000
Delivery Commitment, Long Term Take In Kind Gas Gather Agreements, Year Two Through Seven					7,500
Processing Plant, Number | processing_plant										2
Delivery commitment, daily | MMcf		20.6	51.5
Annual minimum volume (in bcf) | Bcf			13
Oil and Gas Delivery Commitments and Contracts, Baseline Daily Production | MMcf		65
Payments for Other Commitments | $					$ 299,300,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year Seven | MMcf / d					52,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year Six | MMcf / d					70,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year Five | MMcf / d					98,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year Four | MMcf / d					118,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year Three | MMcf / d					140,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year Two | MMcf / d					125,000
Delivery Commitment, Long Term Gas Gathering Agreements, Year One | MMcf / d					85,000
Elevation Gathering Commitment [Member]
Delivery and Gathering commitments
Aggregate estimated payments due | $							$ 34,700,000
Payments for Other Commitments | $							$ 23,500,000	$ 19,500,000
Gathering Commitment, Payment For Development and Construction, Percent							135.00%
Elevation Matador Facility Commitment [Member]
Delivery and Gathering commitments
Loss Contingency, Midstream, Maximum Exposure | $							$ 20,700,000
Broomfield [Member] | Elevation Gathering Commitment [Member]
Delivery and Gathering commitments
Gathering Commitment, Number of Wells | rig						100
Hawkeye [Member] | Elevation Gathering Commitment [Member]
Delivery and Gathering commitments
Gathering Commitment, Number of Wells | rig						325
Elevation | Subsequent Event [Member]
Delivery and Gathering commitments
Administrative penalty | $	$ 46,800,000

Related Party Transactions - Du

Related Party Transactions - Due to Related Parties (Details) - USD ($)	Apr. 02, 2020	Mar. 31, 2020	Dec. 31, 2019	Jan. 31, 2018
Elevation | Subsequent Event [Member]
Due to Related Party
Administrative penalty	$ 46,800,000
Senior Notes Due 2024 [Member] | Related Party Debt Transaction | 5% Holdings' Members
Due to Related Party
Face amount of debt		$ 400,000,000
Debt outstanding		54,900,000
Senior Notes due 2026
Due to Related Party
Face amount of debt				$ 750,000,000
Debt outstanding		700,189,000	$ 700,189,000
Senior Notes due 2026 | Related Party Debt Transaction | 5% Holdings' Members
Due to Related Party
Face amount of debt		750,000,000
Debt outstanding		$ 56,200,000

Segment Information (Details)

Segment Information (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2020USD ($)segment	Mar. 31, 2019USD ($)	Dec. 31, 2019USD ($)
Segment Reporting Information [Line Items]
Number of Operating Segments | segment	2
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	$ 123,895	$ 138,187
Depreciation, Depletion and Amortization	(76,051)	(118,770)
Impairment of Long-Lived Assets Held-for-use	(775)	(8,248)
Other Cost and Expense, Operating	52,575	0
Exploration Expense	(112,480)	(6,194)
Gain (Loss) On Disposition of Property Plant Equipment and Unconsolidated Subsidiaries	0	222
Commodity derivatives gain (loss)	263,015	(122,091)
Unrealized Gain (Loss) on Derivatives and Commodity Contracts	(39,295)	10,329
Premiums Paid For Settlement of Derivatives	0	9,549
Share-based compensation expense	0	13,008
Amortization of Debt Issuance Costs	(1,242)	(1,497)
Gain (Loss) on Repurchase of Debt Instrument	0	7,317
Interest Revenue (Expense), Net	(20,116)	(18,828)
Loss on deconsolidation of Elevation Midstream, LLC	(73,139)	0
Revenues	165,187	221,917
Operating Expenses	70,565	0
Interest Income, Other	90	779
Interest Expense	(21,358)	(13,008)
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	480	338
Operating Expense and Other Income (Expense)	(167,404)	(130,661)
Assets	2,703,388	4,096,999	$ 2,926,957
Payments to Acquire Property, Plant, and Equipment	149,130	217,485
Equity Method Investments	0	17,555
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	11,237	(123,032)
Exploration and Production [Member]
Segment Reporting Information [Line Items]
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	122,639	138,339
Revenues	163,714	221,917
Assets	2,703,388	3,813,513
Gathering and Facilities [Member]
Segment Reporting Information [Line Items]
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	1,256	(152)
Revenues	5,986	0
Assets	0	284,200
Operating Segments [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	122,639	138,339
Depreciation, Depletion and Amortization	74,952	118,751
Revenues	163,714	221,917
Operating Expenses	70,924	0
Interest Income, Other	61	154
Interest Expense	(21,358)	(13,008)
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	0	0
Operating Expense and Other Income (Expense)	(167,173)	(131,605)
Payments to Acquire Property, Plant, and Equipment	155,441	158,622
Equity Method Investments	0	0
Operating Segments [Member] | Gathering and Facilities [Member]
Segment Reporting Information [Line Items]
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	1,256	(152)
Depreciation, Depletion and Amortization	1,099	19
Revenues	1,473	0
Operating Expenses	3,935	0
Interest Income, Other	29	625
Interest Expense	0	0
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	480	338
Operating Expense and Other Income (Expense)	(4,525)	944
Payments to Acquire Property, Plant, and Equipment	(6,311)	58,863
Equity Method Investments	0	17,555
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(4,513)	0
Operating Expenses	(4,294)	0
Operating Expense and Other Income (Expense)	4,294	0
Assets	0	(714)
Intersegment Eliminations [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Revenues	0	0
Intersegment Eliminations [Member] | Gathering and Facilities [Member]
Segment Reporting Information [Line Items]
Revenues	$ 4,513	$ 0