Extraction Oil & Gas (XOG) 10-Q 7 Nov 19 2019 Q3 Quarterly report Financial data

Cover

Cover - shares	9 Months Ended
	Sep. 30, 2019	Oct. 28, 2019
Cover page.
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
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	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		138,628,707
Amendment Flag	false
Entity Central Index Key	0001655020
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 57,728,000	$ 234,986,000
Accounts receivable
Trade	55,095,000	41,695,000
Oil, natural gas and NGL sales	69,750,000	91,225,000
Inventory and prepaid expenses	19,489,000	26,816,000
Commodity derivative asset	66,480,000	48,907,000
Assets held for sale	0	21,008,000
Total Current Assets	268,542,000	464,637,000
Property and Equipment (successful efforts method), at cost:
Proved oil and gas properties	4,494,226,000	3,916,622,000
Unproved oil and gas properties	572,400,000	609,284,000
Wells in progress	104,429,000	144,323,000
Less: accumulated depletion, depreciation and amortization	(1,498,608,000)	(1,152,590,000)
Net oil and gas properties	3,672,447,000	3,517,639,000
Gathering systems and facilities	307,038,000	114,469,000
Other property and equipment, net of accumulated depreciation	73,265,000	39,849,000
Net Property and Equipment	4,052,750,000	3,671,957,000
Non-Current Assets:
Commodity derivative asset	41,520,000	8,432,000
Other non-current assets	66,346,000	21,001,000
Total Non-Current Assets	107,866,000	29,433,000
Total Assets	4,429,158,000	4,166,027,000
Current Liabilities:
Accounts payable and accrued liabilities	216,193,000	186,218,000
Revenue payable	96,140,000	117,344,000
Production taxes payable	114,969,000	57,516,000
Commodity derivative liability	108,000	196,000
Accrued interest payable	17,272,000	22,249,000
Asset retirement obligations	26,426,000	15,729,000
Liabilities related to assets held for sale	0	3,146,000
Total Current Liabilities	471,108,000	402,398,000
Non-Current Liabilities:
Credit facility	550,000,000	285,000,000
Senior Notes, net of unamortized debt issuance costs	1,085,217,000	1,132,659,000
Production taxes payable	70,560,000	115,607,000
Commodity derivative liability	83,000	0
Other non-current liabilities	23,412,000	8,072,000
Asset retirement obligations	67,500,000	54,062,000
Deferred tax liability	115,876,000	109,176,000
Total Non-Current Liabilities	1,912,648,000	1,704,576,000
Total Liabilities	2,383,756,000	2,106,974,000
Commitments and Contingencies—Note 11
Series A Convertible Preferred Stock, $0.01 par value; 50,000,000 shares authorized; 185,280 issued and outstanding	169,282,000	164,367,000
Stockholders' Equity:
Common stock, $0.01 par value; 900,000,000 shares authorized; 138,073,124 and 171,666,485 issued and outstanding	1,336,000	1,678,000
Treasury stock, at cost, 38,859,078 and 4,543,262 shares	(170,138,000)	(32,737,000)
Additional paid-in capital	2,164,921,000	2,153,661,000
Accumulated deficit	(378,220,000)	(375,788,000)
Total Extraction Oil & Gas, Inc. Stockholders' Equity	1,617,899,000	1,746,814,000
Noncontrolling interest	258,221,000	147,872,000
Total Stockholders' Equity	1,876,120,000	1,894,686,000
Total Liabilities and Stockholders' Equity	$ 4,429,158,000	$ 4,166,027,000

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - $ / shares	Sep. 30, 2019	Mar. 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)	171,893,157	171,834,605
Common Stock, shares outstanding (in shares)	171,893,157	171,834,605
Treasury stock (in shares)	165,385	0

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues:
Revenues	$ 196,974	$ 282,160	$ 640,948	$ 772,571
Operating Expenses:
Lease operating expenses	22,979	20,283	68,445	61,760
Production taxes	9,711	21,605	46,419	66,317
Exploration expenses	13,245	11,038	32,725	21,326
Depletion, depreciation, amortization and accretion	114,996	107,315	352,134	310,296
Impairment of long lived assets	0	16,166	11,233	16,294
Gain on sale of property and equipment and assets of unconsolidated subsidiary	(1,011)	(83,559)	(1,329)	(143,461)
General and administrative expenses	27,445	35,365	85,835	100,565
Total Operating Expenses	194,287	139,999	624,604	462,381
Operating Income	2,687	142,161	16,344	310,190
Other Income (Expense):
Commodity derivatives gain (loss)	87,956	(35,913)	39,383	(175,752)
Interest expense	(23,224)	(20,725)	(54,791)	(103,229)
Other income	1,337	1,827	3,332	3,094
Total Other Income (Expense)	66,069	(54,811)	(12,076)	(275,887)
Income Before Income Taxes	68,756	87,350	4,268	34,303
Income tax expense	(20,600)	(22,200)	(6,700)	(12,300)
Net Loss	48,156	65,150	(2,432)	22,003
Net income attributable to noncontrolling interest	5,776	3,305	13,849	3,305
Net Income (Loss) Attributable to Extraction Oil & Gas, Inc.	42,380	61,845	(16,281)	18,698
Adjustments to reflect Series A Preferred Stock dividends and accretion of discount	(4,403)	(4,236)	(13,079)	(12,593)
Net Income (Loss) Attributable to Common Shareholders	$ 37,977	$ 57,609	$ (29,360)	$ 6,105
Earnings Per Common Share
Basic and diluted (in dollars per share)	$ 0.28	$ 0.33	$ (0.19)	$ 0.03
Weighted Average Common Shares Outstanding
Basic and diluted (in shares)	137,789	175,814	155,847	175,269
Oil sales
Revenues:
Revenues	$ 171,074	$ 225,467	$ 521,623	$ 619,211
Natural gas sales
Revenues:
Revenues	16,801	23,103	74,385	66,991
NGL sales
Revenues:
Revenues	9,099	33,590	44,940	86,369
Transporting And Gathering
Operating Expenses:
Transportation and gathering	$ 6,922	$ 11,786	$ 29,142	$ 29,284

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY - USD ($) shares in Thousands, $ 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, 2017		172,060	165
Balance at beginning of period at Dec. 31, 2017	$ 1,616,765	$ 1,718	$ (2,105)	$ 2,114,795	$ (497,643)	$ 1,616,765
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Series A Preferred Stock dividends	(2,721)			(2,721)		(2,721)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,438			1,438		1,438
Share-based compensation (in shares)		2,794
Stock-based compensation	15,721
Restricted stock issued, including payment of tax withholdings using withheld shares	(2,305)			(2,305)		(2,305)
Net loss	(51,995)			0		(51,995)
Repurchased of common stock (in shares)			166
Repurchase of common stock	(2,309)		$ 2,309			(2,309)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		852
Net loss					(51,995)
Balance at end of period (in units or shares) at Mar. 31, 2018		175,706	331
Balance at end of period at Mar. 31, 2018	1,571,718	$ 1,718	$ (4,414)	2,124,052	(549,638)	1,571,718	$ 0
Balance at beginning of period (in units or shares) at Dec. 31, 2017		172,060	165
Balance at beginning of period at Dec. 31, 2017	1,616,765	$ 1,718	$ (2,105)	2,114,795	(497,643)	1,616,765
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Preferred Units issued	148,500
Preferred Units commitment fees and dividends paid-in-kind	(3,305)
Net loss	22,003
Balance at end of period (in units or shares) at Sep. 30, 2018		175,861	485
Balance at end of period at Sep. 30, 2018	1,810,329	$ 1,718	$ (6,539)	2,146,918	(475,640)	1,666,457	143,872
Balance at beginning of period (in units or shares) at Mar. 31, 2018		175,706	331
Balance at beginning of period at Mar. 31, 2018	1,571,718	$ 1,718	$ (4,414)	2,124,052	(549,638)	1,571,718	0
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Series A Preferred Stock dividends	(2,722)			(2,722)		(2,722)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,477			1,477		1,477
Share-based compensation (in shares)		0
Stock-based compensation	17,743
Restricted stock issued, including payment of tax withholdings using withheld shares	(226)			(226)		(226)
Net loss	8,848			0		8,848
Repurchase of common stock	0
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		92
Net loss					8,848
Balance at end of period (in units or shares) at Jun. 30, 2018		175,798	331
Balance at end of period at Jun. 30, 2018	1,593,884	$ 1,718	$ (4,414)	2,137,370	(540,790)	1,593,884	0
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Preferred Units issuance costs	7,933						7,933
Preferred Units issued	(148,500)						(148,500)
Series A Preferred Stock dividends	(2,721)			(2,721)		(2,721)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,515			1,515		1,515
Preferred Units commitment fees and dividends paid-in-kind	0			(3,305)		(3,305)	3,305
Stock-based compensation	17,420			17,420		17,420
Restricted stock issued, including payment of tax withholdings using withheld shares	(331)			(331)		(331)
Net loss	65,150					65,150
Repurchased of common stock (in shares)			154
Repurchase of common stock	(2,125)	$ 0	$ 2,125			(2,125)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		63
Net loss	65,150				65,150
Balance at end of period (in units or shares) at Sep. 30, 2018		175,861	485
Balance at end of period at Sep. 30, 2018	1,810,329	$ 1,718	$ (6,539)	2,146,918	(475,640)	1,666,457	143,872
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	$ 1,678	$ (32,737)	2,153,661	(375,788)	1,746,814	147,872
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Series A Preferred Stock dividends	(2,721)			(2,721)		(2,721)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,596			1,596		1,596
Preferred Units commitment fees and dividends paid-in-kind	0			(3,975)		(3,975)	(3,975)
Stock-based compensation	13,008			13,008		13,008
Restricted stock issued, including payment of tax withholdings using withheld shares	(454)			(454)		(454)
Net loss	(94,032)					(94,032)
Repurchased of common stock (in shares)			7,824
Repurchase of common stock	(32,212)	$ 77	$ 32,135			(32,212)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		270
Net loss					(94,032)
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	$ 1,601	$ (64,872)	2,157,923	(469,820)	1,624,832	151,837
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	$ 1,678	$ (32,737)	2,153,661	(375,788)	1,746,814	147,872
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Preferred Units issued	99,000
Preferred Units commitment fees and dividends paid-in-kind	$ (13,849)
Repurchased of common stock (in shares)	34,100
Repurchase of common stock	$ (136,900)
Net loss	(2,432)
Balance at end of period (in units or shares) at Sep. 30, 2019		176,932	38,859
Balance at end of period at Sep. 30, 2019	1,876,120	$ 1,336	$ (170,138)	2,164,921	(378,220)	1,617,899	258,221
Balance at beginning of period (in units or shares) at Mar. 31, 2019		176,480	12,367
Balance at beginning of period at Mar. 31, 2019	1,776,669	$ 1,601	$ (64,872)	2,157,923	(469,820)	1,624,832	151,837
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Series A Preferred Stock dividends	(2,722)			(2,722)		(2,722)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,637			1,637		1,637
Preferred Units commitment fees and dividends paid-in-kind	0			(4,098)		(4,098)	(4,098)
Stock-based compensation	14,957			14,957		14,957
Restricted stock issued, including payment of tax withholdings using withheld shares	(128)			(128)		(128)
Net loss	43,444					43,444
Repurchased of common stock (in shares)			21,685
Repurchase of common stock	(84,284)	$ 217	$ 84,067			(84,284)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		108
Net loss					43,444
Balance at end of period (in units or shares) at Jun. 30, 2019		176,588	34,052
Balance at end of period at Jun. 30, 2019	1,746,309	$ 1,384	$ (148,939)	2,164,295	(426,376)	1,590,364	155,945
CHANGES IN MEMBERS' AND STOCKHOLDERS' EQUITY
Preferred Units issuance costs	2,500						2,500
Preferred Units issued	(99,000)						(99,000)
Series A Preferred Stock dividends	(2,721)			(2,721)		(2,721)
Accretion of beneficial conversion feature on Series A Preferred Stock	1,682			1,682		1,682
Preferred Units commitment fees and dividends paid-in-kind	0			(5,776)		(5,776)	5,776
Stock-based compensation	11,387			11,387		11,387
Restricted stock issued, including payment of tax withholdings using withheld shares	(582)			(582)		(582)
Net loss	$ 48,156					48,156
Repurchased of common stock (in shares)	4,800		4,807
Repurchase of common stock	$ (21,247)	$ 48	$ 21,199			(21,247)
Shares Issued Under LTIP, Including Payment of Tax Withholding using Withheld Shares		344
Net loss	48,156				48,156
Balance at end of period (in units or shares) at Sep. 30, 2019		176,932	38,859
Balance at end of period at Sep. 30, 2019	$ 1,876,120	$ 1,336	$ (170,138)	$ 2,164,921	$ (378,220)	$ 1,617,899	$ 258,221

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash flows from operating activities:
Net loss	$ (2,432)	$ 22,003
Reconciliation of net income (loss) to net cash provided by operating activities:
Depletion, depreciation, amortization and accretion	352,134	310,296
Abandonment and impairment of unproved properties	26,166	15,463
Impairment of long lived assets	11,233	16,294
Gain on sale of property and equipment	(319)	(59,849)
Gain on sale of assets of unconsolidated subsidiary	1,010	83,612
Gain on repurchase of 2026 Senior Notes	(10,486)	0
Amortization of debt issuance costs	3,799	12,303
Non-cash lease expense	7,739
Deferred rent	0	442
Commodity derivatives (gain) loss	(39,383)	175,752
Settlements on commodity derivatives	(18,527)	(93,482)
Premiums paid on commodity derivatives	(2,852)	(17,271)
Earnings in unconsolidated subsidiaries	(1,217)	(1,886)
Distributions from unconsolidated subsidiaries	2,630	1,684
Make-whole premium paid on 2021 Senior Notes	0	35,600
Deferred income tax expense	6,700	12,300
Stock-based compensation	39,306	50,883
Changes in current assets and liabilities:
Accounts receivable—trade	(1,395)	4,573
Accounts receivable—oil, natural gas and NGL sales	16,293	(13,865)
Inventory and prepaid expenses	(3,479)	(637)
Accounts payable and accrued liabilities	231	(14,780)
Revenue payable	(21,723)	60,946
Production taxes payable	12,211	49,657
Accrued interest payable	(4,977)	(5,015)
Asset retirement expenditures	(14,081)	(9,437)
Net cash provided by operating activities	356,561	468,362
Cash flows from investing activities:
Oil and gas property additions	(526,187)	(774,787)
Sale of property and equipment	41,982	72,345
Gathering systems and facilities additions	(169,180)	(41,359)
Other property and equipment additions	(32,575)	(11,944)
Investment in unconsolidated subsidiaries	(22,487)	(6,000)
Distributions from unconsolidated subsidiary, return of capital	569	0
Sale of assets of unconsolidated subsidiary	1,010	83,612
Net cash used in investing activities	(706,868)	(678,133)
Cash flows from financing activities:
Borrowings under credit facility	375,000	590,000
Repayments under credit facility	(110,000)	(390,000)
Proceeds from the issuance of 2026 Senior Notes	0	739,664
Repayments of 2021 Senior Notes	0	550,000
Make-whole premium paid on 2021 Senior Notes	0	(35,600)
Repurchase of 2026 Senior Notes	(39,325)	0
Repurchase of commons stock	(137,743)	(4,434)
Payment of employee payroll withholding taxes	(1,164)	(2,862)
Dividends on Series A Preferred Stock	(8,164)	(8,164)
Debt and equity issuance costs	(2,055)	(3,103)
Preferred Units issued	99,000	148,500
Preferred Unit issuance costs	2,500	6,933
Net cash provided by financing activities	173,049	477,068
(Decrease) increase in cash and cash equivalents	(177,258)	267,297
Cash, cash equivalents and restricted cash at end of the period	57,728	274,065
Supplemental cash flow information:
Property and equipment included in accounts payable and accrued liabilities	158,178	148,156
Cash paid for interest	71,878	66,673
Issuance of promissory note to unconsolidated subsidiary	0	35,329
Extinguishment of promissory note in exchange for equity with unconsolidated subsidiary	0	(35,329)
Accretion of beneficial conversion feature of Series A Preferred Stock	4,915	4,429
Preferred Units paid-in-kind commitment fees and dividends	$ 13,849	$ 3,305

Business and Organization

Business and Organization	9 Months Ended
	Sep. 30, 2019
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 NGL reserves in the Rocky Mountain region, primarily in the Wattenberg Field of the Denver-Julesburg Basin (the “DJ Basin”) of Colorado. The Company and its subsidiaries are focused on the acquisition, development and production of oil, natural gas and NGL reserves in the Rocky Mountain region, as well as the design and support of midstream assets to gather and process crude oil and gas production focused in the DJ Basin of Colorado. Extraction is a public company listed for trading on the NASDAQ Global Select Market under the symbol "XOG". Elevation Midstream, LLC (“Elevation”), a Delaware limited liability company and an unrestricted subsidiary of the Company, is focused on the construction of gathering systems and facilities operations 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. As of September 30, 2019, these gathering systems and facilities operations were not in service, therefore, there were no associated revenues for the three and nine months then ended. On October 3, 2019, Elevation commenced moving crude oil, natural gas and water through its Badger central gathering facility, which enables Extraction to efficiently transport its crude oil and natural gas production along with water used during the completion process. The use of this gathering facility allows for the elimination of oil or water storage on the well pad site and reduces truck traffic, which minimizes the impact to the surrounding environment and communities. On July 10, 2019, Elevation closed on the issuance of an additional 100,000 Preferred Units of Elevation (the "Elevation Preferred Units") under an existing securities purchase agreement with a third party, pursuant to which Elevation had agreed to sell an additional 100,000 Elevation Preferred Units at a price of $990 per Elevation Preferred Unit with an aggregate liquidation preference of $100.0 million, and resulting in net proceeds of approximately $96.5 million, after deducting discounts and related offering expenses. These Elevation Preferred Units are non-recourse to Extraction.

Basis of Presentation, Signific

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2019
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 sheet 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. 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. Leases The Company accounts for leases in accordance with Accounting Standards Codification ("ASC") 842, Leases , which it adopted on January 1, 2019, applying the modified retrospective transition approach as of the effective date of adoption (see "Recent Accounting Pronouncements" for impacts of adoption). The Company enters into operating leases for certain drilling equipment, completions equipment, equipment ancillary to drilling and completions, office facilities, compressors and office equipment. Under ASC 842, a contract is or contains a lease when (i) the contract contains an explicitly or implicitly identified asset and (ii) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. The Company assesses whether an arrangement is or contains a lease at inception of the contract. All leases (operating leases), other than those that qualify for the short-term recognition exemption, are recognized as of the lease commencement date on the balance sheet as a liability for its obligation related to the lease and a corresponding asset representing its right to use the underlying asset over the period of use. The Company's leases have remaining terms up to nine years. Certain of our lease agreements contain options to extend or early terminate the agreement. The lease term used to calculate the lease asset and liability at commencement includes options to extend or terminate the lease when it is reasonably certain that we will exercise that option. When determining whether it is reasonably certain that the Company will exercise an option at commencement, it considers various economic factors, including capital expenditure strategies, the nature, length, and underlying terms of the agreement, as well as the uncertainty of the condition of leased equipment at the end of the lease term. Based on these determinations, the Company generally determines that the exercise of renewal options would not be reasonably certain in determining the expected lease term for leases, other than certain operating compressor leases. The discount rate used to calculate the present value of the future minimum lease payments is the rate implicit in the lease, when readily determinable. As the Company's leases generally do not provide an implicit rate, the Company uses its incremental borrowing rate based on its revolving credit facility, which includes consideration of the nature, term, and geographic location of the leased asset. Certain of the Company's leases include variable lease payments, including payments that depend on an index or rate, as well as variable payments for items such as property taxes, insurance, maintenance, and other operating expenses associated with leased assets. Payments that vary based on an index or rate are included in the measurement of the Company's lease assets and liabilities at the rate as of the commencement date. All other variable lease payments are excluded from the measurement of the Company's lease assets and liabilities and are recognized in the period in which the obligation for those payments is incurred. The Company's lease agreements do not contain any material residual value guarantees or material restrictive covenants. The Company has elected, for all classes of underlying assets, to not apply the balance sheet recognition requirements of ASC 842 to leases with a term of one year or less, and instead, recognize the lease payments in the condensed consolidated statements of operations on a straight-line basis over the lease term. The Company has also made the election, for its certain drilling equipment, completions equipment, equipment ancillary to drilling and completions, compressors and office equipment classes of underlying assets, to account for lease and non-lease components in a contract as a single lease component. For the three and nine months ended September 30, 2019, lease costs, which represent the straight-line lease expense of right-of-use ("ROU") assets and short-term leases, were as follows (in thousands): Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019 Lease Costs included in the Condensed Consolidated Balance Sheets Proved oil and gas properties, including drilling, completions and ancillary equipment, and gathering systems and facilities (1) $ 92,023 $ 230,940 Lease Costs included in the Condensed Consolidated Statements of Operations Operating lease costs (2) $ 9,210 $ 22,627 General and administrative expenses (3) $ 1,054 $ 2,811 Total operating lease costs $ 10,264 $ 25,438 Total lease costs $ 102,287 $ 256,378 (1) Represents short-term lease capital expenditures related to drilling rigs, completions equipment and other equipment ancillary to the drilling and completion of wells. (2) Includes $2.3 million and $6.5 million of lease costs and $0.2 million and $0.4 million of variable costs associated with operating leases for the three and nine months ended September 30, 2019, respectively. (3) Includes $0.3 million and $1.0 million of lease costs and $0.4 million and $1.0 million of variable costs associated with operating leases, as well as $0.1 million and $0.2 million of sublease income for the three and nine months ended September 30, 2019, respectively. Supplemental cash flow information related to operating leases for the nine months ended September 30, 2019, was as follows (in thousands): Nine Months Ended September 30, 2019 Cash paid for amounts included in the measurements of lease liabilities Operating cash flows from operating leases $ (9,014) Right-of-use assets obtained in exchange for lease obligations Operating leases $ (2,997) Supplemental balance sheet information related to operating and finance leases as of September 30, 2019, were as follows (in thousands, except lease term and discount rate): Classification As of September 30, 2019 Operating Leases Operating lease right-of-use assets Other non-current assets $ 20,470 Operating lease obligation - short-term Accounts payable and accrued liabilities 9,236 Operating lease obligation - long-term Other non-current liabilities 16,827 Total operating lease liabilities $ 26,063 Weighted Average Remaining Lease Term in Years Operating leases 5.8 Weighted Average Discount Rate Operating leases 4.7 % As of September 30, 2019, the Company was subject to commitments on one drilling rig contracted through November 2019. These costs are capitalized within proved oil and gas properties on the condensed consolidated balance sheets and are included as short-term lease costs. Beginning in November 2019, the Company will be subject to commitments on one drilling rig contracted through February 2021. As of September 30, 2019, the Company had an insignificant amount of additional operating leases that have not yet commenced, of which none included involvement with the construction or design of the underlying asset. Recent Accounting Pronouncements In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02—Leases (Topic 842), which requires lessee recognition on the balance sheet of a right of use asset and a lease liability, initially measured at the present value of the lease payments. It further requires recognition in the income statement of a single lease cost, calculated so that the cost of the lease is allocated over the lease term on a generally straight-line basis. Finally, it requires classification of all cash payments within operating activities in the statements of cash flows. It is effective for fiscal years commencing after December 15, 2018. The FASB subsequently issued ASU No. 2017-13, ASU No. 2018-01, ASU No. 2018-10, ASU No. 2018-11 and ASU No. 2019-01, which provided additional implementation guidance. The Company adopted the accounting standard using a modified retrospective transition approach, which applies the provisions of the new guidance at the effective date without adjusting the comparative periods presented. The Company has elected the package of practical expedients permitted under the transition guidance with the new standard, which among other things, requires no reassessment of whether existing contracts are or contain leases as well as no reassessment of lease classification for existing leases upon adoption. The Company has also elected the optional practical expedient permitted under the transition guidance within the new standard related to land easements that allows it to carry forward its current accounting treatment for land easements on existing agreements upon adoption. The Company made an accounting policy election to keep leases with an initial term of twelve months or less off of the condensed consolidated balance sheet. The adoption of this guidance resulted in the recognition of right-of-use ("ROU") assets of approximately $26.3 million, and current and non-current lease liabilities for operating leases of approximately $10.1 million and $21.1 million, respectively, as of January 1, 2019, including immaterial reclassifications of prepaid rent, deferred rent and lease incentive liability balances. The adoption of this guidance did not have a material impact to the Company's cash flows from operating, investing, or financing activities. In June 2016, the FASB issued 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 will replace the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost and is 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 does not believe the adoption of this ASU will have a material impact on the Company’s consolidated financial statements as the Company does not have a history of material credit losses. In August 2018, the FASB issued Accounting Standards Update ASU No. 2018-13, which improves the disclosure requirements on fair value measurements. For public entities, the new guidance is effective for fiscal years beginning after December 15, 2019, including interim reporting periods within that reporting period. The Company is currently evaluating this new standard to determine the potential impact to its financial statements and related disclosures. Other than as disclosed above or in the Company’s Annual Report, there are no other accounting standards applicable to the Company 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 through the date of this filing.

Acquisitions

Acquisitions	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
Acquisitions	Acquisitions and Divestitures August 2019 Divestiture On August 22, 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. The Company continues to explore divestitures, as part of our ongoing initiative to divest of non-strategic assets. March 2019 Divestiture On March 27, 2019, the Company completed the sale of its interests in approximately 5,000 net acres of leasehold and producing properties for aggregate sales proceeds of approximately $22.4 million. The effective date for the March 2019 Divestiture was July 1, 2018 with purchase price adjustments calculated as of the closing date of $5.9 million, resulting in net proceeds of $16.5 million. No gain or loss was recognized for the March 2019 Divestiture. December 2018 Divestitures In December 2018, the Company completed various sales of its interests in approximately 31,200 net acres of leasehold and primarily non-producing properties, for aggregate sales proceeds of approximately $8.5 million, subject to customary purchase price adjustments, and recognized a loss of $6.1 million for the year ended December 31, 2018. August 2018 Divestiture On August 3, 2018, Elevation received proceeds of $83.6 million and recognized a gain of $83.6 million for the year ended December 31, 2018, upon the sale of assets of DJ Holdings, LLC, a subsidiary of Discovery Midstream Partners, LP, of which Elevation held a 10% membership interest. The Company acquired its interest in exchange for the contribution of an acreage dedication, which is considered a nonfinancial asset. April 2018 Divestitures In April 2018, the Company completed various sales of its interests in approximately 15,100 net acres of leasehold and primarily non-producing properties for aggregate sales proceeds of approximately $72.3 million and recognized a gain of $59.3 million for the year ended December 31, 2018. April 2018 Acquisition On April 19, 2018, the Company acquired an unaffiliated oil and gas company's interest in approximately 1,000 net acres of non-producing leasehold primarily located in Arapahoe County, Colorado. Upon closing the seller received approximately $9.4 million in cash. This transaction has been accounted for as an asset acquisition. The acquisition provided new development opportunities in the Core DJ Basin. January 2018 Acquisition On January 8, 2018, the Company acquired an unaffiliated oil and gas company's interest in approximately 1,200 net acres of non-producing leasehold located in Arapahoe County, Colorado. Upon closing the seller received approximately $11.6 million in cash. This transaction has been accounted for as an asset acquisition. The acquisition provided new development opportunities in the Core DJ Basin.

Long Term Debt

Long Term Debt	9 Months Ended
	Sep. 30, 2019
Debt Instrument [Line Items]
Long-Term Debt	Long-Term Debt As of the dates indicated, the Company’s long-term debt consisted of the following (in thousands): September 30, December 31, Credit facility due August 16, 2022 (or an earlier time as set forth in the credit facility) $ 550,000 $ 285,000 2024 Senior Notes due May 15, 2024 400,000 400,000 2026 Senior Notes due February 1, 2026 700,189 750,000 Unamortized debt issuance costs on Senior Notes (14,972) (17,341) Total long-term debt 1,635,217 1,417,659 Less: current portion of long-term debt — — Total long-term debt, net of current portion $ 1,635,217 $ 1,417,659 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 of the Company (the "Series A Preferred Stock") have not been converted into common equity or redeemed prior to April 15, 2021, 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. No principal payments are generally required until the credit agreement matures or in the event that the borrowing base falls below the outstanding balance. In January 2019, the Company amended its revolving credit facility to permit prepayments and redemptions of its unsecured bonds, subject to certain term, conditions and financial thresholds. In June 2019, the Company amended its revolving credit facility to (i) increase the elected commitments from $650.0 million to $900.0 million, (ii) increase the amount for permitted letters of credit from $50.0 million to $100.0 million and increase in the letter of credit for the Company's oil marketer from $35.0 million to $40.0 million, (iii) decrease the borrowing base from $1.2 billion to $1.1 billion and (iv) increase the limitation on permitted investments from $15.0 million to $20.0 million. In August 2019, the Company amended its revolving credit facility to increase the elected commitments from $900.0 million to $1.0 billion. As of September 30, 2019, the credit facility was subject to a borrowing base of $1.1 billion, subject to current elected commitments of $1.0 billion. As of September 30, 2019 and December 31, 2018, the Company had outstanding borrowings of $550.0 million and $285.0 million, respectively, and had standby letters of credit of $49.4 million and $35.7 million, respectively, which reduces the availability of the undrawn borrowing base. At September 30, 2019, the undrawn balance under the credit facility was $450.0 million before letters of credit. This 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. As of October 31, 2019, the Company has $550.0 million in borrowings outstanding under the credit facility. On November 4, 2019, the Company amended its revolving credit facility to decrease the borrowing base from $1.1 billion to $950.0 million, associated with the scheduled borrowing base redetermination. The current elected commitments were also decreased to $950.0 million. 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 and estimated cash flows from these reserves and other information deemed relevant by the administrative agent under the Company's revolving credit 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 Borrowing Base Utilization Percentage Utilization Eurodollar Base Rate Commitment Level 1 < 25% 1.50 % 0.50 % 0.375 % Level 2 ≥ 25% < 50% 1.75 % 0.75 % 0.375 % Level 3 ≥ 50% < 75% 2.00 % 1.00 % 0.500 % Level 4 ≥ 75% < 90% 2.25 % 1.25 % 0.500 % Level 5 ≥ 90% 2.50 % 1.50 % 0.500 % 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 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), subject to pro forma adjustments for non-ordinary course acquisitions and divestitures) for the four fiscal quarter period most recently ended, of not greater than 4.0:1.0. The Company was in compliance with all financial covenants under the credit facility as of September 30, 2019 and through the filing of this report. 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. 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 a separate 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 of September 30, 2019, $49.9 million of cash was held by Elevation and is earmarked for construction of pipeline infrastructure to serve the development of acreage in its Hawkeye and Southwest Wattenberg areas. 2021 Senior Notes In July 2016, the Company issued at par $550.0 million principal amount of 7.875% Senior Notes due July 15, 2021 (the “2021 Senior Notes” and the offering, the “2021 Senior Notes Offering”). The 2021 Senior Notes bore an annual interest rate of 7.875%. The interest on the 2021 Senior Notes was payable on January 15 and July 15 of each year commencing on January 15, 2017. The Company received net proceeds of approximately $537.2 million after deducting discounts and fees. Concurrent with the 2026 Senior Notes Offering (as defined below), the Company commenced a cash tender offer to purchase any and all of its 2021 Senior Notes. On January 24, 2018, the Company received approximately $500.6 million aggregate principal amount of the 2021 Senior Notes which were validly tendered (and not validly withdrawn). As a result, on January 25, 2018, the Company made a cash payment of approximately $534.2 million, which includes a principal of approximately $500.6 million, a make-whole premium of approximately $32.6 million and accrued and unpaid interest of approximately $1.0 million. On February 17, 2018, the Company redeemed approximately $49.4 million aggregate principal amount of the 2021 Senior Notes that remained outstanding after the Tender Offer and made a cash payment of approximately $52.7 million to the remaining holders of the 2021 Senior Notes, which included a make-whole premium of $3.0 million and accrued and unpaid interest of approximately $0.3 million. 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 Note Guarantors”). The 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 notes. The 2024 Senior Notes also contain affirmative and negative covenants that, among other things, limit the Company's and the 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 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 (the “2024 Senior Notes Indenture”) 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 the offering, 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 used $534.2 million of the net proceeds from the 2026 Senior Notes Offering to fund the tender offer for its 2021 Senior Notes, $52.7 million to redeem any 2021 Senior Notes not tendered and the remainder for general corporate purposes. 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 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 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 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 (the “2026 Senior Notes Indenture”) 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 September 30, 2019, the Company had debt issuance costs, net of accumulated amortization, of $3.9 million related to its credit facility which has been reflected on the Company’s condensed consolidated balance sheet within the line item other non-current assets. As of September 30, 2019, the Company had debt issuance costs, net of accumulated amortization, of $15.0 million related to its 2024 and 2026 Senior Notes (collectively, the "Senior Notes") which has been reflected on the Company's balance sheet 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 and nine months ended September 30, 2019, the Company recorded amortization expense related to debt issuance costs of $1.0 million and $3.8 million, respectively, as compared to $0.9 million and $12.3 million for the three and nine months ended September 30, 2018, respectively. Debt issuance costs for the nine months ended September 30, 2018 included $9.4 million of acceleration of amortization expense upon the repayment of the Company's 2021 Senior Notes. The repayment of the Company's 2021 Senior Notes had no impact to amortization expense for the three and nine months ended September 30, 2019 and the three and nine months ended September 30, 2018. Interest Incurred on Long-Term Debt For the three and nine months ended September 30, 2019, the Company incurred interest expense on long-term debt of $23.8 million and $66.9 million, respectively, as compared to $21.5 million and $61.6 million for the three and nine months ended September 30, 2018, respectively. For the three and nine months ended September 30, 2019, the Company capitalized interest expense on long term debt of $1.6 million and $5.4 million, respectively, as compared to $1.7 million and $6.3 million for the three and nine months ended September 30, 2018, respectively, which has been reflected in the Company’s condensed consolidated financial statements. Also included in interest expense for the nine months ended September 30, 2018 was a make-whole premium of $35.6 million related to the Company's repayment of its 2021 Senior Notes in January and February 2018. The repayment of the Company's 2021 Senior Notes had no impact to interest expense for the three and nine months ended September 30, 2019 and the three months ended September 30, 2018. 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 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 September 30, 2019, the Company did not repurchase 2026 Senior Notes. For the nine months ended September 30, 2019, the Company repurchased a nominal value of $49.8 million for $39.3 million in connection with the Senior Notes Repurchase Program. Interest expense for the nine months ended September 30, 2019 included a $10.5 million gain on debt repurchase related to the Company's Senior Note Repurchase Program. The Senior Note Repurchase Program had no impact to interest expense for three and nine months ended September 30, 2018.

Commodity Derivative Instrument

Commodity Derivative Instruments	9 Months Ended
	Sep. 30, 2019
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. 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. 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 are no credit risks 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 September 30, 2019 are summarized below: 2019 2020 2021 2022 2023 NYMEX WTI Crude Swaps: Notional volume (Bbl) 3,950,000 3,200,001 3,000,000 1,020,000 900,000 Weighted average fixed price ($/Bbl) $ 57.86 $ 59.81 $ 57.80 $ 54.84 $ 54.87 NYMEX WTI Crude Purchased Puts: Notional volume (Bbl) 200,000 9,725,001 1,800,000 — — Weighted average purchased put price ($/Bbl) $ 60.00 $ 54.99 $ 55.02 $ — $ — NYMEX WTI Crude Sold Calls: Notional volume (Bbl) 200,000 9,725,001 1,800,000 — — Weighted average sold call price ($/Bbl) $ 64.00 $ 62.04 $ 63.70 $ — $ — NYMEX WTI Crude Sold Puts: Notional volume (Bbl) 1,000,000 12,250,002 4,200,000 600,000 600,000 Weighted average sold put price ($/Bbl) $ 44.60 $ 42.91 $ 43.50 $ 43.00 $ 43.00 NYMEX HH Natural Gas Swaps: Notional volume (MMBtu) 9,000,000 35,400,000 — — — Weighted average fixed price ($/MMBtu) $ 2.75 $ 2.75 $ — $ — $ — NYMEX HH Natural Gas Purchased Puts: Notional volume (MMBtu) — 600,000 — — — Weighted average purchased put price ($/MMBtu) $ — $ 2.90 $ — $ — $ — NYMEX HH Natural Gas Sold Calls: Notional volume (MMBtu) — 600,000 — — — Weighted average sold call price ($/MMBtu) $ — $ 3.48 $ — $ — $ — CIG Basis Gas Swaps: Notional volume (MMBtu) 11,100,000 43,200,000 — — — Weighted average fixed basis price ($/MMBtu) $ (0.72) $ (0.61) $ — $ — $ — 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 September 30, 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 (4) $ 114,221 $ (47,741) $ 66,480 $ (83) $ 107,917 Non-current assets $ 77,188 $ (35,668) $ 41,520 $ — $ — Current liabilities (4) $ (47,849) $ 47,741 $ (108) $ 83 $ (108) Non-current liabilities $ (35,751) $ 35,668 $ (83) $ — $ — As of December 31, 2018 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 (5) $ 115,852 $ (66,945) $ 48,907 $ (192) $ 57,147 Non-current assets $ 17,217 $ (8,785) $ 8,432 $ — $ — Current liabilities (5) $ (67,141) $ 66,945 $ (196) $ 192 $ (4) Non-current liabilities $ (8,785) $ 8,785 $ — $ — $ — (1) Agreements are in place with all of the Company’s financial trading counterparties 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 item and all counterparties in a net liability position are shown in the current liability line item. (4) Gross current liabilities include a deferred premium liability of $1.7 million related to the Company's deferred premiums. Gross current assets include a deferred premium asset of $0.4 million related to the Company's deferred premiums. (5) Gross current liabilities include a deferred premium liability of $7.7 million related to the Company's deferred put premiums. Gross current assets include a deferred premium asset of $0.8 million related to the Company's deferred put premiums. The table below sets forth the commodity derivatives gain (loss) for the three and nine months ended September 30, 2019 and 2018 (in thousands). Commodity derivatives gain (loss) is included under the other income (expense) line item in the condensed consolidated statements of operations. For the Three Months Ended September 30, For the Nine Months Ended September 30, 2019 2018 2019 2018 Commodity derivatives gain (loss) $ 87,956 $ (35,913) $ 39,383 $ (175,752)

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2019
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 Nine Months Ended September 30, 2019 Balance beginning of period $ 69,791 Liabilities incurred or acquired $ 315 Liabilities settled $ (15,484) Revisions in estimated cash flows $ 35,466 Accretion expense $ 3,838 Balance end of period $ 93,926

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 and December 31, 2018 by level within the fair value hierarchy (in thousands): Fair Value Measurement at September 30, 2019 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 108,000 $ — $ 108,000 Financial Liabilities: Commodity derivative liabilities $ — $ 191 $ — $ 191 Fair Value Measurement at December 31, 2018 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 57,339 $ — $ 57,339 Financial Liabilities: Commodity derivative liabilities $ — $ 196 $ — $ 196 The following methods and assumptions were used to estimate the fair value of the assets and liabilities in the table 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 4 - 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 September 30, 2019 At December 31, 2018 Carrying Amount Fair Value Carrying Amount Fair Value Credit Facility $ 550,000 $ 550,000 $ 285,000 $ 285,000 2024 Senior Notes (1) $ 394,577 $ 262,000 $ 393,866 $ 330,000 2026 Senior Notes (2) $ 690,640 $ 428,865 $ 738,793 $ 558,750 (1) The carrying amount of the 2024 Senior Notes includes unamortized debt issuance costs of $5.4 million and $6.1 million as of September 30, 2019 and December 31, 2018, respectively. (2) The carrying amount of the 2026 Senior Notes includes unamortized debt issuance costs of $9.5 million and $11.2 million as of September 30, 2019 and December 31, 2018, 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. The Company utilizes fair value on a non-recurring basis to review its proved oil and gas properties for potential impairment when events and circumstances indicate, and at least annually, a possible decline in the recoverability of the carrying value of such property. The Company uses an income approach analysis based on the net discounted future cash flows of producing property. The future cash flows are based on management’s estimates for the future. Unobservable inputs include estimates of oil and gas production, as the case may be, from the Company’s reserve reports, commodity prices based on the sales contract terms and forward price curves, operating and development costs and a discount rate based on a market-based weighted average cost of capital (all of which are Level 3 inputs within the fair value hierarchy). For the three months ended September 30, 2019, the Company recognized no impairment expense on its proved oil and gas properties. For the nine months ended September 30, 2019, the Company recognized $11.2 million of impairment expense on its proved oil and gas properties.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company computes an estimated annual effective rate 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 annual effective rate applied to the year-to-date ordinary income or loss, plus the tax effect of any significant discrete or infrequently occurring items recorded during the interim period. The computation of the annual estimated effective tax rate at each interim period requires certain estimates and significant judgment 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 nine months ended September 30, 2019 was 156.8%. During the nine months ended September 30, 2019, the Company recognized income tax expense of $6.7 million. The effective rate for the nine months ended September 30, 2019 differs from the statutory U.S. federal income tax rate of 21.0% primarily due to state income taxes and estimated permanent differences. The significant differences during the nine months ended September 30, 2019 as compared with nine months ended months ended September 30, 2018 included income attributable to non-controlling interest and a discrete item regarding the tax deficiency of the stock-based compensation compared to the compensation recognized for financial reporting purposes. The cumulative effect of the estimated permanent differences and discrete items applied to the pre-tax book income for the nine months ended September 30, 2019 resulted in an income tax expense that exceeds book income. The Company anticipates the potential for increased periodic volatility in future effective tax rates from the impact of stock-based compensation tax deductions as they are treated as discrete tax items.

Unit and Stock-Based Compensati

Unit and Stock-Based Compensation	9 Months Ended
	Sep. 30, 2019
Disclosure of Compensation Related Costs, Share-based Payments [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 and three, respectively. Grant date fair value was determined based on the value of Extraction’s common stock pursuant to the terms of the LTIP. The Company assumed a forfeiture rate of zero as part of the grant date estimate of compensation cost. The Company recorded $6.6 million and $20.6 million of stock-based compensation costs related to RSUs for the three and nine months ended September 30, 2019, respectively, as compared to $7.1 million and $20.7 million for the three and nine months ended September 30, 2018, respectively. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of September 30, 2019, there was $16.5 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 1.5 years. The following table summarizes the RSU activity from January 1, 2019 through September 30, 2019 and provides information for RSUs outstanding at the dates indicated. Number of Shares Weighted Average Grant Date Non-vested RSUs at January 1, 2019 3,102,335 $ 16.91 Granted 1,901,418 $ 4.76 Forfeited (280,029) $ 12.91 Vested (1,011,340) $ 15.33 Non-vested RSUs at September 30, 2019 3,712,384 $ 11.42 Performance Stock Awards The Company granted performance stock awards ("PSAs") to certain executives under the LTIP in October 2017, March 2018 and April 2019. 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 $0.7 million and $6.8 million of stock-based compensation costs related to PSAs for the three and nine months ended September 30, 2019, respectively, as compared to $1.6 million and $4.2 million of stock-based compensation related to PSAs for the three and nine months ended September 30, 2018, respectively. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of September 30, 2019, there was $9.3 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 1.2 years. The following table summarizes the PSA activity from January 1, 2019 through September 30, 2019 and provides information for PSAs outstanding at the dates indicated. Number of Shares (1) Weighted Average Grant Date Non-vested PSAs at January 1, 2019 2,794,083 $ 9.00 Granted 1,646,218 $ 5.44 Forfeited — $ — Vested — $ — Non-vested PSAs at September 30, 2019 4,440,301 $ 7.68 (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 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 $4.0 million and $11.5 million of stock-based compensation costs related to the stock options for the three and nine months ended September 30, 2019, respectively, as compared to $3.8 million and $11.3 million for the three and nine months ended September 30, 2018, respectively. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of September 30, 2019, there was $0.7 million of unrecognized compensation cost related to the stock options that is expected to be recognized over a weighted average period of 0.1 years. The following table summarizes the stock option activity from January 1, 2019 through September 30, 2019 and provides information for stock options outstanding at the dates indicated. Number of Options Weighted Average Exercise Price Non-vested Stock Options at January 1, 2019 1,748,148 $ 18.50 Granted — $ — Forfeited — $ — Vested (543,977) $ 18.72 Non-vested Stock Options at September 30, 2019 1,204,171 $ 18.41 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 and three, respectively. On July 17, 2017, the partners of Employee Incentive amended the vesting schedule in which 25% vested immediately and the remaining Incentive RSUs vest 25%, 25% and 25% each six months thereafter, over the remaining 18-month service period. Grant date fair value was determined based on the value of Extraction’s common stock on the date of issuance. The Company assumed a forfeiture rate of zero as part of the grant date estimate of compensation cost. The Company recorded no stock-based compensation costs related to Incentive RSUs for the three months ended September 30, 2019. The Company recorded $0.8 million of stock-based compensation costs related to Incentive RSUs for the nine months ended September 30, 2019. The Company recorded $4.9 million and $14.7 million of stock-based compensation costs related to Incentive RSUs for the three and nine months ended September 30, 2018, respectively. These costs were included in the condensed consolidated statements of operations within the general and administrative expenses line item. As of September 30, 2019, there are no remaining unrecognized compensation costs related to the Incentive RSUs granted to certain employees. The following table summarizes the Incentive RSU activity from January 1, 2019 through September 30, 2019 and provides information for Incentive RSUs outstanding at the dates indicated. Number of Shares Weighted Average Grant Date Non-vested Incentive RSUs at January 1, 2019 476,000 $ 20.45 Granted — $ — Forfeited — $ — Vested (476,000) $ 20.45 Non-vested Incentive RSUs at September 30, 2019 — $ —

Earnings (Loss) Per Share

Earnings (Loss) Per Share	9 Months Ended
	Sep. 30, 2019
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 (the “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 and nine months ended September 30, 2019 and 2018. The components of basic and diluted EPS were as follows (in thousands, except per share data): For the Three Months Ended For the Nine Months Ended September 30, September 30, 2019 2018 2019 2018 Basic and Diluted Income (Loss) Per Share Net income (loss) $ 48,156 $ 65,150 $ (2,432) $ 22,003 Less: Noncontrolling interest (5,776) (3,305) (13,849) (3,305) Less: Adjustment to reflect Series A Preferred Stock dividends (2,721) (2,721) (8,164) (8,164) Less: Adjustment to reflect accretion of Series A Preferred Stock discount (1,682) (1,515) (4,915) (4,429) Adjusted net loss available to common shareholders, basic and diluted $ 37,977 $ 57,609 $ (29,360) $ 6,105 Denominator: Weighted average common shares outstanding, basic and diluted (1) (2) 137,789 175,814 155,847 175,269 Income (Loss) Per Common Share Basic and diluted $ 0.28 $ 0.33 $ (0.19) $ 0.03 (1) For the three and nine months ended September 30, 2019, 8,956,812 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	9 Months Ended
	Sep. 30, 2019
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. On January 1, 2019, the Company adopted ASC Topic 842, Leases, using the modified retrospective approach. Refer to Note 2—Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements, Leases for additional information. Maturities of operating lease liabilities, associated with ROU assets and including imputed interest, as of September 30, 2019, were as follows (in thousands): Operating Leases 2019 - remaining $ 2,956 2020 8,675 2021 3,340 2022 2,211 2023 2,246 Thereafter 10,573 Total lease payments 30,001 Less imputed interest (1) (3,938) Present value of lease liabilities (2) $ 26,063 (1) Calculated using the estimated interest rate for each lease. (2) Of the total present value of lease liabilities, $9.7 million was recorded in "Accounts payable and accrued liabilities" and$17.2 million was recorded in "Other non-current liabilities" on the condensed consolidated balance sheets. As of December 31, 2018, minimum future contractual payments for operating leases under the scope of ASC 840 for certain office facilities and drilling rigs are as follows (in thousands): Operating Leases 2019 - remaining $ 12,713 2020 3,371 2021 3,385 2022 3,360 2023 3,411 Thereafter 15,719 Total lease payments $ 41,959 Drilling Rigs As of September 30, 2019, the Company was subject to commitments on one drilling rig contracted through November 2019. 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 Note 2—Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements, Leases . Beginning in November 2019, the Company will be subject to commitments on one drilling rig contracted through February 2021. In the event of early termination of these contracts, the Company would be obligated to pay an aggregate amount of approximately $11.7 million as of September 30, 2019, as required under the terms of the contracts. Delivery Commitments As of September 30, 2019, the Company’s oil marketer was 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. In April 2019, the Company extended the term of this agreement through October 31, 2020, subject to an evergreen provision thereafter and has posted a letter of credit in the amount of $40.0 million. The Company evaluates its contracts for loss contingencies and accrues for such losses, if the loss can be reasonably estimated and deemed probable. During the third quarter of 2019, the Company determined that it likely will not be able to satisfy a portion of the minimum volume commitment in the future and therefore accrued estimated payments up to $6.7 million that will be amortized into oil revenues over the remaining term of the contract. The Company has two long-term crude oil gathering commitments with an unconsolidated subsidiary, in which the Company has a minority ownership interest, and a long-term gas gathering agreement with a third party midstream provider. The summary of these minimum volume commitments as of September 30, 2019, was as follows: Oil (MBbl) Gas (MMcf) Total (MBOE) 2019 - Remaining 2,024 5,185 2,888 2020 8,935 33,550 14,527 2021 10,349 46,540 18,106 2022 9,128 49,758 17,421 2023 9,490 41,850 16,465 Thereafter 38,824 74,420 51,227 Total 78,750 251,303 120,634 The aggregate amount of estimated remaining payments under these agreements is $437.8 million. Also, 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 51.5 and 20.6 MMcf per day, respectively, 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 volumes 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. The Company also has a long-term gas gathering agreement with a third party midstream provider that will commence in or around January 2020 and has a term of ten years with an annual minimum volume commitment of 13.0 Bcf in years one through ten. We may be required to pay an annual shortfall fee for any volume deficiencies under this commitment, calculated based on the weighted average sales price during the corresponding annual period. Under its current drilling plans, the Company expects to meet these volume commitments. 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 amount of estimated commitment assuming no production is $34.5 million. Litigation and Legal Items We are involved in various legal proceedings. We review 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. We have 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, we currently believe 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, we are exposed to environmental risks. We have 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, we are not aware of any material environmental claims existing as of September 30, 2019 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 other accrued expenses on the condensed consolidated balance sheets. The liability ultimately incurred with respect to a matter may exceed the related accrual. Colorado Bradenhead Testing Matter. In February 2019, we resolved by an administrative order by consent (“AOC”) with the COGCC administrative claims for allegations of noncompliance of State bradenhead testing rules at six pad sites in Weld County, Colorado. The AOC includes an administrative penalty of $0.8 million, of which $0.65 million of the total penalty is to be offset by our commensurate contribution to a public project and our requirement to undertake the required testing and improvements to the Company’s standard operating procedures. We have concluded that the resolution of this action did not have a material adverse effect on our financial position, results of operations or cash flows. 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. We do 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.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Office Lease with Affiliate of a Director In April 2016, the Company subleased office space to Star Peak Capital, LLC, of which a member of the board of directors is an owner, for $1,400 per month. The sublease commenced on May 1, 2016 and expires on February 28, 2020. 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.

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Segment Reporting Disclosure [Text Block]	Segment Information Beginning in the fourth quarter of 2018, the Company has two operating segments, (i) the exploration, development and production of oil, natural gas and NGL (the "exploration and production segment") and (ii) the construction and support of midstream assets to gather and process crude oil and gas production (the "gathering and facilities segment"). Prior to the fourth quarter of 2018, the Company had a single operating segment. The gathering systems and facilities operating segment was under development as of September 30, 2019. Capital expenditures associated with gathering systems and facilities are being incurred to develop midstream infrastructure to support the Company's development of its oil and gas leasehold along with third-party activity. The Company's exploration and production segment revenues are derived from third parties. The Company’s gathering and facilities segment was in the construction phase and no revenue generating activities had commenced as of September 30, 2019; however, on October 3, 2019, Elevation commenced moving crude oil, natural gas and water through its Badger central gathering facility. Financial information of the Company's reportable segments was as follows for the three months ended September 30, 2019 and 2018 (in thousands). For the Three Months Ended September 30, 2019 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 196,974 $ — $ — $ 196,974 Intersegment revenues — — — — Total Revenues $ 196,974 $ — $ — $ 196,974 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (114,971) $ (25) $ — $ (114,996) Interest income 114 355 — 469 Interest expense (23,224) — — (23,224) Earnings in unconsolidated subsidiaries — 640 — 640 Subtotal Operating Expenses and Other Income (Expense): $ (138,081) $ 970 $ — $ (137,111) Segment Assets $ 4,015,499 $ 395,224 $ 18,435 $ 4,429,158 Capital Expenditures $ 134,998 $ 65,098 $ — $ 200,096 Investment in Equity Method Investees $ — $ 35,992 $ — $ 35,992 Segment EBITDAX $ 158,523 $ (622) $ — $ 157,901 For the Three Months Ended September 30, 2018 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 282,160 $ — $ — $ 282,160 Intersegment revenues — — — — Total Revenues $ 282,160 $ — $ — $ 282,160 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (107,315) $ — $ — $ (107,315) Interest income 135 635 — 770 Interest expense (20,725) — — (20,725) Earnings in unconsolidated subsidiaries — 843 — 843 Subtotal Operating Expenses and Other Income (Expense): $ (127,905) $ 1,478 $ — $ (126,427) Segment Assets $ 3,894,535 $ 264,014 $ (224) $ 4,158,325 Capital Expenditures $ 202,811 $ 37,548 $ — $ 240,359 Investment in Equity Method Investees $ — $ 14,510 $ — $ 14,510 Segment EBITDAX $ 170,004 $ (601) $ — $ 169,403 Financial information of the Company's reportable segments was as follows for the nine months ended September 30, 2019 and 2018 (in thousands). For the Nine Months Ended September 30, 2019 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 640,948 $ — $ — $ 640,948 Intersegment revenues — — — — Total Revenues $ 640,948 $ — $ — $ 640,948 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (352,062) $ (72) $ — $ (352,134) Interest income 372 1,286 — 1,658 Interest expense (54,791) — — (54,791) Earnings in unconsolidated subsidiaries — 1,179 — 1,179 Subtotal Operating Expenses and Other Income (Expense): $ (406,481) $ 2,393 $ — $ (404,088) Segment Assets $ 4,015,499 $ 395,224 $ 18,435 $ 4,429,158 Capital Expenditures $ 516,510 $ 192,568 $ — $ 709,078 Investment in Equity Method Investees $ — $ 35,992 $ — $ 35,992 Segment EBITDAX $ 426,571 $ (1,168) $ — $ 425,403 For the Nine Months Ended September 30, 2018 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 772,571 $ — $ — $ 772,571 Intersegment revenues — — — — Total Revenues $ 772,571 $ — $ — $ 772,571 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (310,296) $ — $ — $ (310,296) Interest income 280 635 — 915 Interest expense (103,229) — — (103,229) Earnings in unconsolidated subsidiaries — 1,567 — 1,567 Subtotal Operating Expenses and Other Income (Expense): $ (413,245) $ 2,202 $ — $ (411,043) Segment Assets $ 3,894,535 $ 264,014 $ (224) $ 4,158,325 Capital Expenditures $ 730,878 $ 57,224 $ — $ 788,102 Investment in Equity Method Investees $ — $ 14,510 $ — $ 14,510 Segment EBITDAX $ 463,415 $ 102 $ — $ 463,517 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 and nine months ended September 30, 2019 and 2018 (in thousands). For the Three Months Ended September 30, For the Nine Months Ended September 30, 2019 2018 2019 2018 Reconciliation of Adjusted EBITDAX to Income Before Income Taxes Exploration and production segment EBITDAX $ 158,523 $ 170,004 $ 426,571 $ 463,415 Gathering and facilities segment EBITDAX (622) (601) (1,168) 102 Subtotal of Reportable Segments $ 157,901 $ 169,403 $ 425,403 $ 463,517 Less: Depletion, depreciation, amortization and accretion $ (114,996) $ (107,315) $ (352,134) $ (310,296) Impairment of long lived assets — (16,166) (11,233) (16,294) Exploration expenses (13,245) (11,038) (32,725) (21,326) Gain on sale of property and equipment and assets of unconsolidated subsidiary 1,011 83,559 1,329 143,461 Gain (loss) on commodity derivatives 87,956 (35,913) 39,383 (175,752) Settlements on commodity derivative instruments (16,101) 41,009 8,432 99,914 Premiums paid for derivatives that settled during the period 812 1,956 19,910 5,191 Stock-based compensation expense (11,358) (17,420) (39,306) (50,883) Amortization of debt issuance costs (974) (935) (3,799) (12,303) Make-whole premium on 2021 Senior Notes — — — (35,600) Gain on repurchase of 2026 Senior Notes — — 10,486 — Interest expense (22,250) (19,790) (61,478) (55,326) Income Before Income Taxes $ 68,756 $ 87,350 $ 4,268 $ 34,303

Basis of Presentation, Signif_2

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements (Policies)	9 Months Ended
	Sep. 30, 2019
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 statements and the year-end balance sheet 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.
Recent Accounting Pronouncements	Recent Accounting PronouncementsIn February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02—Leases (Topic 842), which requires lessee recognition on the balance sheet of a right of use asset and a lease liability, initially measured at the present value of the lease payments. It further requires recognition in the income statement of a single lease cost, calculated so that the cost of the lease is allocated over the lease term on a generally straight-line basis. Finally, it requires classification of all cash payments within operating activities in the statements of cash flows. It is effective for fiscal years commencing after December 15, 2018. The FASB subsequently issued ASU No. 2017-13, ASU No. 2018-01, ASU No. 2018-10, ASU No. 2018-11 and ASU No. 2019-01, which provided additional implementation guidance. The Company adopted the accounting standard using a modified retrospective transition approach, which applies the provisions of the new guidance at the effective date without adjusting the comparative periods presented. The Company has elected the package of practical expedients permitted under the transition guidance with the new standard, which among other things, requires no reassessment of whether existing contracts are or contain leases as well as no reassessment of lease classification for existing leases upon adoption. The Company has also elected the optional practical expedient permitted under the transition guidance within the new standard related to land easements that allows it to carry forward its current accounting treatment for land easements on existing agreements upon adoption. The Company made an accounting policy election to keep leases with an initial term of twelve months or less off of the condensed consolidated balance sheet.

Basis of Presentation, Signif_3

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements (Tables)	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Lease, Cost [Table Text Block]	For the three and nine months ended September 30, 2019, lease costs, which represent the straight-line lease expense of right-of-use ("ROU") assets and short-term leases, were as follows (in thousands): Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019 Lease Costs included in the Condensed Consolidated Balance Sheets Proved oil and gas properties, including drilling, completions and ancillary equipment, and gathering systems and facilities (1) $ 92,023 $ 230,940 Lease Costs included in the Condensed Consolidated Statements of Operations Operating lease costs (2) $ 9,210 $ 22,627 General and administrative expenses (3) $ 1,054 $ 2,811 Total operating lease costs $ 10,264 $ 25,438 Total lease costs $ 102,287 $ 256,378 (1) Represents short-term lease capital expenditures related to drilling rigs, completions equipment and other equipment ancillary to the drilling and completion of wells. (2) Includes $2.3 million and $6.5 million of lease costs and $0.2 million and $0.4 million of variable costs associated with operating leases for the three and nine months ended September 30, 2019, respectively. (3) Includes $0.3 million and $1.0 million of lease costs and $0.4 million and $1.0 million of variable costs associated with operating leases, as well as $0.1 million and $0.2 million of sublease income for the three and nine months ended September 30, 2019, respectively. Supplemental cash flow information related to operating leases for the nine months ended September 30, 2019, was as follows (in thousands): Nine Months Ended September 30, 2019 Cash paid for amounts included in the measurements of lease liabilities Operating cash flows from operating leases $ (9,014) Right-of-use assets obtained in exchange for lease obligations Operating leases $ (2,997)
Assets And Liabilities, Lessee [Table Text Block]	Supplemental balance sheet information related to operating and finance leases as of September 30, 2019, were as follows (in thousands, except lease term and discount rate): Classification As of September 30, 2019 Operating Leases Operating lease right-of-use assets Other non-current assets $ 20,470 Operating lease obligation - short-term Accounts payable and accrued liabilities 9,236 Operating lease obligation - long-term Other non-current liabilities 16,827 Total operating lease liabilities $ 26,063 Weighted Average Remaining Lease Term in Years Operating leases 5.8 Weighted Average Discount Rate Operating leases 4.7 %

Long Term Debt (Tables)

Long Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Instrument [Line Items]
Schedule of long-term debt	As of the dates indicated, the Company’s long-term debt consisted of the following (in thousands): September 30, December 31, Credit facility due August 16, 2022 (or an earlier time as set forth in the credit facility) $ 550,000 $ 285,000 2024 Senior Notes due May 15, 2024 400,000 400,000 2026 Senior Notes due February 1, 2026 700,189 750,000 Unamortized debt issuance costs on Senior Notes (14,972) (17,341) Total long-term debt 1,635,217 1,417,659 Less: current portion of long-term debt — — Total long-term debt, net of current portion $ 1,635,217 $ 1,417,659
Schedule of Borrowing Base Utilization Grid	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 Borrowing Base Utilization Percentage Utilization Eurodollar Base Rate Commitment Level 1 < 25% 1.50 % 0.50 % 0.375 % Level 2 ≥ 25% < 50% 1.75 % 0.75 % 0.375 % Level 3 ≥ 50% < 75% 2.00 % 1.00 % 0.500 % Level 4 ≥ 75% < 90% 2.25 % 1.25 % 0.500 % Level 5 ≥ 90% 2.50 % 1.50 % 0.500 %

Commodity Derivative Instrume_2

Commodity Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of commodity derivative contracts	The Company’s commodity derivative contracts as of September 30, 2019 are summarized below: 2019 2020 2021 2022 2023 NYMEX WTI Crude Swaps: Notional volume (Bbl) 3,950,000 3,200,001 3,000,000 1,020,000 900,000 Weighted average fixed price ($/Bbl) $ 57.86 $ 59.81 $ 57.80 $ 54.84 $ 54.87 NYMEX WTI Crude Purchased Puts: Notional volume (Bbl) 200,000 9,725,001 1,800,000 — — Weighted average purchased put price ($/Bbl) $ 60.00 $ 54.99 $ 55.02 $ — $ — NYMEX WTI Crude Sold Calls: Notional volume (Bbl) 200,000 9,725,001 1,800,000 — — Weighted average sold call price ($/Bbl) $ 64.00 $ 62.04 $ 63.70 $ — $ — NYMEX WTI Crude Sold Puts: Notional volume (Bbl) 1,000,000 12,250,002 4,200,000 600,000 600,000 Weighted average sold put price ($/Bbl) $ 44.60 $ 42.91 $ 43.50 $ 43.00 $ 43.00 NYMEX HH Natural Gas Swaps: Notional volume (MMBtu) 9,000,000 35,400,000 — — — Weighted average fixed price ($/MMBtu) $ 2.75 $ 2.75 $ — $ — $ — NYMEX HH Natural Gas Purchased Puts: Notional volume (MMBtu) — 600,000 — — — Weighted average purchased put price ($/MMBtu) $ — $ 2.90 $ — $ — $ — NYMEX HH Natural Gas Sold Calls: Notional volume (MMBtu) — 600,000 — — — Weighted average sold call price ($/MMBtu) $ — $ 3.48 $ — $ — $ — CIG Basis Gas Swaps: Notional volume (MMBtu) 11,100,000 43,200,000 — — — Weighted average fixed basis price ($/MMBtu) $ (0.72) $ (0.61) $ — $ — $ —
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 September 30, 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 (4) $ 114,221 $ (47,741) $ 66,480 $ (83) $ 107,917 Non-current assets $ 77,188 $ (35,668) $ 41,520 $ — $ — Current liabilities (4) $ (47,849) $ 47,741 $ (108) $ 83 $ (108) Non-current liabilities $ (35,751) $ 35,668 $ (83) $ — $ — As of December 31, 2018 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 (5) $ 115,852 $ (66,945) $ 48,907 $ (192) $ 57,147 Non-current assets $ 17,217 $ (8,785) $ 8,432 $ — $ — Current liabilities (5) $ (67,141) $ 66,945 $ (196) $ 192 $ (4) Non-current liabilities $ (8,785) $ 8,785 $ — $ — $ — (1) Agreements are in place with all of the Company’s financial trading counterparties 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 item and all counterparties in a net liability position are shown in the current liability line item. (4) Gross current liabilities include a deferred premium liability of $1.7 million related to the Company's deferred premiums. Gross current assets include a deferred premium asset of $0.4 million related to the Company's deferred premiums. (5) Gross current liabilities include a deferred premium liability of $7.7 million related to the Company's deferred put premiums. Gross current assets include a deferred premium asset of $0.8 million related to the Company's deferred put premiums.
Schedule of commodity derivatives gain (loss) included in other income (expense)	The table below sets forth the commodity derivatives gain (loss) for the three and nine months ended September 30, 2019 and 2018 (in thousands). Commodity derivatives gain (loss) is included under the other income (expense) line item in the condensed consolidated statements of operations. For the Three Months Ended September 30, For the Nine Months Ended September 30, 2019 2018 2019 2018 Commodity derivatives gain (loss) $ 87,956 $ (35,913) $ 39,383 $ (175,752)

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2019
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 Nine Months Ended September 30, 2019 Balance beginning of period $ 69,791 Liabilities incurred or acquired $ 315 Liabilities settled $ (15,484) Revisions in estimated cash flows $ 35,466 Accretion expense $ 3,838 Balance end of period $ 93,926

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 and December 31, 2018 by level within the fair value hierarchy (in thousands): Fair Value Measurement at September 30, 2019 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 108,000 $ — $ 108,000 Financial Liabilities: Commodity derivative liabilities $ — $ 191 $ — $ 191 Fair Value Measurement at December 31, 2018 Level 1 Level 2 Level 3 Total Financial Assets: Commodity derivative assets $ — $ 57,339 $ — $ 57,339 Financial Liabilities: Commodity derivative liabilities $ — $ 196 $ — $ 196
Schedule of fair value of financial instruments	At September 30, 2019 At December 31, 2018 Carrying Amount Fair Value Carrying Amount Fair Value Credit Facility $ 550,000 $ 550,000 $ 285,000 $ 285,000 2024 Senior Notes (1) $ 394,577 $ 262,000 $ 393,866 $ 330,000 2026 Senior Notes (2) $ 690,640 $ 428,865 $ 738,793 $ 558,750

Unit and Stock-Based Compensa_2

Unit and Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2019
Unit and Stock-Based Compensation
Schedule summarizing stock option activity	The following table summarizes the RSU activity from January 1, 2019 through September 30, 2019 and provides information for RSUs outstanding at the dates indicated. Number of Shares Weighted Average Grant Date Non-vested RSUs at January 1, 2019 3,102,335 $ 16.91 Granted 1,901,418 $ 4.76 Forfeited (280,029) $ 12.91 Vested (1,011,340) $ 15.33 Non-vested RSUs at September 30, 2019 3,712,384 $ 11.42
Schedule of non-vested restricted award activity	The following table summarizes the PSA activity from January 1, 2019 through September 30, 2019 and provides information for PSAs outstanding at the dates indicated. Number of Shares (1) Weighted Average Grant Date Non-vested PSAs at January 1, 2019 2,794,083 $ 9.00 Granted 1,646,218 $ 5.44 Forfeited — $ — Vested — $ — Non-vested PSAs at September 30, 2019 4,440,301 $ 7.68 (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 grants, depending on the level of satisfaction of the vesting condition.
Incentive RSUs
Unit and Stock-Based Compensation
Schedule of non-vested restricted award activity	The following table summarizes the Incentive RSU activity from January 1, 2019 through September 30, 2019 and provides information for Incentive RSUs outstanding at the dates indicated. Number of Shares Weighted Average Grant Date Non-vested Incentive RSUs at January 1, 2019 476,000 $ 20.45 Granted — $ — Forfeited — $ — Vested (476,000) $ 20.45 Non-vested Incentive RSUs at September 30, 2019 — $ —

Earnings (Loss) Per Share (Tabl

Earnings (Loss) Per Share (Tables)	9 Months Ended
	Sep. 30, 2019
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 For the Nine Months Ended September 30, September 30, 2019 2018 2019 2018 Basic and Diluted Income (Loss) Per Share Net income (loss) $ 48,156 $ 65,150 $ (2,432) $ 22,003 Less: Noncontrolling interest (5,776) (3,305) (13,849) (3,305) Less: Adjustment to reflect Series A Preferred Stock dividends (2,721) (2,721) (8,164) (8,164) Less: Adjustment to reflect accretion of Series A Preferred Stock discount (1,682) (1,515) (4,915) (4,429) Adjusted net loss available to common shareholders, basic and diluted $ 37,977 $ 57,609 $ (29,360) $ 6,105 Denominator: Weighted average common shares outstanding, basic and diluted (1) (2) 137,789 175,814 155,847 175,269 Income (Loss) Per Common Share Basic and diluted $ 0.28 $ 0.33 $ (0.19) $ 0.03

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Maturities of operating lease liabilities, associated with ROU assets and including imputed interest, as of September 30, 2019, were as follows (in thousands): Operating Leases 2019 - remaining $ 2,956 2020 8,675 2021 3,340 2022 2,211 2023 2,246 Thereafter 10,573 Total lease payments 30,001 Less imputed interest (1) (3,938) Present value of lease liabilities (2) $ 26,063 (1) Calculated using the estimated interest rate for each lease. (2) Of the total present value of lease liabilities, $9.7 million was recorded in "Accounts payable and accrued liabilities" and$17.2 million was recorded in "Other non-current liabilities" on the condensed consolidated balance sheets. As of December 31, 2018, minimum future contractual payments for operating leases under the scope of ASC 840 for certain office facilities and drilling rigs are as follows (in thousands): Operating Leases 2019 - remaining $ 12,713 2020 3,371 2021 3,385 2022 3,360 2023 3,411 Thereafter 15,719 Total lease payments $ 41,959

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Financial information of the Company's reportable segments was as follows for the three months ended September 30, 2019 and 2018 (in thousands). For the Three Months Ended September 30, 2019 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 196,974 $ — $ — $ 196,974 Intersegment revenues — — — — Total Revenues $ 196,974 $ — $ — $ 196,974 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (114,971) $ (25) $ — $ (114,996) Interest income 114 355 — 469 Interest expense (23,224) — — (23,224) Earnings in unconsolidated subsidiaries — 640 — 640 Subtotal Operating Expenses and Other Income (Expense): $ (138,081) $ 970 $ — $ (137,111) Segment Assets $ 4,015,499 $ 395,224 $ 18,435 $ 4,429,158 Capital Expenditures $ 134,998 $ 65,098 $ — $ 200,096 Investment in Equity Method Investees $ — $ 35,992 $ — $ 35,992 Segment EBITDAX $ 158,523 $ (622) $ — $ 157,901 For the Three Months Ended September 30, 2018 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 282,160 $ — $ — $ 282,160 Intersegment revenues — — — — Total Revenues $ 282,160 $ — $ — $ 282,160 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (107,315) $ — $ — $ (107,315) Interest income 135 635 — 770 Interest expense (20,725) — — (20,725) Earnings in unconsolidated subsidiaries — 843 — 843 Subtotal Operating Expenses and Other Income (Expense): $ (127,905) $ 1,478 $ — $ (126,427) Segment Assets $ 3,894,535 $ 264,014 $ (224) $ 4,158,325 Capital Expenditures $ 202,811 $ 37,548 $ — $ 240,359 Investment in Equity Method Investees $ — $ 14,510 $ — $ 14,510 Segment EBITDAX $ 170,004 $ (601) $ — $ 169,403 Financial information of the Company's reportable segments was as follows for the nine months ended September 30, 2019 and 2018 (in thousands). For the Nine Months Ended September 30, 2019 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 640,948 $ — $ — $ 640,948 Intersegment revenues — — — — Total Revenues $ 640,948 $ — $ — $ 640,948 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (352,062) $ (72) $ — $ (352,134) Interest income 372 1,286 — 1,658 Interest expense (54,791) — — (54,791) Earnings in unconsolidated subsidiaries — 1,179 — 1,179 Subtotal Operating Expenses and Other Income (Expense): $ (406,481) $ 2,393 $ — $ (404,088) Segment Assets $ 4,015,499 $ 395,224 $ 18,435 $ 4,429,158 Capital Expenditures $ 516,510 $ 192,568 $ — $ 709,078 Investment in Equity Method Investees $ — $ 35,992 $ — $ 35,992 Segment EBITDAX $ 426,571 $ (1,168) $ — $ 425,403 For the Nine Months Ended September 30, 2018 Exploration and Production Gathering and Facilities Elimination of Intersegment Transactions Consolidated Total Revenues: Revenues from external customers $ 772,571 $ — $ — $ 772,571 Intersegment revenues — — — — Total Revenues $ 772,571 $ — $ — $ 772,571 Operating Expenses and Other Income (Expense): Depletion, depreciation, amortization and accretion $ (310,296) $ — $ — $ (310,296) Interest income 280 635 — 915 Interest expense (103,229) — — (103,229) Earnings in unconsolidated subsidiaries — 1,567 — 1,567 Subtotal Operating Expenses and Other Income (Expense): $ (413,245) $ 2,202 $ — $ (411,043) Segment Assets $ 3,894,535 $ 264,014 $ (224) $ 4,158,325 Capital Expenditures $ 730,878 $ 57,224 $ — $ 788,102 Investment in Equity Method Investees $ — $ 14,510 $ — $ 14,510 Segment EBITDAX $ 463,415 $ 102 $ — $ 463,517 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 and nine months ended September 30, 2019 and 2018 (in thousands). For the Three Months Ended September 30, For the Nine Months Ended September 30, 2019 2018 2019 2018 Reconciliation of Adjusted EBITDAX to Income Before Income Taxes Exploration and production segment EBITDAX $ 158,523 $ 170,004 $ 426,571 $ 463,415 Gathering and facilities segment EBITDAX (622) (601) (1,168) 102 Subtotal of Reportable Segments $ 157,901 $ 169,403 $ 425,403 $ 463,517 Less: Depletion, depreciation, amortization and accretion $ (114,996) $ (107,315) $ (352,134) $ (310,296) Impairment of long lived assets — (16,166) (11,233) (16,294) Exploration expenses (13,245) (11,038) (32,725) (21,326) Gain on sale of property and equipment and assets of unconsolidated subsidiary 1,011 83,559 1,329 143,461 Gain (loss) on commodity derivatives 87,956 (35,913) 39,383 (175,752) Settlements on commodity derivative instruments (16,101) 41,009 8,432 99,914 Premiums paid for derivatives that settled during the period 812 1,956 19,910 5,191 Stock-based compensation expense (11,358) (17,420) (39,306) (50,883) Amortization of debt issuance costs (974) (935) (3,799) (12,303) Make-whole premium on 2021 Senior Notes — — — (35,600) Gain on repurchase of 2026 Senior Notes — — 10,486 — Interest expense (22,250) (19,790) (61,478) (55,326) Income Before Income Taxes $ 68,756 $ 87,350 $ 4,268 $ 34,303

Business and Organization Busin

Business and Organization Business and Organization (Details) - USD ($) $ / shares in Units, $ in Thousands	Jul. 10, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Mar. 31, 2019	Sep. 30, 2019	Apr. 01, 2019	Nov. 19, 2018
Subsequent Event [Line Items]
Stock Repurchase Program, Authorized Amount										$ 163,200
Repurchased of common stock (in shares)		4,800,000							34,100,000
Treasury Stock, Value, Acquired, Cost Method		$ 21,247	$ 84,284	$ 32,212	$ 2,125	$ 0	$ 2,309		$ 136,900
Preferred Units [Member]
Subsequent Event [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	100,000
Sale of Stock, Price Per Share	$ 990
Preferred Stock, Liquidation Preference, Value	$ 100,000
Proceeds from Issuance or Sale of Equity	$ 96,500
Stock Repurchase Program [Member]
Subsequent Event [Line Items]
Stock Repurchase Program, Authorized Amount											$ 100,000
Repurchased of common stock (in shares)								13,000,000
Treasury Stock, Value, Acquired, Cost Method								$ 63,200
Extended Stock Repurchase Program [Member]
Subsequent Event [Line Items]
Stock Repurchase Program, Authorized Amount										$ 100,000

Basis of Presentation, Signif_4

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements - Schedules of Lease Cost and Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 10,264	$ 25,438
Total lease costs	102,287	256,378
Sublease income	100	200
Operating cash flows from operating leases		(9,014)
Right-of-use assets obtained in exchange for lease obligations		(2,997)
Lease Operating Expense [Member]
Lessee, Lease, Description [Line Items]
Operating lease cost	9,210	22,627
Total lease costs	2,300	6,500
Variable lease costs	200	400
General and Administrative Expense [Member]
Lessee, Lease, Description [Line Items]
Operating lease cost	1,054	2,811
Total lease costs	300	1,000
Variable lease costs	400	1,000
Proved Oil And Gas Properties [Member]
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 92,023	$ 230,940

Basis of Presentation, Signif_5

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements - Schedule of Future Minimum Lease Payments (Details)	Sep. 30, 2019USD ($)
Organization, Consolidation and Presentation of Financial Statements [Abstract]
2019-remaining	$ 2,956,000
2020	8,675,000
2021	3,340,000
2022	2,211,000
2023	2,246,000
Thereafter	10,573,000
Total lease payments	30,001,000
Less imputed interest	(3,938,000)
Present value of lease liabilities	$ 26,063,000

Basis of Presentation, Signif_6

Basis of Presentation, Significant Accounting Policies and Recent Accounting Pronouncements - Supplemental Balance Sheet Information (Details) - USD ($)	Sep. 30, 2019	Jan. 01, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Operating lease right-of-use assets	$ 20,470,000	$ 26,300,000
Operating lease obligation - short-term	9,236,000	10,100,000
Operating lease obligation - long-term	16,827,000	21,100,000
Present value of lease liabilities	$ 26,063,000
Weighted Average Remaining Lease Term in Years	5 years 9 months 18 days
Weighted Average Discount Rate	4.70%
Current operating lease liabilities	$ 9,236,000	10,100,000
Non-current operating lease liabilities	$ 16,827,000	$ 21,100,000

Acquisitions - Acquisitions and

Acquisitions - Acquisitions and Divestitures (Details) $ in Thousands	Aug. 22, 2019USD ($)	Aug. 03, 2018USD ($)	Apr. 19, 2018USD ($)a	Jan. 08, 2018USD ($)a	Mar. 31, 2019USD ($)a	Dec. 31, 2018USD ($)a	Apr. 30, 2018USD ($)a	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)
Acquisitions
Proceeds from divestitures	$ 22,000	$ 83,600			$ 22,400	$ 8,500
Purchase price adjustments					5,900
Proceeds from divestitures, net					$ 16,500
Ownership percentage		10.00%
Acres of real estate sold | a					5,000	31,200	15,100
Sale of property and equipment							$ 72,300		$ 41,982	$ 72,345
Gain (loss) on sale of oil and gas property						$ 6,100		$ 59,300
Acres of real estate purchased | a			1,000	1,200
Total consideration given			$ 9,400	$ 11,600

Long Term Debt - Components (De

Long Term Debt - Components (Details) - USD ($)	Sep. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Aug. 07, 2018
Long-Term Debt
Line of credit, amount outstanding	$ 550,000,000	$ 285,000,000	$ 285,000,000	$ 550,000,000
Unamortized debt issuance costs on Senior Notes	(14,972,000)	(17,341,000)
Total long-term debt	1,635,217,000	1,417,659,000
Less: current portion of long-term debt	0	0
Total long-term debt, net of current portion	1,635,217,000	1,417,659,000
Credit Facility
Long-Term Debt
Line of credit, amount outstanding	550,000,000	285,000,000
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	$ 750,000,000
5% Holdings' Members | Related Party Debt Transaction | Senior Notes due 2026
Long-Term Debt
Debt outstanding	$ 56,200,000

Long Term Debt - Credit Facilit

Long Term Debt - Credit Facility (Details)	9 Months Ended
	Sep. 30, 2019USD ($)factorperiod	Nov. 04, 2019USD ($)	May 31, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Aug. 07, 2018USD ($)
Long-Term Debt
Total commitments	$ 1,500,000,000
Line of Credit Facility, Maximum Borrowing Capacity	1,100,000,000
Borrowing base	1,000,000,000
Line of credit, amount outstanding	550,000,000			$ 285,000,000	$ 285,000,000	$ 550,000,000
Available credit under the facility	$ 450,000,000
Variable interest rate terms and debt covenant ratios
Number of quarters used for calculation of Net Debt to EBITDAX | period	4
Subsequent Event [Member]
Long-Term Debt
Line of Credit Facility, Maximum Borrowing Capacity		$ 950,000,000
Minimum
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.375%
Debt Covenant, Current ratio	1
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
Borrowing Base, Utilization Level 1
Variable interest rate terms and debt covenant ratios
Borrowing base utilization percentage, maximum	25.00%
Borrowing Base, Utilization Level 2
Variable interest rate terms and debt covenant ratios
Borrowing base utilization percentage, minimum	25.00%
Borrowing base utilization percentage, maximum	50.00%
Borrowing Base, Utilization Level 3
Variable interest rate terms and debt covenant ratios
Borrowing base utilization percentage, minimum	50.00%
Borrowing base utilization percentage, maximum	75.00%
Borrowing Base, Utilization Level 4
Variable interest rate terms and debt covenant ratios
Borrowing base utilization percentage, minimum	75.00%
Borrowing base utilization percentage, maximum	90.00%
Borrowing Base, Utilization Level 5
Variable interest rate terms and debt covenant ratios
Borrowing base utilization percentage, maximum	90.00%
Quarter ending March 31, 2018
Variable interest rate terms and debt covenant ratios
Annualized EBITDAX multiplier | factor	1.333
Revolving Credit Facility [Member]
Long-Term Debt
Line of Credit Facility, Covenant, Elected Commitments	$ 900,000,000		$ 650,000,000
Line of Credit Facility, Maximum Borrowing Capacity	1,100,000,000		1,200,000,000
Line of Credit Facility, Covenant, Limitation On Permitted Investments	20,000,000		15,000,000
Standby Letters of Credit
Long-Term Debt
Letters of credit outstanding	49,400,000			35,700,000
Credit Facility
Long-Term Debt
Line of credit, amount outstanding	$ 550,000,000			$ 285,000,000
Credit Facility | Borrowing Base, Utilization Level 1
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.375%
Credit Facility | Borrowing Base, Utilization Level 2
Variable interest rate terms and debt covenant ratios
Commitment fee, percent	0.375%
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%
Elevation
Long-Term Debt
Cash held by Elevation	$ 49,900,000
Letter of Credit [Member] | Revolving Credit Facility [Member]
Long-Term Debt
Letters of credit outstanding	100,000,000		50,000,000
Letter of Credit Sublimit [Member] | Revolving Credit Facility [Member]
Long-Term Debt
Letters of credit outstanding	$ 40,000,000		$ 35,000,000

Long Term Debt - Senior Notes (

Long Term Debt - Senior Notes (Details) - USD ($)	Feb. 17, 2018	Jan. 25, 2018	Jan. 31, 2018	Oct. 31, 2017	Jul. 31, 2016	Sep. 30, 2018	Sep. 30, 2019
Long-Term Debt
Face amount of debt							$ 750,000,000
Senior Notes due 2021
Long-Term Debt
Face amount of debt					$ 550,000,000
Interest rate percentage					7.875%
Proceeds from debt, net of discounts and issuance costs					$ 537,200,000
Repayments of Debt, Principal		$ 500,600,000
Repayments of Debt	$ 52,700,000	534,200,000
Debt Instrument, Make Whole Provision	3,000,000	32,600,000				$ 35,600,000
Interest Expense, Debt	300,000	$ 1,000,000
Debt Instrument, Redemption Amount	$ 49,400,000
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	Feb. 17, 2018	Jan. 25, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jan. 04, 2019
Interest Incurred On Long Term Debt
Interest expense			$ 23.8	$ 21.5	$ 66.9	$ 61.6
Interest costs capitalized			1.6	1.7	5.4	6.3
Note Repurchase Program, Authorized Amount							$ 100
Note Repurchase Program, Amount Outstanding					49.8
Note Repurchase Program, Amount Repurchased					39.3
Note Repurchase Program, Gain (Loss) on Debt Repurchase					10.5
Credit Facility | Other non-current assets
Long-Term Debt
Accumulated amortization, debt issuance costs			3.9		3.9
Debt issuance costs			15		15
Senior Notes due 2021
Long-Term Debt
Amortization of Debt Issuance Costs, Accelerated Amount					9.4
Interest Incurred On Long Term Debt
Debt Instrument, Make Whole Provision	$ 3	$ 32.6				35.6
Second Lien Notes
Long-Term Debt
Amortization of debt discount			$ 1	$ 0.9	$ 3.8	$ 12.3

Commodity Derivative Instrume_3

Commodity Derivative Instruments - Summary of Contracts (Details)	9 Months Ended
	Sep. 30, 2019USD ($)MMBTUcontract$ / MMBTU$ / bblbbl
Commodity derivative contracts
Number of counterparties | contract	9
Derivative instruments in a net liability position with credit-risk-related contingent features | $	$ 0
Crude | Swaps, 2018
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	3,950,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	57.86
Crude | Swap, 2019
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	3,200,001
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	59.81
Crude | Crude Swap 2021 [Member]
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	3,000,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	57.80
Crude | Calls, 2018 | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	200,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	60
Crude | Calls, 2019 | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	9,725,001
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	54.99
Crude | Crude Purchased Puts 2021 [Member] | Sold
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	1,800,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu)	55.02
Crude | Puts, 2018 | Purchased
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	200,000
Weighted average put price (in $/Bbl or $/MMBtu)	64
Crude | Put Option2019 [Member] | Purchased
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	9,725,001
Weighted average put price (in $/Bbl or $/MMBtu)	62.04
Crude | Crude Sold Calls 2021 [Member] | Purchased
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	1,800,000
Weighted average put price (in $/Bbl or $/MMBtu)	63.70
Crude | Crude Swap 2022 [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 2023 [Member]
Summary of commodity derivative contracts
Notional volume (in barrels) | bbl	900,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	54.87
Natural Gas | Swaps, 2018
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	1,000,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	44.60
Natural Gas | Swaps, 2018 | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	9,000,000
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	12,250,002
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	42.91
Natural Gas | Swap, 2019 | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	35,400,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu) | $ / MMBTU	2.75
Natural Gas | Calls, 2018 | Sold
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	0
Weighted average fixed price, Calls (in $/BBl or $/MMBtu) | $ / MMBTU	0
Natural Gas | Calls, 2019 | Sold
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	600,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu) | $ / MMBTU	3.48
Natural Gas | Puts, 2018 | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	0
Weighted average fixed price, Calls (in $/BBl or $/MMBtu) | $ / MMBTU	0
Natural Gas | Crude Sold Puts 2021 [Member]
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	4,200,000
Weighted average fixed price, Swaps (in $/Bbl or$/MMBtu)	43.50
Natural Gas | Put Option2019 [Member] | Purchased
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	600,000
Weighted average fixed price, Calls (in $/BBl or $/MMBtu) | $ / MMBTU	2.90
Natural Gas | Basis Swaps, 2018
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	11,100,000
Weighted average fixed basis price ($/MMBtu) | $ / MMBTU	(0.72)
Natural Gas | Basis Swap, 2019
Summary of commodity derivative contracts
Notional volume (in MMBtu) | MMBTU	43,200,000
Weighted average fixed basis price ($/MMBtu) | $ / MMBTU	(0.61)
Natural Gas | Crude Sold Puts 2023 [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 | 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	Sep. 30, 2019	Mar. 31, 2019
Gross amounts and adjustments made for net derivative liabilities
Derivative Liability, Fair Value, Gross Liability, Deferred Premium Liability	$ 1,700	$ 7,700
Derivative Asset, Fair Value, Gross Asset, Deferred Premium Asset	400	800
Current assets
Gross amounts and adjustments made for net derivative assets
Gross Amounts of Recognized Assets	114,221	115,852
Gross Amounts Offset in the Balance Sheet	(47,741)	(66,945)
Net Amounts of Assets Presented in the Balance Sheet	66,480	48,907
Gross Amounts not Offset in the Balance Sheet	(83)	(192)
Net Amounts	107,917	57,147
Non-current assets
Gross amounts and adjustments made for net derivative assets
Gross Amounts of Recognized Assets	77,188	17,217
Gross Amounts Offset in the Balance Sheet	(35,668)	(8,785)
Net Amounts of Assets Presented in the Balance Sheet	41,520	8,432
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	(47,849)	(67,141)
Gross Amounts Offset in the Balance Sheet	47,741	66,945
Net Amounts of Liabilities Presented in the Balance Sheet	(108)	(196)
Gross Amounts not Offset in the Balance Sheet	83	192
Net Amounts	(108)	(4)
Non-current liabilities
Gross amounts and adjustments made for net derivative liabilities
Gross Amounts of Recognized Liabilities	(35,751)	(8,785)
Gross Amounts Offset in the Balance Sheet	35,668	8,785
Net Amounts of Liabilities Presented in the Balance Sheet	(83)	0
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 ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income (loss) on derivatives
Commodity derivatives gain (loss)	$ 87,956	$ (35,913)	$ 39,383	$ (175,752)
Other income (expense)
Income (loss) on derivatives
Gain (Loss) on Price Risk Derivatives, Net	$ 87,956	$ (35,913)	$ 39,383	$ (175,752)

Asset Retirement Obligations -

Asset Retirement Obligations - Summary (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Asset retirement obligations
Balance beginning of period	$ 69,791
Liabilities incurred or acquired	315
Liabilities settled	(15,484)
Revisions in estimated cash flows	35,466
Accretion expense	3,838
Balance end of period	$ 93,926

Fair Value Measurements - Recur

Fair Value Measurements - Recurring Basis (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Mar. 31, 2017	Sep. 30, 2019	Sep. 30, 2018	Mar. 31, 2019
Fair Value Measurements
Impairment of Oil and Gas Properties	$ 0	$ 16,200		$ 11,200	$ 16,200
Asset transfers out of Level 2 into Level 1	0			0		$ 0
Asset transfers into (out of) Level 3			$ 0	0
Liability transfers out of Level 1 into Level 2	0			0		0
Liability transfers out of Level 2 into Level 1	0			0		0
Liability transfers into (out of) Level 3			$ 0	0
Recurring
Financial Assets:
Commodity derivative assets	108,000			108,000		57,339
Financial Liabilities:
Commodity derivative liabilities	191			191		196
Recurring | Level 1
Financial Assets:
Commodity derivative assets	0			0		0
Financial Liabilities:
Commodity derivative liabilities	0			0		0
Recurring | Level 2
Financial Assets:
Commodity derivative assets	108,000			108,000		57,339
Financial Liabilities:
Commodity derivative liabilities	191			191		196
Recurring | Level 3
Financial Assets:
Commodity derivative assets	0			0		0
Financial Liabilities:
Commodity derivative liabilities	$ 0			$ 0		$ 0

Fair Value Measurements - Finan

Fair Value Measurements - Financial Instruments (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Mar. 31, 2019
Fair Value of Financial Instruments
Unamortized debt discount and debt issuance costs	$ 14,972	$ 17,341
Carrying Amount | Senior Notes due 2024
Fair Value of Financial Instruments
Long-term debt	394,577	393,866
Unamortized debt discount and debt issuance costs	5,400	6,100
Carrying Amount | Senior Notes due 2026
Fair Value of Financial Instruments
Long-term debt	690,640	738,793
Unamortized debt discount and debt issuance costs	9,500	11,200
Fair value | Level 2 | Senior Notes due 2024
Fair Value of Financial Instruments
Long-term debt	262,000	330,000
Fair value | Level 2 | Senior Notes due 2026
Fair Value of Financial Instruments
Long-term debt	428,865	558,750
Line of Credit | Carrying Amount
Fair Value of Financial Instruments
Long-term debt	550,000	285,000
Line of Credit | Fair value | Level 2
Fair Value of Financial Instruments
Long-term debt	$ 550,000	$ 285,000

Fair Value Measurements - Nonre

Fair Value Measurements - Nonrecurring (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Impairment of Oil and Gas Properties	$ 0	$ 16.2	$ 11.2	$ 16.2

Income Taxes - Effective Tax Ra

Income Taxes - Effective Tax Rate (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income Taxes
Effective combined U.S. federal and state income tax rate			156.80%
Income tax expense (in dollars)	$ 20,600	$ 22,200	$ 6,700	$ 12,300
Statutory U.S. federal income tax rate			21.00%

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 ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Compensation costs
Share-based compensation expense	$ 11,358	$ 17,420	$ 39,306	$ 50,883
Stock Options
Number of Shares
Non-vested Stock Options at beginning of period (in shares)			1,748,148
Granted (in shares)			0
Forfeited (in shares)			0
Vested (in shares)			543,977
Non-vested Stock Options at end of period (in shares)	1,204,171		1,204,171
Weighted Average Exercise Price (in dollars per share)
Non-vested Stock Options at beginning of period (in dollars per share)			$ 18.50
Vested (in dollars per share)			18.72
Non-vested Stock Options at end of period (in dollars per share)	$ 18.41		$ 18.41
2016 Long Term Incentive Plan | Stock Options
Assumptions used for the Black-Scholes valuation model
Forfeiture rate (as a percent)			0.00%
Compensation costs
Share-based compensation expense	$ 4,000	$ 3,800	$ 11,500	$ 11,300
Unrecognized compensation costs	$ 700		$ 700
Weighted-average period for recognition, unvested awards			1 month 6 days

Unit and Stock-Based Compensa_5

Unit and Stock-Based Compensation - Long Term Incentive Plan RSUs (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Compensation costs
Share-based compensation expense	$ 11,358	$ 17,420	$ 39,306	$ 50,883
2016 Long Term Incentive Plan | Stock Options
Restricted Stock Units ("RSUs")
Forfeiture rate (as a percent)			0.00%
Compensation costs
Share-based compensation expense	4,000	3,800	$ 11,500	11,300
Weighted-average period for recognition, unvested awards			1 month 6 days
2016 Long Term Incentive Plan | RSUs
Restricted Stock Units ("RSUs")
Forfeiture rate (as a percent)			0.00%
Compensation costs
Share-based compensation expense	6,600	$ 7,100	$ 20,600	$ 20,700
Unrecognized compensation cost	$ 16,500		$ 16,500
Weighted-average period for recognition, unvested awards			1 year 6 months
2016 Long Term Incentive Plan | RSUs - One Year Vesting
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 period, in years			1 year
Vesting percentage			25.00%
2016 Long Term Incentive Plan | Vesting Period Two | RSUs - Three Year Vesting
Restricted Stock Units ("RSUs")
Vesting period, in years			2 years
Vesting percentage			25.00%
2016 Long Term Incentive Plan | Vesting Period Three | RSUs - Three Year Vesting
Restricted Stock Units ("RSUs")
Vesting period, in years			3 years
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	9 Months Ended
	Sep. 30, 2019$ / sharesshares
RSUs
Number of Shares
Non-vested units at beginning of period (in shares) | shares	3,102,335
Granted (in shares) | shares	1,901,418
Forfeited (in shares) | shares	(280,029)
Vested (in shares) | shares	(1,011,340)
Non-vested units at end of period (in shares) | shares	3,712,384
Weighted Average Grant Date Fair Value
Non-vested units at beginning of period (in dollars per share) | $ / shares	$ 16.91
Granted (in dollars per share) | $ / shares	4.76
Forfeited (in dollars per share) | $ / shares	12.91
Vested (in dollars per share) | $ / shares	15.33
Non-vested units at end of period (in dollars per share) | $ / shares	$ 11.42
Performance Stock Awards
Number of Shares
Non-vested units at beginning of period (in shares) | shares	2,794,083
Granted (in shares) | shares	1,646,218
Forfeited (in shares) | shares	0
Vested (in shares) | shares	0
Non-vested units at end of period (in shares) | shares	4,440,301
Weighted Average Grant Date Fair Value
Non-vested units at beginning of period (in dollars per share) | $ / shares	$ 9
Granted (in dollars per share) | $ / shares	5.44
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	$ 7.68

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	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Incentive Units
Share-based compensation expense		$ 11,358	$ 17,420	$ 39,306	$ 50,883
Compensation costs
Unit-based compensation				$ 39,306	50,883
Employee Incentive | Incentive RSUs | Vesting Period One
Incentive Units
Service vesting period, in years				3 years
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 | Incentive RSUs
Compensation costs
Unit-based compensation		0	4,900	$ 800	14,700
Employee Incentive | Incentive RSUs | Vesting Period One
Incentive Units
Vesting period, in years				1 year
Employee Incentive | Incentive RSUs | Vesting Period Two
Incentive Units
Vesting period, in years	6 months			2 years
Employee Incentive | Incentive RSUs | Vesting Period Three
Incentive Units
Vesting period, in years	12 months			3 years
Employee Incentive | Incentive RSUs | Vesting Period Four
Incentive Units
Vesting period, in years	18 months
Officers | Employee Incentive | Employee Incentive | Common Stock
Incentive Units
Shares contributed to Extraction Employee Incentive, LLC				2.7
2016 Long Term Incentive Plan | Stock Options
Incentive Units
Forfeiture rate (as a percent)				0.00%
Share-based compensation expense		4,000	3,800	$ 11,500	11,300
Compensation costs
Weighted-average period for recognition, unvested awards				1 month 6 days
2016 Long Term Incentive Plan | RSUs
Incentive Units
Forfeiture rate (as a percent)				0.00%
Share-based compensation expense		6,600	$ 7,100	$ 20,600	$ 20,700
Compensation costs
Unrecognized compensation cost		$ 16,500		$ 16,500
Weighted-average period for recognition, unvested awards				1 year 6 months

Unit and Stock-Based Compensa_8

Unit and Stock-Based Compensation - Incentive Restricted Stock Units Rollforward (Details) - Incentive RSUs	9 Months Ended
	Sep. 30, 2019$ / sharesshares
Number of Shares
Non-vested units at beginning of period (in shares) | shares	476,000
Granted (in shares) | shares	0
Forfeited (in shares) | shares	0
Vested (in shares) | shares	(476,000)
Non-vested units at end of period (in shares) | shares	0
Weighted Average Grant Date Fair Value
Non-vested units at beginning of period (in dollars per share) | $ / shares	$ 20.45
Granted (in dollars per share) | $ / shares	0
Forfeited (in dollars per share) | $ / shares	0
Vested (in dollars per share) | $ / shares	20.45
Non-vested units at end of period (in dollars per share) | $ / shares	$ 0

Unit and Stock-Based Compensa_9

Unit and Stock-Based Compensation - RUAs (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Compensation costs
Unit-based compensation costs	$ 11,358	$ 17,420	$ 39,306	$ 50,883
2016 Long Term Incentive Plan | Stock Options
Compensation costs
Unit-based compensation costs	$ 4,000	$ 3,800	$ 11,500	$ 11,300

Unit and Stock-Based Compens_10

Unit and Stock-Based Compensation Unit and Stock-Based Compensation - Performance Stock Awards (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation			$ 39,306	$ 50,883
Performance Stock Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation	$ 700	$ 1,600	6,800	$ 4,200
Unrecognized compensation cost	$ 9,300		$ 9,300
Weighted-average period for recognition, unvested awards			1 year 2 months 12 days

Earnings (Loss) Per Share - Com

Earnings (Loss) Per Share - Components (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Basic and Diluted EPS (in thousands, except per share data)
Net loss	$ 48,156	$ 65,150	$ (2,432)	$ 22,003
Net Income (Loss) Attributable to Noncontrolling Interest	(5,776)	(3,305)	(13,849)	(3,305)
Less: Adjustment to reflect Series A Preferred Stock dividends	2,721	2,721	(8,164)	(8,164)
Less: Adjustment to reflect Series A Preferred Stock dividends	1,682	1,515	(4,915)	(4,429)
Adjusted net loss available to common shareholders, basic and diluted	$ 37,977	$ 57,609	$ (29,360)	$ 6,105
Denominator
Weighted average common shares outstanding, basic and diluted	137,789	175,814	155,847	175,269
Earnings Per Common Share
Basic and diluted (in dollars per share)	$ 0.28	$ 0.33	$ (0.19)	$ 0.03

Earnings (Loss) Per Share - Exc

Earnings (Loss) Per Share - Excluded and Antidilutive Securities (Details) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2018
Antidilutive Securities Excluded from Computation of Earnings Per Share
Securities excluded from diluted EPS calculation (in shares)	8,956,812	347,343	537,706
Out-of-the-money stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share
Securities excluded from diluted EPS calculation (in shares)		5,244,428	4,500,000
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	11,472,445

Commitments and Contingencies -

Commitments and Contingencies - Leases (Details) - USD ($)	9 Months Ended
	Sep. 30, 2019	Mar. 31, 2019
Future minimum lease payments
2017		$ 12,713
2018		3,371
2019		3,385
2020		3,360
2021		3,411
Thereafter		15,719
Total rental commitments under non cancelable leases		$ 41,959
Long Term Crude Oil Delivery Commitment November2016 Ten Year Term [Member] | Affiliated Entity [Member]
Operating Leased Assets [Line Items]
Long-term Delivery Commitment, Period	10 years

Commitments and Contingencies_2

Commitments and Contingencies - Drilling Rigs (Details) - Drilling Rig Commitments $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)well
Drilling Rigs
Number of drilling rigs | well	1
Early termination obligation | $	$ 11.7

Commitments and Contingencies_3

Commitments and Contingencies - Commitments (Details) MBoe in Thousands, MBbls in Thousands, $ in Millions	Jul. 07, 2017MMcf	Dec. 15, 2016MMcfBcf	Sep. 30, 2019USD ($)MBoebbl / dMBblsMMcf	Jul. 31, 2019USD ($)	Apr. 30, 2019USD ($)	Aug. 07, 2017processing_plant
Delivery and Gathering commitments
Aggregate estimated payments due | $			$ 437.8	$ 34.5
Gathering Commitment, Long Term Crude Oil, Remaining Fiscal Year | MBbls			2,024
Gathering Commitment, Long Term Crude Oil, Gas, Remaining Fiscal Year			5,185,000
Gathering Commitment, Total Commitments, Remaining Fiscal Year | MBoe			2,888
Gathering Commitment, Long Term Crude Oil, Year Two | MBbls			8,935
Gathering Commitment, Long Term Crude Oil, Gas, Year Two			33,550,000
Gathering Commitment, Total Commitments, Year Two | MBoe			14,527
Gathering Commitment, Long Term Crude Oil, Year Three | MBbls			10,349
Gathering Commitment, Long Term Crude Oil, Gas, Year Three			46,540,000
Gathering Commitment, Total Commitments, Year Three | MBoe			18,106
Gathering Commitment, Long Term Crude Oil, Year Four | MBbls			9,128
Gathering Commitment, Long Term Crude Oil, Gas, Year Four			49,758,000
Gathering Commitment, Total Commitments, Year Four | MBoe			17,421
Gathering Commitment, Long Term Crude Oil, Year Five | MBbls			9,490
Gathering Commitment, Long Term Crude Oil, Gas, Year Five			41,850,000
Gathering Commitment, Total Commitments, Year Five | MBoe			16,465
Gathering Commitment, Long Term Crude Oil, Thereafter | MBbls			38,824
Gathering Commitment, Long Term Crude Oil, Gas, Thereafter			74,420,000
Gathering Commitment, Total Commitments, Thereafter | MBoe			51,227
Gathering Commitment, Long Term Crude Oil | MBbls			78,750
Gathering Commitment, Long Term Crude Oil, Gas			251,303,000
Gathering Commitment, Total Commitments | MBoe			120,634
Long Term Crude Oil Delivery Commitment, November 2016, Ten Year Term
Delivery and Gathering commitments
Letters of credit outstanding | $					$ 40
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 | bbl / d			45,000
Delivery commitment, in barrels per day (Bpd), year two | bbl / d			55,800
Delivery commitment, in barrels per day (Bpd), years three through seven | bbl / d			61,800
Delivery commitment, in barrels per day (Bpd), years eight through ten | bbl / d			58,000
Natural Gas Gathering and Processing Expansion Commitment
Delivery and Gathering commitments
Term of commitment			7 years
Processing Plant, Number | processing_plant						2
Delivery commitment, daily	20.6	51.5
Target profit margin period, in years			3 years
Annual minimum volume (in bcf) | Bcf		13
Affiliated Entity [Member] | Long Term Crude Oil Delivery Commitment, November 2016, Ten Year Term
Delivery and Gathering commitments
Term of commitment			10 years

Commitments and Contingencies_4

Commitments and Contingencies - Acquisition of Undeveloped Leasehold (Details) - Natural Gas Gathering And Processing Expansion Commitment [Member]	9 Months Ended
	Sep. 30, 2019
Acquisition of Undeveloped Leasehold Acreage Commitments
Long-term Delivery Commitment, Period	7 years
Delivery Commitment, Target Profit Margin Period	3 years

Commitments and Contingencies_5

Commitments and Contingencies - Future Minimum Lease Payments (Details)	Sep. 30, 2019USD ($)
Loss Contingencies [Line Items]
2019-remaining	$ 2,956,000
2020	8,675,000
2021	3,340,000
2022	2,211,000
2023	2,246,000
Thereafter	10,573,000
Total lease payments	30,001,000
Less imputed interest	(3,938,000)
Present value of lease liabilities	26,063,000
Accounts Payable and Accrued Liabilities [Member]
Loss Contingencies [Line Items]
Present value of lease liabilities	9,700,000
Other Liabilities [Member]
Loss Contingencies [Line Items]
Present value of lease liabilities	$ 17,200,000

Related Party Transactions - Du

Related Party Transactions - Due From Related Parties (Details)	1 Months Ended
	Apr. 30, 2016USD ($)
Board member | Star Peak Capital Office Lease
Office Lease with Related Affiliate
Monthly rent	$ 1,400

Related Party Transactions - _2

Related Party Transactions - Due to Related Parties (Details) - USD ($)	Sep. 30, 2019	Mar. 31, 2019	Jan. 31, 2018
Due to Related Party
Face amount of debt	$ 750,000,000
Senior Notes due 2026
Due to Related Party
Face amount of debt			$ 750,000,000
Debt outstanding	700,189,000	$ 750,000,000
Senior Notes due 2026 | Related Party Debt Transaction | 5% Holdings' Members
Due to Related Party
Debt outstanding	$ 56,200,000

Segment Information (Details)

Segment Information (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)segment	Sep. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Segment Reporting Information [Line Items]
Number of Operating Segments | segment			2
Revenues	$ 196,974	$ 282,160	$ 640,948	$ 772,571
Interest Income, Other	469	770	1,658	915
Interest Expense	(23,224)	(20,725)	(54,791)	(103,229)
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	640	843	1,179	1,567
Operating Expense and Other Income (Expense)	(137,111)	(126,427)	(404,088)	(411,043)
Assets	4,429,158	4,158,325	4,429,158	4,158,325	$ 4,166,027
Payments to Acquire Property, Plant, and Equipment	200,096	240,359	709,078	788,102
Equity Method Investments	35,992	14,510	35,992	14,510
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	157,901	169,403	425,403	463,517
Depreciation, Depletion and Amortization	(114,996)	(107,315)	(352,134)	(310,296)
Impairment of Long-Lived Assets Held-for-use	0	(16,166)	(11,233)	(16,294)
Exploration Expense	(13,245)	(11,038)	(32,725)	(21,326)
Gain on sale of property and equipment and assets of unconsolidated subsidiary	1,011	83,559	1,329	143,461
Commodity derivatives gain (loss)	87,956	(35,913)	39,383	(175,752)
Unrealized Gain (Loss) on Derivatives and Commodity Contracts	(16,101)	41,009	8,432	99,914
Premiums Paid For Settlement of Derivatives	812	1,956	19,910	5,191
Share-based compensation expense	11,358	17,420	39,306	50,883
Amortization of Debt Issuance Costs	(974)	(935)	(3,799)	(12,303)
Payments for Make-Whole Premium On Long Term Debt	0	0	0	(35,600)
Gain (Loss) on Repurchase of Debt Instrument	0	0	10,486	0
Interest Revenue (Expense), Net	(22,250)	(19,790)	(61,478)	(55,326)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	68,756	87,350	4,268	34,303
Exploration and Production [Member]
Segment Reporting Information [Line Items]
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	158,523	170,004	426,571	463,415
Gathering and Facilities [Member]
Segment Reporting Information [Line Items]
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	(622)	(601)	(1,168)	102
Operating Segments [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Revenues	196,974	282,160	640,948	772,571
Interest Income, Other	114	135	372	280
Interest Expense	(23,224)	(20,725)	(54,791)	(103,229)
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	0	0	0	0
Operating Expense and Other Income (Expense)	(138,081)	(127,905)	(406,481)	(413,245)
Assets	4,015,499	3,894,535	4,015,499	3,894,535
Payments to Acquire Property, Plant, and Equipment	134,998	202,811	516,510	730,878
Equity Method Investments	0	0	0	0
Depreciation, Depletion and Amortization	114,971	107,315	352,062	310,296
Operating Segments [Member] | Gathering and Facilities [Member]
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Interest Income, Other	355	635	1,286	635
Interest Expense	0	0	0	0
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	640	843	1,179	1,567
Operating Expense and Other Income (Expense)	970	1,478	2,393	2,202
Assets	395,224	264,014	395,224	264,014
Payments to Acquire Property, Plant, and Equipment	65,098	37,548	192,568	57,224
Equity Method Investments	35,992	14,510	35,992	14,510
Depreciation, Depletion and Amortization	25	0	72	0
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Interest Income, Other	0	0	0	0
Interest Expense	0	0	0	0
Income (Loss) From Unconsolidated Subsidiaries, Before Tax	0	0	0	0
Operating Expense and Other Income (Expense)	0	0	0	0
Assets	18,435	(224)	18,435	(224)
Payments to Acquire Property, Plant, and Equipment	0	0	0	0
Equity Method Investments	0	0	0	0
Net Income (Loss) Before Interest, Taxes, Depreciation, Amortization and Exploration Expense	0	0	0	0
Depreciation, Depletion and Amortization	0	0	0	0
Intersegment Eliminations [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Intersegment Eliminations [Member] | Gathering and Facilities [Member]
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 0	$ 0	$ 0

Uncategorized Items - xog-20190

Label	Element	Value
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	$ 6,768,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	$ 234,986,000