Vital Energy (VTLE) 10-Q 5 Aug 21 2021 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2021	Aug. 03, 2021
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2021
Document Transition Report	false
Entity File Number	001-35380
Entity Registrant Name	Laredo Petroleum, Inc.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	45-3007926
Entity Address, Address Line One	15 W. Sixth Street
Entity Address, Address Line Two	Suite 900
Entity Address, City or Town	Tulsa
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74119
City Area Code	918
Local Phone Number	513-4570
Title of 12(b) Security	Common stock, $0.01 par value per share
Trading Symbol	LPI
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		16,071,349
Entity Central Index Key	0001528129
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q2

Consolidated balance sheets

Consolidated balance sheets - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 193,543	$ 48,757
Accounts receivable, net	90,609	63,976
Derivatives	0	7,893
Other current assets	18,665	15,964
Total current assets	302,817	136,590
Oil and natural gas properties, full cost method:
Evaluated properties	8,053,975	7,874,932
Unevaluated properties not being depleted	62,248	70,020
Less accumulated depletion and impairment	(6,889,399)	(6,817,949)
Oil and natural gas properties, net	1,226,824	1,127,003
Midstream service assets, net	109,681	112,697
Other fixed assets, net	31,548	32,011
Property and equipment, net	1,368,053	1,271,711
Derivatives	423	0
Operating lease right-of-use assets	19,231	17,973
Other noncurrent assets, net	96,282	16,336
Total assets	1,786,806	1,442,610
Current liabilities:
Accounts payable and accrued liabilities	49,783	38,279
Accrued capital expenditures	32,641	28,275
Undistributed revenue and royalties	46,285	24,728
Derivatives	256,460	31,826
Operating lease liabilities	15,143	11,721
Other current liabilities	89,363	62,766
Total current liabilities	489,675	197,595
Long-term debt, net	1,306,112	1,179,266
Derivatives	61,514	12,051
Asset retirement obligations	67,587	64,775
Operating lease liabilities	6,573	8,918
Other noncurrent liabilities	9,627	1,448
Total liabilities	1,941,088	1,464,053
Commitments and contingencies
Stockholders' equity:
Preferred stock, $0.01 par value, 50,000,000 shares authorized and zero issued as of June 30, 2021 and December 31, 2020	0	0
Common stock, $0.01 par value, 22,500,000 shares authorized and 13,572,872 and 12,020,164 issued and outstanding as of June 30, 2021 and December 31, 2020, respectively	136	120
Additional paid-in capital	2,473,709	2,398,464
Accumulated deficit	(2,628,127)	(2,420,027)
Total stockholders' equity	(154,282)	(21,443)
Total liabilities and stockholders' equity	$ 1,786,806	$ 1,442,610

Consolidated balance sheets (Pa

Consolidated balance sheets (Parenthetical) - $ / shares	Jun. 30, 2021	Dec. 31, 2020
Statement of Financial Position [Abstract]
Preferred stock par value (in USD per share)	$ 0.01	$ 0.01
Preferred stock authorized (in shares)	50,000,000	50,000,000
Preferred stock issued (in shares)	0	0
Common stock par value (in USD per share)	$ 0.01	$ 0.01
Common stock authorized (in shares)	22,500,000	22,500,000
Common stock issued (in shares)	13,572,872	12,020,164
Common stock outstanding (in shares)	13,572,872	12,020,164

Consolidated statements of oper

Consolidated statements of operations - USD ($) shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Revenues:
Total revenues	$ 294,371,000	$ 110,588,000	$ 544,601,000	$ 315,580,000
Costs and expenses:
Lease operating expenses	19,771,000	20,591,000	38,689,000	42,631,000
Production and ad valorem taxes	14,737,000	6,938,000	28,020,000	16,182,000
General and administrative	21,101,000	10,659,000	34,174,000	23,221,000
Organizational restructuring expenses	9,800,000	4,200,000	9,800,000	4,200,000
Transaction expenses	1,741,000	0	1,741,000	0
Depletion, depreciation and amortization	39,976,000	66,574,000	78,085,000	127,876,000
Impairment expense	1,613,000	406,448,000	1,613,000	593,147,000
Other operating expenses	1,158,000	1,117,000	2,301,000	2,223,000
Total costs and expenses	186,024,000	544,640,000	333,451,000	931,604,000
Operating income (loss)	108,347,000	(434,052,000)	211,150,000	(616,024,000)
Non-operating income (expense):
Gain (loss) on derivatives, net	(216,942,000)	(90,537,000)	(371,307,000)	207,299,000
Interest expense	(25,870,000)	(27,072,000)	(51,816,000)	(52,042,000)
Loss on extinguishment of debt	0	0	0	(13,320,000)
Gain (loss) on disposal of assets, net	66,000	152,000	(6,000)	(450,000)
Write-off of debt issuance costs	0	(1,103,000)	0	(1,103,000)
Other income (expense), net	416,000	(16,000)	1,795,000	75,000
Total non-operating income (expense), net	(242,330,000)	(118,576,000)	(421,334,000)	140,459,000
Loss before income taxes	(133,983,000)	(552,628,000)	(210,184,000)	(475,565,000)
Income tax benefit:
Deferred	1,322,000	7,173,000	2,084,000	4,756,000
Total income tax benefit	1,322,000	7,173,000	2,084,000	4,756,000
Net loss	$ (132,661,000)	$ (545,455,000)	$ (208,100,000)	$ (470,809,000)
Net loss per common share:
Basic (in USD per share)	$ (10.47)	$ (46.75)	$ (16.92)	$ (40.44)
Diluted (in USD per share)	$ (10.47)	$ (46.75)	$ (16.92)	$ (40.44)
Weighted-average common shares outstanding:
Basic (in shares)	12,674	11,667	12,298	11,642
Diluted (in shares)	12,674	11,667	12,298	11,642
Oil sales
Revenues:
Total revenues	$ 157,722,000	$ 70,105,000	$ 285,423,000	$ 190,083,000
NGL sales
Revenues:
Total revenues	43,494,000	13,228,000	85,172,000	24,786,000
Natural gas sales
Revenues:
Total revenues	31,110,000	10,810,000	64,188,000	15,159,000
Midstream service revenues
Revenues:
Total revenues	1,257,000	2,281,000	2,553,000	4,964,000
Costs and expenses:
Cost of goods and services sold	700,000	815,000	1,558,000	1,985,000
Sales of purchased oil
Revenues:
Total revenues	60,788,000	14,164,000	107,265,000	80,588,000
Costs and expenses:
Cost of goods and services sold	64,737,000	16,117,000	114,653,000	95,414,000
Transportation and marketing expenses
Costs and expenses:
Cost of goods and services sold	$ 10,690,000	$ 11,181,000	$ 22,817,000	$ 24,725,000

Consolidated statement of stock

Consolidated statement of stockholders' equity - USD ($) shares in Thousands, $ in Thousands	Total	Common stock	Additional paid-in capital	Treasury stock (at cost)	Accumulated deficit
Balance at beginning of period (in shares) at Dec. 31, 2019		11,865		0
Balance at beginning of period at Dec. 31, 2019	$ 841,874	$ 2,373	$ 2,385,355	$ 0	$ (1,545,854)
Increase (Decrease) in Stockholders' Equity
Reverse stock split	0	$ (2,277)	2,277
Restricted stock awards (in shares)		152
Restricted stock awards	0	$ 30	(30)
Restricted stock forfeitures (in shares)		(44)
Restricted stock forfeitures	0	$ (2)	$ 2
Stock exchanged for tax withholding (in shares)			34
Stock exchanged for tax withholding	(762)			(762)
Retirement of treasury stock (in shares)		(34)	(34)
Retirement of treasury stock	0	$ (5)	$ (757)	$ 762
Share-settled equity-based compensation	5,717		5,717
Net loss	(470,809)				(470,809)
Balance at end of period (in shares) at Jun. 30, 2020		11,939		0
Balance at end of period at Jun. 30, 2020	376,020	$ 119	2,392,564	$ 0	(2,016,663)
Balance at beginning of period (in shares) at Mar. 31, 2020		11,970		0
Balance at beginning of period at Mar. 31, 2020	919,221	$ 2,394	2,388,035	$ 0	(1,471,208)
Increase (Decrease) in Stockholders' Equity
Reverse stock split	0	$ (2,277)	2,277
Restricted stock awards (in shares)		13
Restricted stock awards	0	$ 2	(2)
Restricted stock forfeitures (in shares)		(37)
Stock exchanged for tax withholding (in shares)				7
Stock exchanged for tax withholding	(122)			$ (122)
Retirement of treasury stock (in shares)		(7)		(7)
Retirement of treasury stock	0		(122)	$ 122
Share-settled equity-based compensation	2,376		2,376
Net loss	(545,455)				(545,455)
Balance at end of period (in shares) at Jun. 30, 2020		11,939		0
Balance at end of period at Jun. 30, 2020	376,020	$ 119	2,392,564	$ 0	(2,016,663)
Balance at beginning of period (in shares) at Dec. 31, 2020		12,020		0
Balance at beginning of period at Dec. 31, 2020	(21,443)	$ 120	2,398,464	$ 0	(2,420,027)
Increase (Decrease) in Stockholders' Equity
Restricted stock awards (in shares)		194
Restricted stock awards	0	$ 2	(2)
Restricted stock forfeitures (in shares)		(41)
Stock exchanged for tax withholding (in shares)				44
Stock exchanged for tax withholding	(1,741)			$ (1,741)
Retirement of treasury stock (in shares)		(44)		(44)
Retirement of treasury stock	0		(1,741)	$ 1,741
Share-settled equity-based compensation	4,510		4,510
Issuance of common stock, net of costs (in shares)		1,438
Issuance of common stock, net of costs	72,492	$ 14	72,478
Performance share conversion (in shares)		6
Net loss	(208,100)				(208,100)
Balance at end of period (in shares) at Jun. 30, 2021		13,573		0
Balance at end of period at Jun. 30, 2021	(154,282)	$ 136	2,473,709	$ 0	(2,628,127)
Balance at beginning of period (in shares) at Mar. 31, 2021		12,900		0
Balance at beginning of period at Mar. 31, 2021	(68,568)	$ 129	2,426,769	$ 0	(2,495,466)
Increase (Decrease) in Stockholders' Equity
Restricted stock awards (in shares)		6
Restricted stock forfeitures (in shares)		(40)
Stock exchanged for tax withholding (in shares)				7
Stock exchanged for tax withholding	(451)			$ (451)
Retirement of treasury stock (in shares)		(7)		(7)
Retirement of treasury stock	0		(451)	$ 451
Share-settled equity-based compensation	1,772		1,772
Issuance of common stock, net of costs (in shares)		714
Issuance of common stock, net of costs	45,626	$ 7	45,619
Net loss	(132,661)				(132,661)
Balance at end of period (in shares) at Jun. 30, 2021		13,573		0
Balance at end of period at Jun. 30, 2021	$ (154,282)	$ 136	$ 2,473,709	$ 0	$ (2,628,127)

Consolidated statements of cash

Consolidated statements of cash flows - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2021	Jun. 30, 2020
Cash flows from operating activities:
Net loss		$ (208,100)	$ (470,809)
Adjustments to reconcile net loss to net cash provided by operating activities:
Share-settled equity-based compensation, net		3,798	4,070
Depletion, depreciation and amortization		78,085	127,876
Impairment expense		1,613	593,147
Mark-to-market on derivatives:
(Gain) loss on derivatives, net		371,307	(207,299)
Settlements (paid) received for matured derivatives, net		(98,781)	134,595
Premiums received (paid) for commodity derivatives		9,041	(51,070)
Amortization of debt issuance costs		2,099	2,274
Amortization of operating lease right-of-use assets		5,764	7,242
Loss on extinguishment of debt		0	13,320
Deferred income tax benefit		(2,084)	(4,756)
Other, net		2,497	3,341
Changes in operating assets and liabilities:
Accounts receivable, net		(26,633)	16,110
Other current assets		(4,412)	2,584
Other noncurrent assets, net		(12,649)	(3,130)
Accounts payable and accrued liabilities		9,784	6,912
Undistributed revenue and royalties		21,557	(10,526)
Other current liabilities		29,952	12,378
Other noncurrent liabilities		4,859	(4,697)
Net cash provided by operating activities		187,697	171,562
Cash flows from investing activities:
Acquisitions of oil and natural gas properties, net		0	(23,563)
Capital expenditures:
Oil and natural gas properties		(166,077)	(241,939)
Midstream service assets		(1,561)	(1,761)
Other fixed assets		(1,236)	(2,069)
Proceeds from dispositions of capital assets, net of selling costs		307	728
Net cash used in investing activities		(168,567)	(268,604)
Cash flows from financing activities:
Borrowings on Senior Secured Credit Facility		245,000	0
Payments on Senior Secured Credit Facility		(120,000)	(100,000)
Issuance of January 2025 Notes and January 2028 Notes		0	1,000,000
Extinguishment of debt		0	(808,855)
Proceeds from issuance of common stock, net of costs		72,492	0
Stock exchanged for tax withholding		(1,741)	(762)
Payments for debt issuance costs		(1,452)	(18,451)
Other liabilities		2,798	0
Net cash provided by financing activities		197,097	71,932
Net increase (decrease) in cash, cash equivalents and restricted cash		216,227	(25,110)
Cash, cash equivalents and restricted cash, beginning of period		48,757	40,857
Cash, cash equivalents and restricted cash, end of period	[1]	$ 264,984	$ 15,747
[1]	See Note 1 for further discussion of the Company's cash, cash equivalents and restricted cash.

Organization and basis of prese

Organization and basis of presentation	6 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Organization and basis of presentation	Organization and basis of presentation a. Organization Laredo Petroleum, Inc. ("Laredo"), together with its wholly-owned subsidiaries, Laredo Midstream Services, LLC ("LMS") and Garden City Minerals, LLC ("GCM"), is an independent energy company focused on the acquisition, exploration and development of oil and natural gas properties, primarily in the Permian Basin of West Texas. The Company has identified one operating segment: exploration and production. In these notes, the "Company" refers to Laredo, LMS and GCM collectively, unless the context indicates otherwise. All amounts, dollars and percentages presented in these unaudited consolidated financial statements and the related notes are rounded and, therefore, approximate. b. Basis of presentation The unaudited consolidated financial statements were derived from the historical accounting records of the Company and reflect the historical financial position, results of operations and cash flows for the periods described herein. The unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All material intercompany transactions and account balances have been eliminated in the consolidation of accounts. The unaudited consolidated financial statements have not been audited by the Company's independent registered public accounting firm, except that the consolidated balance sheet as of December 31, 2020 is derived from the Company's audited consolidated financial statements. In the opinion of management, the unaudited consolidated financial statements reflect all necessary adjustments to present fairly the Company's financial position as of June 30, 2021, results of operations for the three and six months ended June 30, 2021 and 2020 and cash flows for the six months ended June 30, 2021 and 2020. Certain disclosures have been condensed or omitted from the unaudited consolidated financial statements. Accordingly, the unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the 2020 Annual Report. Significant accounting policies See Note 2 in the 2020 Annual Report for discussion of significant accounting policies. The following table presents the Company's cash, cash equivalents and restricted cash as of the dates presented: As of June 30, (in thousands) 2021 2020 Cash and cash equivalents $ 193,543 $ 15,747 Restricted cash (1) 71,441 — Total cash, cash equivalents and restricted cash $ 264,984 $ 15,747 _____________________________________________________________________________ (1) Under the terms of the Sabalo/Shad PSAs (defined below), the Company deposited into third-party escrow accounts an amount equal to $71.4 million, which is included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets as of June 30, 2021. Use of estimates in the preparation of interim unaudited consolidated financial statements The preparation of the unaudited consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Although management believes these estimates are reasonable, actual results could differ. See Note 2.b in the 2020 Annual Report for further information regarding the use of estimates and assumptions.

New accounting standards

New accounting standards	6 Months Ended
	Jun. 30, 2021
Accounting Standards Update and Change in Accounting Principle [Abstract]
New accounting standards	New accounting standards The Company considered the applicability and impact of all accounting standard updates ("ASU") issued by the Financial Accounting Standards Board to the Accounting Standards Codification ("ASC") and has determined there are no ASUs that are not yet adopted and meaningful to disclose as of June 30, 2021.

Acquisitions and divestitures

Acquisitions and divestitures	6 Months Ended
	Jun. 30, 2021
Business Combination and Asset Acquisition [Abstract]
Acquisitions and divestitures	Acquisitions and divestitures a. 2021 Acquisition and divestiture Sabalo/Shad Acquisition On May 7, 2021, the Company entered into two separate purchase and sale agreements, one (the "Sabalo PSA") with Sabalo Energy, LLC and its subsidiary, Sabalo Operating, LLC (collectively, "Sabalo"), and the other (the "Shad PSA" and, together with the Sabalo PSA, the "Sabalo/Shad PSAs") with Shad Permian, LLC ("Shad"), which is unaffiliated with Sabalo but owns interests in the same assets, pursuant to which the Company agreed to purchase (the "Sabalo/Shad Acquisition"), effective as of April 1, 2021, certain oil and gas properties in the Midland Basin, located in the Howard and Borden Counties, Texas, and related assets and contracts for an aggregate purchase price of $864.3 million, comprising $624.3 million of cash and 2,506,964 shares of the Company's common stock, par value $0.01 per share (the "Shares"), based upon the closing price of the Company's common stock on July 1, 2021. Under the terms of the Sabalo/Shad PSAs, the Company deposited into third-party escrow accounts an amount equal to $71.4 million, which is included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets as of June 30, 2021. The Company funded the acquisition price and related transaction costs with respect to the Sabalo/Shad Acquisition with proceeds from a sale of working interests in certain of its oil and gas properties in connection with the Working Interest Sale (defined below), as more fully described below, and borrowings under its Senior Secured Credit Facility (defined below). The Sabalo/Shad Acquisition will be accounted for as a single transaction because the Sabalo PSA and Shad PSA were entered into at the same time and in contemplation of one another and form a single transaction designed to achieve an overall economic effect. The Sabalo/Shad Acquisition will be accounted for as an asset acquisition as substantially all of the gross assets acquired are concentrated in a group of similar identifiable assets. The consideration paid will be allocated to the individual assets acquired and liabilities assumed based on their relative fair values. All transaction costs associated with the Sabalo/Shad Acquisition will be capitalized. As of June 30, 2021, the Company has recorded $3.9 million in transaction costs associated with the Sabalo/Shad Acquisition, which are included in "Other noncurrent assets, net" on the unaudited consolidated balance sheet. The Company expects to finalize its allocation of the purchase consideration as soon as practicable after completion of the Sabalo/Shad Acquisition. For income tax purposes, the Sabalo/Shad Acquisition will be treated as an asset purchase such that the tax basis in the assets and liabilities will generally reflect the allocated fair value at closing. Therefore, the Company does not anticipate a material tax consequence for deferred income taxes related to the Sabalo/Shad Acquisition. Sale of Working Interest On May 7, 2021, the Company entered into a purchase and sale agreement (the "Sixth Street PSA") with Piper Investments Holdings, LLC, an affiliate of Sixth Street Partners, LLC ("Sixth Street"), pursuant to which the Company agreed to sell to Sixth Street a portion of the Company's working interests in certain specified oil and gas properties (the "Working Interest Sale" and, together with the Sabalo/Shad Acquisition, the "Transactions"), for an aggregate purchase price of $405.0 million in cash at closing and potential cash flow-based earn-out payments after closing, subject to certain customary adjustments. The interests conveyed include such undivided interest in and to the scheduled oil and gas leases as may be necessary to entitle the purchaser to the scheduled working interest and net revenue interest amounts, and the undivided percentage ownership in and to the scheduled producing wellbores, comprising approximately 37.5% of the Company's interest in such producing wellbores, the properties being primarily located within the Glasscock and Reagan Counties, Texas, subject to certain excluded assets and title diligence procedures. Effective at closing, the operations and cash flows of the 37.5% working interest in certain oil and natural gas properties included in the Working Interest Sale will be eliminated from the ongoing operations of the Company. The Company will continue to own a partial working interest in the properties and will operate the properties. The Company expects to record a gain on the Working Interest Sale, net of transaction costs, pursuant to full cost accounting rules as the Working Interest Sale represents more than 25% of the Company’s pre-acquisition reserves. For the purposes of calculating the gain, total capitalized costs will be allocated between reserves sold and reserves retained. During the three months ended June 30, 2021, the Company recognized $1.7 million in transaction costs associated with the Working Interest Sale, which are included in "Transaction expenses" on the unaudited consolidated statement of operations. The Sixth Street PSA provides the Company with the right to receive up to a maximum of $93.7 million in additional cash contingent consideration for the Working Interest Sale if certain cash flow targets related to divested oil and natural gas property operations are met. The contingent consideration is made up of quarterly payments through June 2027 totaling up to $38.7 million and a potential balloon payment of $55.0 million in June 2027. The Company has concluded that the contingent consideration should be accounted for as a derivative instrument, with all gains and losses as a result of changes in the fair value of the contingent consideration derivative recognized in earnings in the period in which the changes occur. See Note 19.b for discussion of the July 1, 2021 closing of the Transactions. b. 2020 Asset acquisitions On October 16, 2020 and November 16, 2020, the Company closed a bolt-on acquisition of 2,758 and 80 net acres, respectively, including production of 210 BOE per day, in Howard County, Texas for an aggregate purchase price of $11.6 million, subject to customary post-closing purchase price adjustments. On April 30, 2020, the Company closed an acquisition of 180 net acres in Howard County, Texas for $0.6 million. The acquisition also provides for one or more potential contingent payments to be paid by the Company if the arithmetic average of the monthly settlement West Texas Intermediate ("WTI") NYMEX prices exceed certain thresholds for the contingency period beginning on January 1, 2021 and ending on the earlier of December 31, 2022 or the date the counterparty has received the maximum consideration of $1.2 million. The fair value of this contingent consideration was $0.2 million as of the acquisition date, which was recorded as part of the basis in the oil and natural gas properties acquired and as a contingent consideration derivative liability. See Notes 9.c and 10.a for additional discussion of this contingent consideration. On February 4, 2020, the Company closed a transaction for $22.5 million acquiring 1,180 net acres and divesting 80 net acres in Howard County, Texas. All transaction costs were capitalized and are included in "Oil and natural gas properties" on the consolidated balance sheet. c. 2020 Divestiture On April 9, 2020, the Company closed a divestiture of 80 net acres and working interests in two producing wells in Glasscock County, Texas for $0.7 million, net of customary post-closing sales price adjustments. The divestiture was recorded as an adjustment to oil and natural gas properties pursuant to the rules governing full cost accounting. Effective at closing, the operations and cash flows of these oil and natural gas properties were eliminated from the ongoing operations of the Company, and the Company has no continuing involvement in the properties. This divestiture did not represent a strategic shift and has not had a major effect on the Company's future operations or financial results. d. Exchange of unevaluated oil and natural gas properties From time to time, the Company exchanges undeveloped acreage with third parties. The exchanges are recorded at fair value and the difference is accounted for as an adjustment of capitalized costs with no gain or loss recognized pursuant to the rules governing full cost accounting, unless such adjustment would significantly alter the relationship between capitalized costs and proved reserves of oil, NGL and natural gas.

Leases

Leases	6 Months Ended
	Jun. 30, 2021
Leases [Abstract]
Leases	LeasesThe Company has recognized operating lease right-of-use assets and operating lease liabilities on the unaudited consolidated balance sheets for leases of commercial real estate with lease terms extending into 2027 and drilling, completion, production and other equipment leases with lease terms extending into 2022. The Company's lease costs include those that are recognized in net income or loss during the period and capitalized as part of the cost of another asset in accordance with GAAP.The lease costs related to drilling, completion and production activities are reflected at the Company's net ownership, which is consistent with the principles of proportional consolidation, and lease commitments are reflected on a gross basis. As of June 30, 2021, the Company had an average working interest of 97% in Laredo-operated active productive wells. See Note 5 in the 2020 Annual Report for additional discussion of the Company's leases.

Property and equipment

Property and equipment	6 Months Ended
	Jun. 30, 2021
Property, Plant and Equipment [Abstract]
Property and equipment	Property and equipment The following table presents the Company's property and equipment as of the dates presented: (in thousands) June 30, 2021 December 31, 2020 Evaluated oil and natural gas properties $ 8,053,975 $ 7,874,932 Less accumulated depletion and impairment (6,889,399) (6,817,949) Evaluated oil and natural gas properties, net 1,164,576 1,056,983 Unevaluated oil and natural gas properties not being depleted 62,248 70,020 Midstream service assets 183,079 181,718 Less accumulated depreciation and impairment (73,398) (69,021) Midstream service assets, net 109,681 112,697 Depreciable other fixed assets 38,210 37,454 Less accumulated depreciation and amortization (25,563) (24,344) Depreciable other fixed assets, net 12,647 13,110 Land 18,901 18,901 Total property and equipment, net $ 1,368,053 $ 1,271,711 See Note 10.b for discussion of impairments of inventory during the six months ended June 30, 2021. See Note 6 in the 2020 Annual Report for additional discussion of the Company's property and equipment. The Company uses the full cost method of accounting for its oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain employee-related costs, incurred for the purpose of acquiring, exploring for or developing oil and natural gas properties, are capitalized and, once evaluated, depleted on a composite unit-of-production method based on estimates of proved oil, NGL and natural gas reserves. The depletion base includes estimated future development costs and dismantlement, restoration and abandonment costs, net of estimated salvage values. Capitalized costs include the cost of drilling and equipping productive wells, dry hole costs, lease acquisition costs, delay rentals and other costs related to such activities. Costs, including employee-related costs, associated with production and general corporate activities are expensed in the period incurred. The Company excludes unevaluated property acquisition costs and exploration costs from the depletion calculation until it is determined whether or not proved reserves can be assigned to the properties. The Company capitalizes a portion of its interest costs to its unevaluated properties and such costs become subject to depletion when proved reserves can be assigned to the associated properties. All items classified as unevaluated properties are assessed on a quarterly basis for possible impairment. The assessment includes consideration of the following factors, among others: intent to drill, remaining lease term, geological and geophysical evaluations, drilling results and activity, the assignment of proved reserves and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, the cumulative drilling incurred capital expenditures to date for such property and all or a portion of the associated leasehold costs are transferred to the full cost pool and are then subject to depletion. Sales of oil and natural gas properties, whether or not being depleted currently, are accounted for as adjustments of capitalized costs, with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil, NGL and natural gas. The following table presents incurred capital expenditures in the acquisition, exploration and development of oil and natural gas properties, with asset retirement obligations included in evaluated property acquisition costs and development costs, for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Property acquisition costs: Evaluated $ — $ — $ — $ 7,586 Unevaluated — 912 — 16,468 Exploration costs 15,313 3,374 19,270 10,084 Development costs 87,509 72,567 152,001 218,725 Total oil and natural gas properties incurred capital expenditures $ 102,822 $ 76,853 $ 171,271 $ 252,863 The aforementioned total oil and natural gas properties incurred capital expenditures included certain employee-related costs as shown in the table below. The following table presents capitalized employee-related incurred capital expenditures in the acquisition, exploration and development of oil and natural gas properties for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Capitalized employee-related costs $ 4,848 $ 4,092 $ 9,089 $ 8,597 The following table presents depletion expense, which is included in "Depletion, depreciation and amortization" on the unaudited consolidated statements of operations, and depletion expense per BOE sold of evaluated oil and natural gas properties for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands except per BOE data) 2021 2020 2021 2020 Depletion expense of evaluated oil and natural gas properties $ 36,650 $ 63,305 $ 71,375 $ 121,057 Depletion expense per BOE sold $ 4.69 $ 7.39 $ 4.78 $ 7.36 The full cost ceiling is based principally on the estimated future net cash flows from proved oil, NGL and natural gas reserves, which exclude the effect of the Company's commodity derivative transactions, discounted at 10%. SEC guidelines require companies to use the unweighted arithmetic average first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period before differentials ("Benchmark Prices"). The Benchmark Prices are then adjusted for quality, certain transportation fees, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the delivery point ("Realized Prices") without giving effect to the Company's commodity derivative transactions. The Realized Prices are utilized to calculate the estimated future net cash flows in the full cost ceiling calculation. Significant inputs included in the calculation of discounted cash flows used in the impairment analysis include the Company's estimate of operating and development costs, anticipated production of proved reserves and other relevant data. In the event the unamortized cost of evaluated oil and natural gas properties being depleted exceeds the full cost ceiling, as defined by the SEC, the excess is expensed in the period such excess occurs. Once incurred, a write-down of oil and natural gas properties is not reversible. The unamortized cost of evaluated oil and natural gas properties being depleted did not exceed the full cost ceiling as of June 30, 2021, and as such, the Company did not record a second-quarter full cost ceiling impairment. The following table presents the Benchmark Prices and the Realized Prices as of the dates presented: June 30, 2021 March 31, 2021 December 31, 2020 September 30, 2020 Benchmark Prices: Oil ($/Bbl) $ 46.26 $ 36.49 $ 36.04 $ 39.88 NGL ($/Bbl) (1) $ 23.69 $ 19.24 $ 16.63 $ 16.95 Natural gas ($/MMBtu) $ 2.06 $ 1.69 $ 1.21 $ 1.06 Realized Prices: Oil ($/Bbl) $ 47.31 $ 38.28 $ 37.69 $ 41.08 NGL ($/Bbl) $ 14.01 $ 9.92 $ 7.43 $ 7.71 Natural gas ($/Mcf) $ 1.51 $ 1.20 $ 0.79 $ 0.68 _____________________________________________________________________________ (1) Based on the Company's average composite NGL barrel. The following table presents full cost ceiling impairment expense, which is included in "Impairment expense" on the unaudited consolidated statements of operations for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Full cost ceiling impairment expense $ — $ 406,448 $ — $ 583,630

Debt

Debt	6 Months Ended
	Jun. 30, 2021
Debt Disclosure [Abstract]
Debt	Debt a. January 2025 Notes and January 2028 Notes On January 24, 2020, the Company completed an offer and sale (the "Offering") of $600.0 million in aggregate principal amount of 9 1/2% senior unsecured notes due 2025 (the "January 2025 Notes") and $400.0 million in aggregate principal amount of 10 1/8% senior unsecured notes due 2028 (the "January 2028 Notes"). Interest for both the January 2025 Notes and January 2028 Notes is payable semi-annually, in cash in arrears on January 15 and July 15 of each year. The first interest payment was made on July 15, 2020, and consisted of interest from closing to that date. The terms of the January 2025 Notes and January 2028 Notes include covenants, which are in addition to but different than similar covenants in the Senior Secured Credit Facility, which limit the Company's ability to incur indebtedness, make restricted payments, grant liens and dispose of assets. The January 2025 Notes and January 2028 Notes are fully and unconditionally guaranteed on a senior unsecured basis by LMS, GCM and certain of the Company's future restricted subsidiaries, subject to certain automatic customary releases, including the sale, disposition or transfer of all of the capital stock or of all or substantially all of the assets of a subsidiary guarantor to one or more persons that are not the Company or a restricted subsidiary, exercise of legal defeasance or covenant defeasance options or satisfaction and discharge of the applicable indenture, designation of a subsidiary guarantor as a non-guarantor restricted subsidiary or as an unrestricted subsidiary in accordance with the applicable indenture, release from guarantee under the Senior Secured Credit Facility, or liquidation or dissolution (collectively, the "Releases"). The Company received net proceeds of $982.0 million from the Offering, after deducting underwriting discounts and commissions and estimated offering expenses. The proceeds from the Offering were used (i) to fund Tender Offers (defined below) for the Company's January 2022 Notes and March 2023 Notes (defined below), (ii) to repay the Company's January 2022 Notes and March 2023 Notes that remained outstanding after settling the Tender Offers and (iii) for general corporate purposes, including repayment of a portion of the borrowings outstanding under the Senior Secured Credit Facility. In November 2020, the Company's board of directors authorized a $50.0 million bond repurchase program. During the year ended December 31, 2020, the Company repurchased $22.1 million in aggregate principal amount of the January 2025 Notes and $39.0 million in aggregate principal amount of the January 2028 Notes for aggregate consideration of $13.9 million and $24.2 million, respectively, plus accrued and unpaid interest. The Company recognized a gain on extinguishment b. January 2022 Notes and March 2023 Notes On January 23, 2014, the Company completed an offering of $450.0 million in aggregate principal amount of 5 5/8% senior unsecured notes due 2022 (the "January 2022 Notes"). The January 2022 Notes were due to mature on January 15, 2022 and bore an interest rate of 5 5/8% per annum, payable semi-annually, in cash in arrears on January 15 and July 15 of each year, commencing July 15, 2014. The January 2022 Notes were fully and unconditionally guaranteed on a senior unsecured basis by LMS, GCM and certain of the Company's future restricted subsidiaries, subject to certain Releases. On March 18, 2015, the Company completed an offering of $350.0 million in aggregate principal amount of 6 1/4% senior unsecured notes due 2023 (the "March 2023 Notes"). The March 2023 Notes were due to mature on March 15, 2023 and bore an interest rate of 6 1/4% per annum, payable semi-annually, in cash in arrears on March 15 and September 15 of each year, commencing September 15, 2015. The March 2023 Notes were fully and unconditionally guaranteed on a senior unsecured basis by LMS, GCM and certain of the Company's future restricted subsidiaries, subject to certain Releases. On January 6, 2020, the Company commenced cash tender offers and consent solicitations for any or all of its outstanding January 2022 Notes and March 2023 Notes (collectively, the "Tender Offers"). On January 24, 2020 and February 6, 2020, the Company settled the Tender Offers for the outstanding principal amounts of $428.9 million and $299.4 million, respectively, for consideration for tender offers and early tender premiums of $431.6 million and $304.1 million for the January 2022 Notes and March 2023 Notes, respectively, plus accrued and unpaid interest. On January 29, 2020, the Company redeemed the remaining $21.1 million of January 2022 Notes not tendered under the Tender Offers at a redemption price of 100.000% of the principal amount thereof, plus accrued and unpaid interest. On March 15, 2020, the Company redeemed the remaining $50.6 million of March 2023 Notes not tendered under the Tender Offers at a redemption price of 101.563% of the principal amount thereof, plus accrued and unpaid interest. The Company recognized a loss on extinguishment of $13.3 million related to the difference between the consideration for tender offers, early tender premiums and redemption prices and the net carrying amounts of the extinguished January 2022 Notes and March 2023 Notes. c. Senior Secured Credit Facility On May 7, 2021, the Company entered into the Sixth Amendment (the “Sixth Amendment”) to the “Senior Secured Credit Facility” among the Company, as borrower, Wells Fargo Bank, N.A., as administrative agent, Laredo Midstream Services, LLC and Garden City Minerals, LLC, as guarantors, and the banks signatory thereto. The Sixth Amendment, among other things, reaffirmed the Senior Secured Credit Facility borrowing base at $725 million and amended the Senior Secured Credit Facility to permit (i) the Sabalo/Shad Acquisition and the other transactions contemplated by the Sabalo/Shad PSAs and (ii) the Working Interest Sale and the other transactions contemplated by the Sixth Street PSA, in each case, subject to the terms of the Sixth Amendment and the Senior Secured Credit Facility. As of June 30, 2021, the Senior Secured Credit Facility, which matures on April 19, 2023, had a maximum credit amount of $2.0 billion, a borrowing base and an aggregate elected commitment of $725.0 million each, with $380.0 million outstanding, and was subject to an interest rate of 3.658%. The Senior Secured Credit Facility contains both financial and non-financial covenants, all of which the Company was in compliance with for all periods presented. Additionally, the Senior Secured Credit Facility provides for the issuance of letters of credit, limited to the lesser of total capacity or $80.0 million. As of June 30, 2021 and December 31, 2020, the Company had one letter of credit outstanding of $44.1 million under the Senior Secured Credit Facility. The Senior Secured Credit Facility is fully and unconditionally guaranteed by LMS and GCM. For additional information see Note 7.c in the 2020 Annual Report. See Note 19.c for discussion of (i) additional borrowings and payments on and (ii) an amendment to the Senior Secured Credit Facility subsequent to June 30, 2021. The Company's measurements of Adjusted EBITDA (non-GAAP) for financial reporting as compared to compliance under its debt agreements differ. d. Debt issuance costs The Company capitalized debt issuance costs of $18.4 million during the six months ended June 30, 2020 in connection with the issuance of the January 2025 Notes and January 2028 Notes. The Company capitalized $1.5 million in debt issuance costs during the six months ended June 30,2021 in connection with entering into the Sixth Amendment to the Senior Secured Credit Facility. The Company wrote off debt issuance costs during the six months ended June 30, 2020 in connection with the extinguishment of the January 2022 Notes and March 2023 Notes, which are included in "Loss on extinguishment of debt" on the unaudited consolidated statement of operations. No debt issuance costs were written off during the six months ended June 30, 2021. The Company had total debt issuance costs of $16.0 million and $17.0 million, net of accumulated amortization of $24.2 million and $22.1 million, as of June 30, 2021 and December 31, 2020, respectively. Debt issuance costs related to the Company's January 2025 and January 2028 Notes are included in "Long-term debt, net" on the unaudited consolidated balance sheets. Debt issuance costs related to the Senior Secured Credit Facility are included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets. Debt issuance costs are amortized on a straight-line basis over the respective terms of the notes and the Senior Secured Credit Facility. See Note 6.e for additional discussion of debt issuance costs. e. Long-term debt, net The following table presents the Company's long-term debt and debt issuance costs, net included in "Long-term debt, net" on the unaudited consolidated balance sheets as of the dates presented: June 30, 2021 December 31, 2020 (in thousands) Long-term debt Debt issuance costs, net Long-term debt, net Long-term debt Debt issuance costs, net Long-term debt, net January 2025 Notes $ 577,913 $ (7,402) $ 570,511 $ 577,913 $ (8,676) $ 569,237 January 2028 Notes 361,044 (5,443) 355,601 361,044 (6,015) 355,029 Senior Secured Credit Facility (1) 380,000 — 380,000 255,000 — 255,000 Long-term debt, net $ 1,318,957 $ (12,845) $ 1,306,112 $ 1,193,957 $ (14,691) $ 1,179,266 ______________________________________________________________________________ (1) Debt issuance costs, net related to the Senior Secured Credit Facility of $3.2 million and $2.3 million as of June 30, 2021 and December 31, 2020, respectively, are included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets. See Note 19.a for discussion of an additional notes offering subsequent to June 30, 2021.

Stockholders' equity

Stockholders' equity	6 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Stockholders' equity	Stockholders' equity a. ATM Program On February 23, 2021, the Company entered into an equity distribution agreement (the "Equity Distribution Agreement") with Wells Fargo Securities, LLC acting as sales agent and/or principal (the "Sales Agent"), pursuant to which the Company may offer and sell, from time to time through the Sales Agent, shares of its common stock, par value $0.01 per share (the "common stock"), having an aggregate gross sales price of up to $75.0 million through an "at-the-market" equity program (the "ATM Program"). Pursuant to the Equity Distribution Agreement, shares of common stock may be offered and sold in privately negotiated transactions or transactions that are deemed to be "at-the-market" offerings as defined in Rule 415 under the Securities Act, including by ordinary brokers’ transactions through the facilities of the New York Stock Exchange, to or through a market maker or as otherwise agreed with the Sales Agent. Under the terms of the Equity Distribution Agreement, the Company may also sell common stock from time to time to the Sales Agent as principal for its own account at a price to be agreed upon at the time of sale. Any sale of common stock to the Sales Agent as principal would be pursuant to the terms of a separate terms agreement between the Company and the Sales Agent, which would be described in a separate prospectus supplement or pricing supplement. As of June 30, 2021, the Company has sold 1,438,105 shares of its common stock pursuant to the ATM Program for net proceeds of approximately $72.5 million, after underwriting commissions and other related expenses. Proceeds from the share sales were utilized to reduce borrowings on the Senior Secured Credit Facility. b. Reverse stock split and Authorized Share Reduction On March 17, 2020, the board of directors authorized an amendment to the Company's amended and restated certificate of incorporation ("Certificate of Incorporation") to effect, at the discretion of the board of directors (i) a reverse stock split that would reduce the number of shares of outstanding common stock in accordance with a ratio to be determined by the board of directors within a range of 1-for-5 and 1-for-20 currently outstanding and (ii) a reduction of the number of authorized shares of common stock by a corresponding proportion ("Authorized Share Reduction"). On May 14, 2020, after receiving stockholder approval of the amendment to the Certificate of Incorporation, the board of directors approved the implementation of the reverse stock split at a ratio of 1-for-20 currently outstanding shares of common stock, and the related corresponding Authorized Share Reduction. On June 1, 2020, the amendment to the Certificate of Incorporation became effective and effected the 1-for-20 reverse stock split of the Company's issued and outstanding common stock and the related Authorized Share Reduction from 450,000,000 to 22,500,000 authorized shares, par value $0.01 per share, with authorized shares of preferred stock remaining unchanged at 50,000,000, par value $0.01 per share, for a total of 72,500,000 shares of capital stock. See Note 8 for discussion of the Equity Incentive Plan (defined below), that proportionately reduced the number of shares that may be granted. c. Treasury stock Treasury stock is recorded at cost, which includes incremental direct transaction costs, and is retired upon acquisition as a result of (i) stock exchanged to satisfy tax withholding that arises upon the lapse of restrictions on share-settled equity-based awards at the awardee's election or (ii) stock exchanged for the cost of exercise of stock options at the awardee's election.

Equity Incentive Plan

Equity Incentive Plan	6 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Equity Incentive Plan	Equity Incentive Plan The Laredo Petroleum, Inc. Omnibus Equity Incentive Plan (the "Equity Incentive Plan") provides for the granting of incentive awards in the form of restricted stock awards, stock option awards, performance share awards, outperformance share awards, performance unit awards, phantom unit awards and other awards. On June 1, 2020, in connection with the effectiveness of the reverse stock split and Authorized Share Reduction, the board of directors approved and adopted an amendment to the Equity Incentive Plan to proportionately adjust the limitations on awards that may be granted under the Equity Incentive Plan. Following the amendment, an aggregate of 1,492,500 shares of common stock may be issued under the Equity Incentive Plan. See Note 7.b for additional discussion of the reverse stock split and Authorized Share Reduction. On May 20, 2021, the Company's stockholders approved an amendment to the Equity Incentive Plan to, among other things, increase the maximum number of shares of the Company's common stock issuable under the Equity Incentive Plan from 1,492,500 to 2,432,500 shares. See Note 9.a in the 2020 Annual Report for additional discussion of the Company's equity-based compensation awards. a. Restricted stock awards Restricted stock awards granted to employees vest on a 33%, 33% and 34% schedule per year beginning on the first anniversary of the grant date and restricted stock awards granted to non-employee directors vest immediately on the grant date. The following table reflects the restricted stock award activity for the six months ended June 30, 2021: (in thousands, except for weighted-average grant-date fair value) Restricted stock awards Weighted-average Outstanding as of December 31, 2020 309 $ 44.88 Granted 194 $ 36.04 Forfeited (41) $ 44.67 Vested (1) (125) $ 64.14 Outstanding as of June 30, 2021 337 $ 32.70 _____________________________________________________________________________ (1) The aggregate intrinsic value of vested restricted stock awards for the six months ended June 30, 2021 was $4.9 million. The Company utilizes the closing stock price on the grant date to determine the fair value of restricted stock awards. As of June 30, 2021, unrecognized equity-based compensation related to the restricted stock awards expected to vest was $8.8 million. Such cost is expected to be recognized over a weighted-average period of 1.95 years. b. Stock option awards As of June 30, 2021, the 11,362 outstanding stock option awards had a weighted-average exercise price of $257.42 per award and a weighted-average remaining contractual term of 3.29 years. There was no activity related to the stock option awards during the six months ended June 30, 2021. The intrinsic value of the vested and exercisable stock option awards as of June 30, 2021 was de minimis. c. Performance share awards Performance share awards, which the Company has determined are equity awards, are subject to a combination of market, performance and service vesting criteria. For portions of awards with market criteria, a Monte Carlo simulation prepared by an independent third party is utilized to determine the grant-date (or modification date) fair value, and the associated expense is recognized on a straight-line basis over the three-year requisite service period of the awards. For portions of awards with performance criteria, the fair value is equal to the Company's closing stock price on the grant date (or modification date), and for each reporting period, the associated expense fluctuates and is adjusted based on an estimated payout of the number of shares of common stock to be delivered on the payment date for the three-year performance period. These awards were granted in 2019 and 2018, and their market criteria consists of: (i) the relative three-year total shareholder return ("TSR") comparing the Company's shareholder return to the shareholder return of the peer group specified in each award agreement ("RTSR Performance Percentage") and (ii) the Company's absolute three-year total shareholder return ("ATSR Appreciation"). The performance criteria for these awards consists of the Company's three-year return on average capital employed ("ROACE Percentage"). Any shares earned under performance share awards are expected to be issued in the first quarter following the completion of the respective requisite service periods based on the achievement of certain market and performance criteria, and the payout can range from 0% to 200%. The following table reflects the performance share award activity for the six months ended June 30, 2021: (in thousands, except for weighted-average grant-date fair value) Performance share awards Weighted-average Outstanding as of December 31, 2020 97 $ 84.06 Forfeited (10) $ 74.70 Vested (1) (15) $ 184.43 Outstanding as of June 30, 2021 72 $ 64.78 ______________________________________________________________________________ (1) The performance share awards granted on February 16, 2018 had a performance period of January 1, 2018 to December 31, 2020 and, as their market and performance criteria were partially satisfied, resulted in a 43% payout. As such, the granted awards vested and were converted into 6,343 shares of the Company's common stock during the six months ended June 30, 2021 based on this 43% payout. As of June 30, 2021, unrecognized equity-based compensation related to the performance share awards expected to vest was $1.4 million. Such cost is expected to be recognized over a weighted-average period of 0.67 years. As of June 30, 2021, the expense per performance share, which is the fair value per performance share adjusted for the estimated payout of the performance criteria, was $86.64. d. Outperformance share award An outperformance share award was granted during the year ended December 31, 2019, in conjunction with the appointment of the Company's President, and is accounted for as an equity award. If earned, the payout ranges from 0 to 50,000 shares in the Company's common stock per the vesting schedule. This award is subject to a combination of market and service vesting criteria, therefore, a Monte Carlo simulation prepared by an independent third party was utilized to determine the grant-date fair value with the associated expense recognized over the requisite service period. The payout of this award is based on the highest 50 consecutive trading day average closing stock price of the Company that occurs during the performance period that commenced on June 3, 2019 and ends on June 3, 2022 ("Final Date"). Of the earned outperformance shares, one-third of the award will vest on the Final Date, one-third will vest on the first anniversary of the Final Date and one-third will vest on the second anniversary of the Final Date, provided that the participant has been continuously employed with the Company through the applicable vesting date. As of June 30, 2021, unrecognized equity-based compensation related to the outperformance share award expected to vest was $0.3 million. Such cost is expected to be recognized over a weighted-average period of 2.14 years. e. Performance unit awards Performance unit awards, which the Company has determined are liability awards since they are settled in cash, are subject to a combination of market, performance and service vesting criteria. For portions of awards with market criteria, a Monte Carlo simulation prepared by an independent third party is utilized to determine the fair value, and is re-measured at each reporting period until settlement. For portions of awards with performance criteria, the Company's closing stock price is utilized to determine the fair value and is re-measured on the last trading day of each reporting period until settlement and, additionally, the associated expense fluctuates based on an estimated payout for the three-year performance period. The expense related to the performance unit awards is recognized on a straight-line basis over the three-year requisite service period of the awards, and the life-to-date recognized expense is adjusted accordingly at each reporting period based on the quarterly fair value re-measurements and redetermination of the estimated payout for the performance criteria. For performance unit awards granted in 2021, the market criteria consists of: (i) annual relative total shareholder return comparing the Company's shareholder return to the shareholder return of the E&P companies listed in the Russell 2000 index ("Relative TSR") and (ii) annual absolute total shareholder return ("Absolute Return"), together the "PSU Matrix." The performance criteria for these awards consists of: (i) earnings before interest , taxes, depreciation, amortization and exploration expense ("EBITDAX") and three-year total debt reduction (the "EBITDAX/Total Debt Component") and (ii) growth in inventory (the "Inventory Growth Component"). Any units earned are expected to be paid in cash during the first quarter following the completion of the requisite service period, based on the achievement of certain market and performance criteria, and the payout can range from 0% to 250% for the market criteria and 0% to 200% for the performance criteria. For performance unit awards granted in 2020, the market criteria consists of: (i) the RTSR Performance Percentage and (ii) the ATSR Appreciation. The performance criteria for these awards consists of the ROACE Percentage. Any units earned are expected to be paid in cash during the first quarter following the completion of the requisite service period, based on the achievement of certain market and performance criteria, and the payout can range from 0% to 200%, but is capped at 100% if the ATSR Appreciation is zero or less. The following table presents the assumptions used to estimate the fair value per performance unit for the performance unit awards granted in 2021: March 9, 2021 Remaining performance period 2.81 years Risk-free interest rate (1) 0.32 % Dividend yield — % Expected volatility (2) 114.60 % Closing stock price on grant date $ 34.66 ______________________________________________________________________________ (1) The remaining performance period matched zero-coupon risk-free interest rate was derived from the U.S. Treasury constant maturities yield curve on grant date. (2) The Company utilized its own remaining performance period matched historical volatility in order to develop the expected volatility. The following table reflects the performance unit award activity for the six months ended June 30, 2021: (in thousands) Performance units Outstanding as of December 31, 2020 99 Granted 110 Outstanding as of June 30, 2021 209 As of June 30, 2021, unrecognized equity-based compensation related to the performance unit awards expected to vest was $21.5 million. Such cost is expected to be recognized over a weighted-average period of 2.31 years. As of June 30, 2021, the expense per performance unit, which is the fair value per performance unit adjusted for the estimated payout of the performance criteria, for the 2021 and 2020 performance unit awards was $135.58 and $145.77, respectively. f. Phantom unit awards Phantom unit awards, which the Company has determined are liability awards, represent the holder's right to receive the cash equivalent of one share of common stock of the Company for each phantom unit as of the applicable vesting date, subject to withholding requirements. Phantom unit awards granted to employees vest 33%, 33% and 34% per year beginning on the first anniversary of the grant date. The following table reflects the phantom unit award activity for the six months ended June 30, 2021: (in thousands) Phantom units Outstanding as of December 31, 2020 75 Granted 5 Forfeited (22) Vested (1) (25) Outstanding as of June 30, 2021 33 ______________________________________________________________________________ (1) On March 5, 2021, the vested phantom unit awards were settled and paid out in cash at a fair value of $34.24 based on the Company's closing stock price on the vesting date. The Company utilizes the closing stock price on the last day of each reporting period to determine the fair value of phantom unit awards and the life-to-date recognized expense is adjusted accordingly. As of June 30, 2021, unrecognized equity-based compensation related to the phantom unit awards expected to vest was $2.6 million. Such cost is expected to be recognized over a weighted-average period of 1.82 years. g. Equity-based compensation The following table reflects equity-based compensation expense for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Equity awards: Restricted stock awards $ 1,857 $ 2,044 $ 3,820 $ 4,542 Performance share awards (129) 282 596 1,038 Outperformance share award 44 43 87 87 Stock option awards — 7 7 50 Total share-settled equity-based compensation, gross $ 1,772 $ 2,376 $ 4,510 $ 5,717 Less amounts capitalized (42) (682) (712) (1,647) Total share-settled equity-based compensation, net $ 1,730 $ 1,694 $ 3,798 $ 4,070 Liability awards: Performance unit awards $ 6,352 $ 166 $ 7,172 $ 190 Phantom unit awards 427 86 7 933 111 Total cash-settled equity-based compensation, gross $ 6,779 $ 252 $ 8,105 $ 301 Less amounts capitalized (95) (33) (293) (43) Total cash-settled equity-based compensation, net $ 6,684 $ 219 $ 7,812 $ 258 Total equity-based compensation, net $ 8,414 $ 1,913 $ 11,610 $ 4,328

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	DerivativesThe Company has three types of derivative instruments as of June 30, 2021: (i) commodity derivatives, (ii) a debt interest rate derivative and (iii) a contingent consideration derivative. See Notes (i) 2.e in the 2020 Annual Report for discussion of the Company's significant accounting policies for derivatives and presentation, (ii) 10.a for discussion of fair value measurement of derivatives on a recurring basis and (iii) 19.d for discussion of derivatives subsequent events. The Company's derivatives were not designated as hedges for accounting purposes, and the Company does not enter into such instruments for speculative trading purposes. Accordingly, the changes in fair value are recognized in "Gain (loss) on derivatives, net" under "Non-operating income (expense)" on the unaudited consolidated statements of operations. The following table summarizes components of the Company's gain (loss) on derivatives, net by type of derivative instrument for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Commodity $ (216,869) $ (90,864) $ (370,902) $ 200,497 Interest rate (30) (338) (26) (338) Contingent consideration (43) 665 (379) 7,140 Gain (loss) on derivatives, net $ (216,942) $ (90,537) $ (371,307) $ 207,299 a. Commodity Due to the inherent volatility in oil, NGL and natural gas prices and differences in the prices of oil, NGL and natural gas between where the Company produces and where the Company sells such commodities, the Company engages in commodity derivative transactions, such as puts, swaps, collars and basis swaps, to hedge price risk associated with a portion of the Company's anticipated sales volumes. By removing a portion of the price volatility associated with future sales volumes, the Company expects to mitigate, but not eliminate, the potential effects of variability in cash flows from operations. See Note 9 in the 2020 Annual Report for discussion of transaction types and settlement indexes. During the six months ended June 30, 2021, the Company’s derivatives were settled based on reported prices on commodity exchanges, with (i) oil derivatives settled based on Brent ICE pricing, (ii) NGL derivatives settled based on Mont Belvieu OPIS pricing and (iii) natural gas derivatives settled based on Henry Hub NYMEX and Waha Inside FERC pricing. During the six months ended June 30, 2021, the Company completed a hedge restructuring by (i) selling 2,254,500 calendar year 2021 $55.00 per barrel Brent ICE puts, which volumetrically offset existing calendar year 2021 $55.00 per barrel Brent ICE puts, and receiving aggregate premiums of $9.0 million at inception of the contracts and (ii) entering into 2,254,500 calendar year 2021 Brent ICE swaps at a weighted-average price of $55.09 per barrel. Associated with the aforementioned existing calendar year 2021 $55.00 per barrel Brent ICE puts, which were entered into during 2020, were $50.6 million in aggregate premiums paid at the inception of the contacts. During the six months ended June 30, 2020, the Company completed a hedge restructuring by early terminating collars and entering into new swaps. The following table presents the commodity derivatives that were terminated: Aggregate volumes (Bbl) Floor price ($/Bbl) Ceiling price ($/Bbl) Contract period WTI NYMEX - Collars 912,500 $ 45.00 $ 71.00 January 2021 - December 2021 The following table summarizes open commodity derivative positions as of June 30, 2021, for commodity derivatives that were entered into through June 30, 2021, for the settlement periods presented: Remaining Year 2021 (1) Year 2022 (1) Oil: WTI NYMEX - Collars: Volume (Bbl) — 1,204,500 Weighted-average floor price ($/Bbl) $ — $ 55.00 Weighted-average ceiling price ($/Bbl) $ — $ 74.35 Brent ICE - Swaps: Volume (Bbl) 3,781,200 4,124,500 Weighted-average price ($/Bbl) $ 51.29 $ 48.34 Brent ICE - Collars: Volume (Bbl) 662,400 1,551,250 Weighted-average floor price ($/Bbl) $ 55.00 $ 56.65 Weighted-average ceiling price ($/Bbl) $ 66.53 $ 65.44 Total Brent ICE: Total volume (Bbl) 4,443,600 5,675,750 Weighted-average floor price ($/Bbl) $ 51.84 $ 50.61 Weighted-average ceiling price ($/Bbl) $ 53.56 $ 53.01 NGL: Mont Belvieu OPIS: Purity Ethane - Swaps: Volume (Bbl) 460,000 — Weighted-average price ($/Bbl) $ 12.01 $ — Non-TET Propane - Swaps: Volume (Bbl) 1,221,576 — Weighted-average price ($/Bbl) $ 22.90 $ — Non-TET Normal Butane - Swaps: Volume (Bbl) 407,192 — Weighted-average price ($/Bbl) $ 25.87 $ — Non-TET Isobutane - Swaps: Volume (Bbl) 111,136 — Weighted-average price ($/Bbl) $ 26.55 $ — Non-TET Natural Gasoline - Swaps: Volume (Bbl) 444,176 — Weighted-average price ($/Bbl) $ 38.16 $ — Total NGL volume (Bbl) 2,644,080 — Natural gas: Henry Hub NYMEX - Swaps: Volume (MMBtu) 21,436,000 3,650,000 Weighted-average price ($/MMBtu) $ 2.59 $ 2.73 Waha Inside FERC to Henry Hub NYMEX - Basis Swaps: Volume (MMBtu) 28,556,800 18,067,500 Weighted-average differential ($/MMBtu) $ (0.47) $ (0.41) ______________________________________________________________________________ (1) Does not include derivative positions entered into on behalf of Sixth Street, which were novated upon closing of the Working Interest Sale subsequent to June 30, 2021. During the three months ended June 30, 2021, in connection with the Working Interest Sale, the Company entered into derivative positions on behalf of Sixth Street. These derivatives are included in the Company's mark-to-market hedge position as of June 30, 2021 and were subsequently novated to Sixth Street upon the closing of the Working Interest Sale. The following table summarizes the commodity derivative positions entered into on behalf of Sixth Street as of June 30, 2021, for commodity derivatives that were entered into through June 30, 2021, for the settlement periods presented: Remaining Year 2021 Year 2022 Year 2023 Year 2024 Year 2025 Oil: WTI NYMEX - Swaps: Volume (Bbl) 786,242 1,280,111 1,017,720 847,480 730,509 Weighted-average price ($/Bbl) $ 63.38 $ 59.79 $ 56.70 $ 54.70 $ 53.52 WTI Midland to WTI Nymex - Basis Swaps: Volume (Bbl) 786,242 1,280,111 1,017,720 — 730,509 Weighted-average differential ($/Bbl) $ 0.24 $ 0.50 $ 0.50 $ — $ 0.40 NGL: Mont Belvieu OPIS: Purity Ethane - Swaps: Volume (Bbl) 356,327 629,123 280,362 — — Weighted-average price ($/Bbl) $ 10.50 $ 9.56 $ 8.87 $ — $ — Non-TET Propane - Swaps: Volume (Bbl) 267,245 471,841 210,271 — — Weighted-average price ($/Bbl) $ 33.60 $ 28.19 $ 24.89 $ — $ — Non-TET Normal Butane - Swaps: Volume (Bbl) 80,983 142,983 63,719 — — Weighted-average price ($/Bbl) $ 37.70 $ 31.55 $ 27.77 $ — $ — Non-TET Isobutane - Swaps: Volume (Bbl) 24,295 42,897 19,116 — — Weighted-average price ($/Bbl) $ 37.54 $ 31.45 $ 27.67 $ — $ — Non-TET Natural Gasoline - Swaps: Volume (Bbl) 80,983 142,983 63,719 — — Weighted-average price ($/Bbl) $ 58.38 $ 52.92 $ 48.20 $ — $ — Total NGL volume (Bbl) 809,833 1,429,827 637,187 — — Natural gas: Henry Hub NYMEX - Swaps: Volume (MMBtu) 9,219,072 16,276,973 14,038,618 12,385,310 11,112,681 Weighted-average price ($/MMBtu) $ 3.00 $ 2.73 $ 2.56 $ 2.55 $ 2.57 Waha Inside FERC to Henry Hub NYMEX - Basis Swaps: Volume (MMBtu) 9,219,072 16,276,973 14,038,618 12,385,310 — Weighted-average differential ($/MMBtu) $ (0.04) $ (0.26) $ (0.41) $ (0.42) $ — b. Interest rate Due to the inherent volatility in interest rates, the Company has entered into an interest rate derivative swap to hedge interest rate risk associated with a portion of the Company's anticipated outstanding debt under the Senior Secured Credit Facility. The Company will pay a fixed rate over the contract term for that portion. By removing a portion of the interest rate volatility associated with anticipated outstanding debt, the Company expects to mitigate, but not eliminate, the potential effects of variability in cash flows from operations. The following table summarizes the Company's interest rate derivative: Notional amount Fixed rate Contract period LIBOR - Swap $ 100,000 0.345 % April 16, 2020 - April 18, 2022 c. Contingent consideration The Company's asset acquisition of oil and natural gas properties that closed on April 30, 2020 provides for potential contingent payments to be paid by the Company if the arithmetic average of the monthly settlement WTI NYMEX prices exceed certain thresholds for the contingency period beginning on January 1, 2021 and ending on the earlier of December 31, 2022 or the date the counterparty has received the maximum consideration of $1.2 million. See Note 3.b for further discussion of the Company's asset acquisition associated with potential contingent consideration payments. At each quarterly reporting period, the Company remeasures its contingent consideration with the changes in fair values recognized in earnings.

Fair value measurements

Fair value measurements	6 Months Ended
	Jun. 30, 2021
Fair Value Disclosures [Abstract]
Fair value measurements	Fair value measurements See the beginning of Note 11 in the 2020 Annual Report for information about the fair value hierarchy levels. a. Fair value measurement on a recurring basis See Note 9 for further discussion of the Company's derivatives, and see Note 2.e in the 2020 Annual Report for the Company's significant accounting policies for derivatives. Balance sheet presentation The following tables present the Company's derivatives by (i) balance sheet classification, (ii) derivative type and (iii) fair value hierarchy level, and provide a total, on a gross basis and a net basis reflected in "Derivatives" on the unaudited consolidated balance sheets as of the dates presented: June 30, 2021 (in thousands) Level 1 Level 2 Level 3 Total gross fair value Amounts offset Net fair value presented on the unaudited consolidated balance sheets Assets: Current: Commodity - Oil $ — $ 5,993 $ — $ 5,993 $ (5,993) $ — Commodity - NGL — 27 — 27 (27) — Commodity - Natural gas — 1,650 — 1,650 (1,650) — Noncurrent: Commodity - Oil $ — $ 6,678 $ — $ 6,678 $ (6,255) $ 423 Commodity - NGL — — — — — — Commodity - Natural gas — 6,542 — 6,542 (6,542) — Liabilities: Current: Commodity - Oil $ — $ (150,865) $ — $ (150,865) $ 5,993 $ (144,872) Commodity - NGL — (65,171) — (65,171) 27 (65,144) Commodity - Natural gas — (46,756) — (46,756) 1,650 (45,106) Interest rate - LIBOR — (179) — (179) — (179) Contingent consideration — (1,159) — (1,159) — (1,159) Noncurrent: Commodity - Oil $ — $ (57,774) $ — $ (57,774) $ 6,255 $ (51,519) Commodity - NGL — (6,087) — (6,087) — (6,087) Commodity - Natural gas — (10,450) — (10,450) 6,542 (3,908) Interest rate - LIBOR — — — — — — Contingent consideration — — — — — — Net derivative liability positions $ — $ (317,551) $ — $ (317,551) $ — $ (317,551) December 31, 2020 (in thousands) Level 1 Level 2 Level 3 Total gross fair value Amounts offset Net fair value presented on the Assets: Current: Commodity - Oil $ — $ 32,958 $ — $ 32,958 $ (24,930) $ 8,028 Commodity - NGL — 2,720 — 2,720 (2,720) — Commodity - Natural gas — 521 — 521 (656) (135) Noncurrent: Commodity - Oil $ — $ — $ — $ — $ — $ — Commodity - NGL — — — — — — Commodity - Natural gas — 535 — 535 (535) — Liabilities: Current: Commodity - Oil $ — $ (25,118) $ — $ (25,118) $ 24,930 $ (188) Commodity - NGL — (16,185) — (16,185) 2,720 (13,465) Commodity - Natural gas — (17,958) — (17,958) 656 (17,302) Interest rate - LIBOR — (206) — (206) — (206) Contingent consideration — (665) — (665) — (665) Noncurrent: Commodity - Oil $ — $ (10,932) $ — $ (10,932) $ — $ (10,932) Commodity - NGL — — — — — — Commodity - Natural gas — (1,476) — (1,476) 535 (941) Interest rate - LIBOR — (63) — (63) — (63) Contingent consideration — (115) — (115) — (115) Net derivative liability positions $ — $ (35,984) $ — $ (35,984) $ — $ (35,984) See Note 11.a in the 2020 Annual Report for discussion of the significant Level 2 inputs used in the fair value mark-to-market analysis of commodity, interest rate and contingent consideration derivatives. The Company reviewed the third-party specialist's valuations of commodity, interest rate and contingent consideration derivatives, including the related inputs, and analyzed changes in fair values between reporting dates. b. Fair value measurement on a nonrecurring basis See Note 2.i in the 2020 Annual Report for the Level 2 fair value hierarchy input assumptions used in estimating the net realizable value ("NRV") of inventory used to determine the $1.6 million and $1.3 million impairment expense of inventory recorded during the six months ended June 30, 2021 and 2020, respectively, pertaining to line-fill and other inventories. See Note 11.b in the 2020 Annual Report for the Level 3 fair value hierarchy input assumptions used in the fair value measurement of long-lived assets used to determine the $8.2 million impairment expense of long-lived assets recorded during the six months ended June 30, 2020, pertaining to midstream service assets. There were no impairments of long-lived assets recorded during the six months ended June 30, 2021. c. Items not accounted for at fair value The carrying amounts reported on the unaudited consolidated balance sheets for cash and cash equivalents, accounts receivable, accounts payable, accrued capital expenditures, undistributed revenue and royalties and other accrued assets and liabilities approximate their fair values. The Company has not elected to account for its debt instruments at fair value. The following table presents the carrying amounts and fair values of the Company's debt as of the dates presented: June 30, 2021 December 31, 2020 (in thousands) Long-term Fair value (1) Long-term Fair value (1) January 2025 Notes $ 577,913 $ 608,953 $ 577,913 $ 499,299 January 2028 Notes 361,044 396,607 361,044 299,667 Senior Secured Credit Facility 380,000 380,611 255,000 255,187 Total $ 1,318,957 $ 1,386,171 $ 1,193,957 $ 1,054,153 ______________________________________________________________________________ (1) The fair values of the outstanding notes were determined using the Level 1 fair value hierarchy quoted market prices for each respective instrument as of June 30, 2021 and December 31, 2020. The fair values of the outstanding debt under the Senior Secured Credit Facility were estimated utilizing the Level 2 fair value hierarchy pricing model for similar instruments as of June 30, 2021 and December 31, 2020.

Net loss per common share

Net loss per common share	6 Months Ended
	Jun. 30, 2021
Earnings Per Share [Abstract]
Net loss per common share	Net loss per common share Basic and diluted net loss per common share are computed by dividing net loss by the weighted-average common shares outstanding for the period. Diluted net loss per common share reflects the potential dilution of non-vested restricted stock awards, outstanding stock option awards, non-vested performance share awards and the non-vested outperformance share award. See Note 8 for additional discussion of these awards. For the periods presented, all of these awards were anti-dilutive due to the Company's net loss and, therefore, were excluded from the calculation of diluted net loss per common share. The following table reflects the calculations of basic and diluted (i) weighted-average common shares outstanding and (ii) net loss per common share for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands, except for per share data) 2021 2020 2021 2020 Net loss (numerator) $ (132,661) $ (545,455) $ (208,100) $ (470,809) Weighted-average common shares outstanding (denominator): Basic 12,674 11,667 12,298 11,642 Diluted 12,674 11,667 12,298 11,642 Net loss per common share: Basic $ (10.47) $ (46.75) $ (16.92) $ (40.44) Diluted $ (10.47) $ (46.75) $ (16.92) $ (40.44)

Commitments and contingencies

Commitments and contingencies	6 Months Ended
	Jun. 30, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and contingencies	Commitments and contingencies a. Litigation From time to time, the Company is subject to various legal proceedings arising in the ordinary course of business, including proceedings for which the Company may not have insurance coverage. While many of these matters involve inherent uncertainty, as of the date hereof, the Company does not currently believe that any such legal proceedings will have a material adverse effect on the Company's business, financial position, results of operations or liquidity. b. Drilling rig contracts The Company enters into drilling rig contracts to ensure availability of desired rigs to facilitate drilling plans. The Company has two operating leases for terms of multiple months, both of which contain early termination clauses that require the Company to potentially pay penalties to the third party should the Company cease drilling efforts. These penalties would negatively impact the Company's financial statements upon early contract termination. There were no penalties incurred for early contract termination for either of the six months ended June 30, 2021 or 2020. As these drilling rig contracts are operating leases, the present value of the future commitment as of June 30, 2021 related to the drilling rig contract with an initial term greater than 12 months is included in current and noncurrent "Operating lease liabilities" on the unaudited consolidated balance sheet as of June 30, 2021. See Note 5 in the 2020 Annual Report for additional discussion of the Company's leases. c. Firm sale and transportation commitments The Company has committed to deliver, for sale or transportation, fixed volumes of product under certain contractual arrangements that specify the delivery of a fixed and determinable quantity. If not fulfilled, the Company is subject to firm transportation payments on excess pipeline capacity and other contractual penalties. These commitments are normal and customary for the Company's business. In certain instances, the Company has used spot market purchases to meet its commitments in certain locations or due to favorable pricing. A portion of the Company's commitments are related to transportation commitments with a certain pipeline pertaining to the gathering of the Company's production from established acreage that extends into 2024. The Company was unable to satisfy a portion of this particular commitment with produced or purchased oil, therefore, the Company expensed firm transportation payments on excess capacity of $1.1 million during the six months ended June 30, 2021, which is recorded in "Transportation and marketing expenses" on the unaudited consolidated statement of operations. No firm transportation payments on excess pipeline capacity were incurred during the six months ended June 30, 2020. The Company's estimated aggregate liability of firm transportation payments on excess capacity is $3.4 million as of June 30, 2021, and is included in "Accounts payable and accrued liabilities" on the unaudited consolidated balance sheet. As of June 30, 2021, future firm sale and transportation commitments of $244.4 million are expected to be satisfied, and as such, are not recorded as a liability on the unaudited consolidated balance sheet. d. Sand purchase commitment During the year ended December 31, 2020, the Company entered into an agreement to take delivery of processed sand at a fixed price for one year, which is utilized in the Company's completions activities, from its sand mine that is operated by a third-party contractor. As of June 30, 2021, under the terms of this agreement, the Company is required to purchase a certain volume remaining under its commitment or it would incur a shortfall payment of $1.7 million at the end of the contract period. e. Federal and state regulations Oil and natural gas exploration, production and related operations are subject to extensive federal and state laws, rules and regulations. Failure to comply with these laws, rules and regulations can result in substantial penalties. The regulatory burden on the oil and natural gas industry increases the cost of doing business and affects profitability. The Company believes that it is in compliance with currently applicable federal and state regulations related to oil and natural gas exploration and production, and that compliance with the current regulations will not have a material adverse impact on the financial position or results of operations of the Company. These rules and regulations are frequently amended or reinterpreted; therefore, the Company is unable to predict the future cost or impact of complying with these regulations. f. Environmental The Company is subject to extensive federal, state and local environmental laws and regulations. These laws, among other things, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Environmental expenditures are expensed in the period incurred. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment or remediation is probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable. Management believes no materially significant liabilities of this nature existed as of June 30, 2021 or December 31, 2020.

Supplemental cash flow and non-

Supplemental cash flow and non-cash information	6 Months Ended
	Jun. 30, 2021
Supplemental Cash Flow Elements [Abstract]
Supplemental cash flow and non-cash information	Supplemental cash flow and non-cash information The following table presents supplemental cash flow and non-cash information for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Supplemental cash flow information: Cash paid for interest, net of $890 and $1,822 of capitalized interest, respectively $ 49,966 $ 25,595 Supplemental non-cash investing information: Fair value of contingent consideration on acquisition date (1) $ — $ 225 Change in accrued capital expenditures $ 4,366 $ (15,024) Capitalized share-settled equity-based compensation $ 712 $ 1,647 Capitalized asset retirement cost $ 730 $ 1,082 _____________________________________________________________________________ (1) See Notes 3.b and 9.c for discussion of the Company's 2020 acquisition of oil and natural gas properties that includes contingent consideration. See Note 10.a for discussion of the quarterly remeasurement of this contingent consideration. The following table presents supplemental non-cash adjustments information related to operating leases for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Right-of-use assets obtained in exchange for operating lease liabilities (1) $ 7,532 $ 2,349 _____________________________________________________________________________ (1) See Note 4 for additional discussion of the Company's leases.

Asset retirement obligations

Asset retirement obligations	6 Months Ended
	Jun. 30, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations	Asset retirement obligations See Note 2.k in the 2020 Annual Report for discussion of the Company's significant accounting policies for asset retirement obligations. The following table reconciles the Company's asset retirement obligation liability associated with tangible long-lived assets for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Liability at beginning of period $ 68,326 $ 62,718 Liabilities added due to acquisitions, drilling, midstream service asset construction and other 730 1,082 Accretion expense (1) 2,301 2,223 Liabilities settled due to plugging and abandonment or removed due to sale (150) (778) Liability at end of period $ 71,206 $ 65,245 _____________________________________________________________________________ (1) Accretion expense is included in "Other operating expenses" on the unaudited consolidated statements of operations.

Revenue recognition

Revenue recognition	6 Months Ended
	Jun. 30, 2021
Revenue from Contract with Customer [Abstract]
Revenue recognition	Revenue recognition Oil, NGL and natural gas sales and sales of purchased oil are generally recognized at the point in time that control of the product is transferred to the customer. Midstream service revenues are recognized over time as the customer benefits from these services when provided. A more detailed summary of the underlying contracts that give rise to the Company's revenues and methods of recognition can be found in Note 14 in the 2020 Annual Report.

Income taxes

Income taxes	6 Months Ended
	Jun. 30, 2021
Income Tax Disclosure [Abstract]
Income taxes	Income taxesThe Company is subject to federal and state income taxes and the Texas franchise tax. As of June 30, 2021, the Company had federal net operating loss carryforwards totaling $2.2 billion, and of this amount, $1.7 billion will begin to expire in 2026 and $436.3 million will not expire but may be limited in future periods, and state of Oklahoma net operating loss carryforwards totaling $34.5 million that will begin to expire in 2032. As of June 30, 2021, the Company believes it is more likely than not that a portion of the net operating loss carryforwards are not fully realizable. The Company continues to consider new evidence, both positive and negative, in determining whether, based on the weight of that evidence, a valuation allowance is needed. Such consideration includes projected future cash flows from its oil, NGL and natural gas reserves (including the timing of those cash flows), the reversal of deferred tax liabilities recorded as of June 30, 2021, the Company's ability to capitalize intangible drilling costs, rather than expensing these costs and future projections of Oklahoma sourced income. As of June 30, 2021, a total valuation allowance of $532.8 million has been recorded to offset the Company's federal and Oklahoma net deferred tax assets, resulting in a Texas net deferred tax asset of $3.6 million, which is included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets.

Related parties

Related parties	6 Months Ended
	Jun. 30, 2021
Related Party Transactions [Abstract]
Related parties	Related parties Halliburton The Chairman of the Company's board of directors is on the board of directors of Halliburton Company ("Halliburton"). Halliburton provides drilling and completions services to the Company. The following table presents the capital expenditures for oil and natural gas properties paid to Halliburton included in the unaudited consolidated statements of cash flows for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Capital expenditures for oil and natural gas properties $ 25,657 $ 18,104

Organizational restructurings

Organizational restructurings	6 Months Ended
	Jun. 30, 2021
Restructuring and Related Activities [Abstract]
Organizational restructurings	Organizational restructurings On June 29, 2021 (the "Effective Date"), the Company committed to a company-wide reorganization effort (the “Plan”) that included a workforce reduction of 14 individuals, or approximately 5% of the workforce. The reduction in workforce was communicated to employees on the Effective Date and implemented immediately, subject to certain administrative procedures. The Company put the Plan in place in order to better position the Company for the future. In connection with the Plan, the Company incurred an aggregate of $9.8 million of one-time charges during the three months ended June 30, 2021 comprising of compensation, tax, professional, outplacement and insurance related expenses. These charges are accrued in "Other current liabilities" on the unaudited consolidated balance sheet as of June 30, 2021. All equity-based compensation awards held by the affected employees were forfeited and the corresponding equity-based compensation totaling $1.1 million was reversed during the three months ended June 30, 2021. See Note 8 for additional information on the associated forfeiture activity.On June 17, 2020, the Company announced organizational changes, including a workforce reduction of 22 individuals which included a senior officer, that were implemented immediately, subject to certain administrative procedures. In connection with these changes, the Company incurred $4.2 million of one-time charges during the three months ended June 30, 2020, comprised of compensation, tax, professional, outplacement and insurance-related expenses. All equity-based compensation awards held by the affected employees were forfeited and the corresponding equity-based compensation was reversed totaling $0.8 million during the three months ended June 30, 2020.

Subsequent events

Subsequent events	6 Months Ended
	Jun. 30, 2021
Subsequent Events [Abstract]
Subsequent events	Subsequent events a. July 2029 Notes On July 16, 2021, the Company closed a private offering and sale of $400.0 million in aggregate principal amount of 7.75% senior unsecured notes due 2029 (the "July 2029 Notes"). The Company received net proceeds from the offering of approximately $392.0 million (after deducting underwriting discounts and commissions and estimated offering expenses), which it intends to use for general corporate purposes, including, repaying a portion of the borrowings outstanding under the Senior Secured Credit Facility. b. 2021 Acquisition and divestiture On July 1, 2021, the Company closed the Sabalo/Shad Acquisition, and issued the 2,506,964 shares of its common stock constituting a portion of the purchase price in reliance on the exemption from registration requirements under the Securities Act, pursuant to Section 4(a)(2) thereof. On July 1, 2021, the Company also closed the Working Interest Sale. See Note 3.a for additional discussion of the Sabalo/Shad Acquisition and Working Interest Sale. c. Senior Secured Credit Facility On July 16, 2021, the Company entered into the Seventh Amendment (the "Seventh Amendment") to the Senior Secured Credit Facility. The Seventh Amendment, among other things, includes technical amendments (including in connection with Eurodollar advances), extends the maturity date by two years to July 16, 2025 (subject to a springing maturity date of July 29, 2024 if any of the January 2025 Notes are outstanding on such date), increases the applicable margins for advances made thereunder, increases certain commitment and letter of credit fees, revises certain exceptions to the limitations on the payment of distributions and the repayment of unsecured debt and decreases the leverage ratio for quarterly periods ending on and after September 30, 2021. On July 7, 2021, July 14, 2021 and August 4, 2021, the Company borrowed an additional $30.0 million, $55.0 million and $40.0 million, respectively, and on July 16, 2021 and July 26, 2021, the Company repaid $385.0 million and $50.0 million, respectively, on the Senior Secured Credit Facility. As a result, the outstanding balance under the Senior Secured Credit Facility was $70.0 million as of August 4, 2021. See Note 6.c for additional discussion of the Senior Secured Credit Facility. d. Commodity derivatives The following table summarizes open derivative positions as of June 30, 2021, updated for derivative transactions entered into from June 30, 2021 through August 3, 2021, for the settlement periods presented: Remaining Year 2021 Year 2022 Oil: WTI NYMEX - Swaps: Volume (Bbl) 612,000 365,000 Weighted-average price ($/Bbl) $ 69.46 $ 64.40 WTI NYMEX - Collars: Volume (Bbl) 153,000 3,394,500 Weighted-average floor price ($/Bbl) $ 63.00 $ 58.23 Weighted-average ceiling price ($/Bbl) $ 67.65 $ 69.39 Total WTI NYMEX: Total volume (Bbl) 765,000 3,759,500 Weighted-average floor price ($/Bbl) $ 68.16 $ 58.83 Weighted-average ceiling price ($/Bbl) $ 69.09 $ 68.91 Brent ICE - Swaps: Volume (Bbl) 3,781,200 4,124,500 Weighted-average price ($/Bbl) $ 51.29 $ 48.34 Brent ICE - Collars: Volume (Bbl) 662,400 1,551,250 Weighted-average floor price ($/Bbl) $ 55.00 $ 56.65 Weighted-average ceiling price ($/Bbl) $ 66.53 $ 65.44 Total Brent ICE: Total volume (Bbl) 4,443,600 5,675,750 Weighted-average floor price ($/Bbl) $ 51.84 $ 50.61 Weighted-average ceiling price ($/Bbl) $ 53.56 $ 53.01 NGL: Purity Ethane - Swaps: Volume (Bbl) 460,000 1,533,000 Weighted-average price ($/Bbl) $ 12.01 $ 11.42 Non-TET Propane - Swaps: Volume (Bbl) 1,221,576 1,168,000 Weighted-average price ($/Bbl) $ 22.90 $ 35.91 Non-TET Normal Butane - Swaps: Volume (Bbl) 407,192 365,000 Weighted-average price ($/Bbl) $ 25.87 $ 41.58 Non-TET Isobutane - Swaps: Volume (Bbl) 111,136 109,500 Weighted-average price ($/Bbl) $ 26.55 $ 42.00 Non-TET Natural Gasoline - Swaps: Volume (Bbl) 444,176 365,000 Weighted-average price ($/Bbl) $ 38.16 $ 60.65 Total NGL volume (Bbl) 2,644,080 3,540,500 CONTINUED ON NEXT PAGE Remaining Year 2021 Year 2022 Natural gas: Henry Hub NYMEX - Swaps: Volume (MMBtu) 21,436,000 3,650,000 Weighted-average price ($/MMBtu) $ 2.59 $ 2.73 Henry Hub NYMEX - Collars: Volume (MMBtu) — 18,250,000 Weighted-average floor price ($/MMBtu) $ — $ 3.00 Weighted-average ceiling price ($/MMBtu) $ — $ 3.31 Total Henry Hub NYMEX: Total volume with floor price (MMBtu) 21,436,000 21,900,000 Weighted-average floor price ($/MMBtu) $ 2.59 $ 2.96 Total volume with ceiling price (MMBtu) 21,436,000 21,900,000 Weighted-average ceiling price ($/MMBtu) $ 2.59 $ 3.22 Waha Inside FERC to Henry Hub NYMEX - Basis Swaps: Volume (MMBtu) 28,556,800 18,067,500 Weighted-average differential ($/MMBtu) $ (0.47) $ (0.41)

Organization and basis of pre_2

Organization and basis of presentation (Policies)	6 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Basis of presentation	Basis of presentation The unaudited consolidated financial statements were derived from the historical accounting records of the Company and reflect the historical financial position, results of operations and cash flows for the periods described herein. The unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All material intercompany transactions and account balances have been eliminated in the consolidation of accounts. The unaudited consolidated financial statements have not been audited by the Company's independent registered public accounting firm, except that the consolidated balance sheet as of December 31, 2020 is derived from the Company's audited consolidated financial statements. In the opinion of management, the unaudited consolidated financial statements reflect all necessary adjustments to present fairly the Company's financial position as of June 30, 2021, results of operations for the three and six months ended June 30, 2021 and 2020 and cash flows for the six months ended June 30, 2021 and 2020. Certain disclosures have been condensed or omitted from the unaudited consolidated financial statements. Accordingly, the unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the 2020 Annual Report.
Use of estimates in the preparation of interim unaudited consolidated financial statements	Use of estimates in the preparation of interim unaudited consolidated financial statements The preparation of the unaudited consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Although management believes these estimates are reasonable, actual results could differ. See Note 2.b in the 2020 Annual Report for further information regarding the use of estimates and assumptions.
New accounting standards	New accounting standards The Company considered the applicability and impact of all accounting standard updates ("ASU") issued by the Financial Accounting Standards Board to the Accounting Standards Codification ("ASC") and has determined there are no ASUs that are not yet adopted and meaningful to disclose as of June 30, 2021.
Full cost	The Company uses the full cost method of accounting for its oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain employee-related costs, incurred for the purpose of acquiring, exploring for or developing oil and natural gas properties, are capitalized and, once evaluated, depleted on a composite unit-of-production method based on estimates of proved oil, NGL and natural gas reserves. The depletion base includes estimated future development costs and dismantlement, restoration and abandonment costs, net of estimated salvage values. Capitalized costs include the cost of drilling and equipping productive wells, dry hole costs, lease acquisition costs, delay rentals and other costs related to such activities. Costs, including employee-related costs, associated with production and general corporate activities are expensed in the period incurred. The Company excludes unevaluated property acquisition costs and exploration costs from the depletion calculation until it is determined whether or not proved reserves can be assigned to the properties. The Company capitalizes a portion of its interest costs to its unevaluated properties and such costs become subject to depletion when proved reserves can be assigned to the associated properties. All items classified as unevaluated properties are assessed on a quarterly basis for possible impairment. The assessment includes consideration of the following factors, among others: intent to drill, remaining lease term, geological and geophysical evaluations, drilling results and activity, the assignment of proved reserves and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, the cumulative drilling incurred capital expenditures to date for such property and all or a portion of the associated leasehold costs are transferred to the full cost pool and are then subject to depletion. Sales of oil and natural gas properties, whether or not being depleted currently, are accounted for as adjustments of capitalized costs, with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil, NGL and natural gas.
Treasury stock	Treasury stock Treasury stock is recorded at cost, which includes incremental direct transaction costs, and is retired upon acquisition as a result of (i) stock exchanged to satisfy tax withholding that arises upon the lapse of restrictions on share-settled equity-based awards at the awardee's election or (ii) stock exchanged for the cost of exercise of stock options at the awardee's election.
Equity Incentive Plan	Equity Incentive Plan The Laredo Petroleum, Inc. Omnibus Equity Incentive Plan (the "Equity Incentive Plan") provides for the granting of incentive awards in the form of restricted stock awards, stock option awards, performance share awards, outperformance share awards, performance unit awards, phantom unit awards and other awards. On June 1, 2020, in connection with the effectiveness of the reverse stock split and Authorized Share Reduction, the board of directors approved and adopted an amendment to the Equity Incentive Plan to proportionately adjust the limitations on awards that may be granted under the Equity Incentive Plan. Following the amendment, an aggregate of 1,492,500 shares of common stock may be issued under the Equity Incentive Plan. See Note 7.b for additional discussion of the reverse stock split and Authorized Share Reduction. On May 20, 2021, the Company's stockholders approved an amendment to the Equity Incentive Plan to, among other things, increase the maximum number of shares of the Company's common stock issuable under the Equity Incentive Plan from 1,492,500 to 2,432,500 shares.
Net income (loss) per common share	Net loss per common share Basic and diluted net loss per common share are computed by dividing net loss by the weighted-average common shares outstanding for the period. Diluted net loss per common share reflects the potential dilution of non-vested restricted stock awards, outstanding stock option awards, non-vested performance share awards and the non-vested outperformance share award.
Revenue recognition	Revenue recognition Oil, NGL and natural gas sales and sales of purchased oil are generally recognized at the point in time that control of the product is transferred to the customer. Midstream service revenues are recognized over time as the customer benefits from these services when provided.

Organization and basis of pre_3

Organization and basis of presentation (Tables)	6 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Schedule of cash and cash equivalents	The following table presents the Company's cash, cash equivalents and restricted cash as of the dates presented: As of June 30, (in thousands) 2021 2020 Cash and cash equivalents $ 193,543 $ 15,747 Restricted cash (1) 71,441 — Total cash, cash equivalents and restricted cash $ 264,984 $ 15,747 _____________________________________________________________________________ (1) Under the terms of the Sabalo/Shad PSAs (defined below), the Company deposited into third-party escrow accounts an amount equal to $71.4 million, which is included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets as of June 30, 2021.
Schedule of restricted cash and restricted cash equivalents	The following table presents the Company's cash, cash equivalents and restricted cash as of the dates presented: As of June 30, (in thousands) 2021 2020 Cash and cash equivalents $ 193,543 $ 15,747 Restricted cash (1) 71,441 — Total cash, cash equivalents and restricted cash $ 264,984 $ 15,747 _____________________________________________________________________________ (1) Under the terms of the Sabalo/Shad PSAs (defined below), the Company deposited into third-party escrow accounts an amount equal to $71.4 million, which is included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets as of June 30, 2021.

Property and equipment (Tables)

Property and equipment (Tables)	6 Months Ended
	Jun. 30, 2021
Property, Plant and Equipment [Abstract]
Schedule of property and equipment	The following table presents the Company's property and equipment as of the dates presented: (in thousands) June 30, 2021 December 31, 2020 Evaluated oil and natural gas properties $ 8,053,975 $ 7,874,932 Less accumulated depletion and impairment (6,889,399) (6,817,949) Evaluated oil and natural gas properties, net 1,164,576 1,056,983 Unevaluated oil and natural gas properties not being depleted 62,248 70,020 Midstream service assets 183,079 181,718 Less accumulated depreciation and impairment (73,398) (69,021) Midstream service assets, net 109,681 112,697 Depreciable other fixed assets 38,210 37,454 Less accumulated depreciation and amortization (25,563) (24,344) Depreciable other fixed assets, net 12,647 13,110 Land 18,901 18,901 Total property and equipment, net $ 1,368,053 $ 1,271,711 The following table presents depletion expense, which is included in "Depletion, depreciation and amortization" on the unaudited consolidated statements of operations, and depletion expense per BOE sold of evaluated oil and natural gas properties for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands except per BOE data) 2021 2020 2021 2020 Depletion expense of evaluated oil and natural gas properties $ 36,650 $ 63,305 $ 71,375 $ 121,057 Depletion expense per BOE sold $ 4.69 $ 7.39 $ 4.78 $ 7.36 The following table presents full cost ceiling impairment expense, which is included in "Impairment expense" on the unaudited consolidated statements of operations for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Full cost ceiling impairment expense $ — $ 406,448 $ — $ 583,630
Schedule of costs incurred in the acquisition, exploration and development of oil and natural gas properties	The following table presents incurred capital expenditures in the acquisition, exploration and development of oil and natural gas properties, with asset retirement obligations included in evaluated property acquisition costs and development costs, for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Property acquisition costs: Evaluated $ — $ — $ — $ 7,586 Unevaluated — 912 — 16,468 Exploration costs 15,313 3,374 19,270 10,084 Development costs 87,509 72,567 152,001 218,725 Total oil and natural gas properties incurred capital expenditures $ 102,822 $ 76,853 $ 171,271 $ 252,863
Schedule of capitalized related employee costs incurred for the purpose of exploring for or developing oil and natural gas properties	The following table presents capitalized employee-related incurred capital expenditures in the acquisition, exploration and development of oil and natural gas properties for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Capitalized employee-related costs $ 4,848 $ 4,092 $ 9,089 $ 8,597
Schedule of benchmark prices and realized prices	The following table presents the Benchmark Prices and the Realized Prices as of the dates presented: June 30, 2021 March 31, 2021 December 31, 2020 September 30, 2020 Benchmark Prices: Oil ($/Bbl) $ 46.26 $ 36.49 $ 36.04 $ 39.88 NGL ($/Bbl) (1) $ 23.69 $ 19.24 $ 16.63 $ 16.95 Natural gas ($/MMBtu) $ 2.06 $ 1.69 $ 1.21 $ 1.06 Realized Prices: Oil ($/Bbl) $ 47.31 $ 38.28 $ 37.69 $ 41.08 NGL ($/Bbl) $ 14.01 $ 9.92 $ 7.43 $ 7.71 Natural gas ($/Mcf) $ 1.51 $ 1.20 $ 0.79 $ 0.68 _____________________________________________________________________________ (1) Based on the Company's average composite NGL barrel.

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2021
Debt Disclosure [Abstract]
Schedule of debt	The following table presents the Company's long-term debt and debt issuance costs, net included in "Long-term debt, net" on the unaudited consolidated balance sheets as of the dates presented: June 30, 2021 December 31, 2020 (in thousands) Long-term debt Debt issuance costs, net Long-term debt, net Long-term debt Debt issuance costs, net Long-term debt, net January 2025 Notes $ 577,913 $ (7,402) $ 570,511 $ 577,913 $ (8,676) $ 569,237 January 2028 Notes 361,044 (5,443) 355,601 361,044 (6,015) 355,029 Senior Secured Credit Facility (1) 380,000 — 380,000 255,000 — 255,000 Long-term debt, net $ 1,318,957 $ (12,845) $ 1,306,112 $ 1,193,957 $ (14,691) $ 1,179,266 ______________________________________________________________________________ (1) Debt issuance costs, net related to the Senior Secured Credit Facility of $3.2 million and $2.3 million as of June 30, 2021 and December 31, 2020, respectively, are included in "Other noncurrent assets, net" on the unaudited consolidated balance sheets.

Equity Incentive Plan (Tables)

Equity Incentive Plan (Tables)	6 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Schedule of restricted stock award activity	The following table reflects the restricted stock award activity for the six months ended June 30, 2021: (in thousands, except for weighted-average grant-date fair value) Restricted stock awards Weighted-average Outstanding as of December 31, 2020 309 $ 44.88 Granted 194 $ 36.04 Forfeited (41) $ 44.67 Vested (1) (125) $ 64.14 Outstanding as of June 30, 2021 337 $ 32.70 _____________________________________________________________________________
Schedule of performance unit and performance share awards activity	The following table reflects the performance share award activity for the six months ended June 30, 2021: (in thousands, except for weighted-average grant-date fair value) Performance share awards Weighted-average Outstanding as of December 31, 2020 97 $ 84.06 Forfeited (10) $ 74.70 Vested (1) (15) $ 184.43 Outstanding as of June 30, 2021 72 $ 64.78 ______________________________________________________________________________ (1) The performance share awards granted on February 16, 2018 had a performance period of January 1, 2018 to December 31, 2020 and, as their market and performance criteria were partially satisfied, resulted in a 43% payout. As such, the granted awards vested and were converted into 6,343 shares of the Company's common stock during the six months ended June 30, 2021 based on this 43% payout. The following table reflects the performance unit award activity for the six months ended June 30, 2021: (in thousands) Performance units Outstanding as of December 31, 2020 99 Granted 110 Outstanding as of June 30, 2021 209
Schedule of assumptions used to estimate fair value	The following table presents the assumptions used to estimate the fair value per performance unit for the performance unit awards granted in 2021: March 9, 2021 Remaining performance period 2.81 years Risk-free interest rate (1) 0.32 % Dividend yield — % Expected volatility (2) 114.60 % Closing stock price on grant date $ 34.66 ______________________________________________________________________________ (1) The remaining performance period matched zero-coupon risk-free interest rate was derived from the U.S. Treasury constant maturities yield curve on grant date. (2) The Company utilized its own remaining performance period matched historical volatility in order to develop the expected volatility.
Schedule of phantom unit award activity	The following table reflects the phantom unit award activity for the six months ended June 30, 2021: (in thousands) Phantom units Outstanding as of December 31, 2020 75 Granted 5 Forfeited (22) Vested (1) (25) Outstanding as of June 30, 2021 33 ______________________________________________________________________________
Schedule of allocated share-based compensation costs	The following table reflects equity-based compensation expense for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Equity awards: Restricted stock awards $ 1,857 $ 2,044 $ 3,820 $ 4,542 Performance share awards (129) 282 596 1,038 Outperformance share award 44 43 87 87 Stock option awards — 7 7 50 Total share-settled equity-based compensation, gross $ 1,772 $ 2,376 $ 4,510 $ 5,717 Less amounts capitalized (42) (682) (712) (1,647) Total share-settled equity-based compensation, net $ 1,730 $ 1,694 $ 3,798 $ 4,070 Liability awards: Performance unit awards $ 6,352 $ 166 $ 7,172 $ 190 Phantom unit awards 427 86 7 933 111 Total cash-settled equity-based compensation, gross $ 6,779 $ 252 $ 8,105 $ 301 Less amounts capitalized (95) (33) (293) (43) Total cash-settled equity-based compensation, net $ 6,684 $ 219 $ 7,812 $ 258 Total equity-based compensation, net $ 8,414 $ 1,913 $ 11,610 $ 4,328

Derivatives (Tables)

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of gain (loss) on derivatives	The following table summarizes components of the Company's gain (loss) on derivatives, net by type of derivative instrument for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2021 2020 2021 2020 Commodity $ (216,869) $ (90,864) $ (370,902) $ 200,497 Interest rate (30) (338) (26) (338) Contingent consideration (43) 665 (379) 7,140 Gain (loss) on derivatives, net $ (216,942) $ (90,537) $ (371,307) $ 207,299
Schedule of derivatives terminated	The following table presents the commodity derivatives that were terminated: Aggregate volumes (Bbl) Floor price ($/Bbl) Ceiling price ($/Bbl) Contract period WTI NYMEX - Collars 912,500 $ 45.00 $ 71.00 January 2021 - December 2021
Schedule of open positions and derivatives in place	The following table summarizes open commodity derivative positions as of June 30, 2021, for commodity derivatives that were entered into through June 30, 2021, for the settlement periods presented: Remaining Year 2021 (1) Year 2022 (1) Oil: WTI NYMEX - Collars: Volume (Bbl) — 1,204,500 Weighted-average floor price ($/Bbl) $ — $ 55.00 Weighted-average ceiling price ($/Bbl) $ — $ 74.35 Brent ICE - Swaps: Volume (Bbl) 3,781,200 4,124,500 Weighted-average price ($/Bbl) $ 51.29 $ 48.34 Brent ICE - Collars: Volume (Bbl) 662,400 1,551,250 Weighted-average floor price ($/Bbl) $ 55.00 $ 56.65 Weighted-average ceiling price ($/Bbl) $ 66.53 $ 65.44 Total Brent ICE: Total volume (Bbl) 4,443,600 5,675,750 Weighted-average floor price ($/Bbl) $ 51.84 $ 50.61 Weighted-average ceiling price ($/Bbl) $ 53.56 $ 53.01 NGL: Mont Belvieu OPIS: Purity Ethane - Swaps: Volume (Bbl) 460,000 — Weighted-average price ($/Bbl) $ 12.01 $ — Non-TET Propane - Swaps: Volume (Bbl) 1,221,576 — Weighted-average price ($/Bbl) $ 22.90 $ — Non-TET Normal Butane - Swaps: Volume (Bbl) 407,192 — Weighted-average price ($/Bbl) $ 25.87 $ — Non-TET Isobutane - Swaps: Volume (Bbl) 111,136 — Weighted-average price ($/Bbl) $ 26.55 $ — Non-TET Natural Gasoline - Swaps: Volume (Bbl) 444,176 — Weighted-average price ($/Bbl) $ 38.16 $ — Total NGL volume (Bbl) 2,644,080 — Natural gas: Henry Hub NYMEX - Swaps: Volume (MMBtu) 21,436,000 3,650,000 Weighted-average price ($/MMBtu) $ 2.59 $ 2.73 Waha Inside FERC to Henry Hub NYMEX - Basis Swaps: Volume (MMBtu) 28,556,800 18,067,500 Weighted-average differential ($/MMBtu) $ (0.47) $ (0.41) ______________________________________________________________________________ (1) Does not include derivative positions entered into on behalf of Sixth Street, which were novated upon closing of the Working Interest Sale subsequent to June 30, 2021. During the three months ended June 30, 2021, in connection with the Working Interest Sale, the Company entered into derivative positions on behalf of Sixth Street. These derivatives are included in the Company's mark-to-market hedge position as of June 30, 2021 and were subsequently novated to Sixth Street upon the closing of the Working Interest Sale. The following table summarizes the commodity derivative positions entered into on behalf of Sixth Street as of June 30, 2021, for commodity derivatives that were entered into through June 30, 2021, for the settlement periods presented: Remaining Year 2021 Year 2022 Year 2023 Year 2024 Year 2025 Oil: WTI NYMEX - Swaps: Volume (Bbl) 786,242 1,280,111 1,017,720 847,480 730,509 Weighted-average price ($/Bbl) $ 63.38 $ 59.79 $ 56.70 $ 54.70 $ 53.52 WTI Midland to WTI Nymex - Basis Swaps: Volume (Bbl) 786,242 1,280,111 1,017,720 — 730,509 Weighted-average differential ($/Bbl) $ 0.24 $ 0.50 $ 0.50 $ — $ 0.40 NGL: Mont Belvieu OPIS: Purity Ethane - Swaps: Volume (Bbl) 356,327 629,123 280,362 — — Weighted-average price ($/Bbl) $ 10.50 $ 9.56 $ 8.87 $ — $ — Non-TET Propane - Swaps: Volume (Bbl) 267,245 471,841 210,271 — — Weighted-average price ($/Bbl) $ 33.60 $ 28.19 $ 24.89 $ — $ — Non-TET Normal Butane - Swaps: Volume (Bbl) 80,983 142,983 63,719 — — Weighted-average price ($/Bbl) $ 37.70 $ 31.55 $ 27.77 $ — $ — Non-TET Isobutane - Swaps: Volume (Bbl) 24,295 42,897 19,116 — — Weighted-average price ($/Bbl) $ 37.54 $ 31.45 $ 27.67 $ — $ — Non-TET Natural Gasoline - Swaps: Volume (Bbl) 80,983 142,983 63,719 — — Weighted-average price ($/Bbl) $ 58.38 $ 52.92 $ 48.20 $ — $ — Total NGL volume (Bbl) 809,833 1,429,827 637,187 — — Natural gas: Henry Hub NYMEX - Swaps: Volume (MMBtu) 9,219,072 16,276,973 14,038,618 12,385,310 11,112,681 Weighted-average price ($/MMBtu) $ 3.00 $ 2.73 $ 2.56 $ 2.55 $ 2.57 Waha Inside FERC to Henry Hub NYMEX - Basis Swaps: Volume (MMBtu) 9,219,072 16,276,973 14,038,618 12,385,310 — Weighted-average differential ($/MMBtu) $ (0.04) $ (0.26) $ (0.41) $ (0.42) $ — The following table summarizes the Company's interest rate derivative: Notional amount Fixed rate Contract period LIBOR - Swap $ 100,000 0.345 % April 16, 2020 - April 18, 2022

Fair value measurements (Tables

Fair value measurements (Tables)	6 Months Ended
	Jun. 30, 2021
Fair Value Disclosures [Abstract]
Schedule of fair value hierarchy for assets and liabilities measured at fair value on a recurring basis	The following tables present the Company's derivatives by (i) balance sheet classification, (ii) derivative type and (iii) fair value hierarchy level, and provide a total, on a gross basis and a net basis reflected in "Derivatives" on the unaudited consolidated balance sheets as of the dates presented: June 30, 2021 (in thousands) Level 1 Level 2 Level 3 Total gross fair value Amounts offset Net fair value presented on the unaudited consolidated balance sheets Assets: Current: Commodity - Oil $ — $ 5,993 $ — $ 5,993 $ (5,993) $ — Commodity - NGL — 27 — 27 (27) — Commodity - Natural gas — 1,650 — 1,650 (1,650) — Noncurrent: Commodity - Oil $ — $ 6,678 $ — $ 6,678 $ (6,255) $ 423 Commodity - NGL — — — — — — Commodity - Natural gas — 6,542 — 6,542 (6,542) — Liabilities: Current: Commodity - Oil $ — $ (150,865) $ — $ (150,865) $ 5,993 $ (144,872) Commodity - NGL — (65,171) — (65,171) 27 (65,144) Commodity - Natural gas — (46,756) — (46,756) 1,650 (45,106) Interest rate - LIBOR — (179) — (179) — (179) Contingent consideration — (1,159) — (1,159) — (1,159) Noncurrent: Commodity - Oil $ — $ (57,774) $ — $ (57,774) $ 6,255 $ (51,519) Commodity - NGL — (6,087) — (6,087) — (6,087) Commodity - Natural gas — (10,450) — (10,450) 6,542 (3,908) Interest rate - LIBOR — — — — — — Contingent consideration — — — — — — Net derivative liability positions $ — $ (317,551) $ — $ (317,551) $ — $ (317,551) December 31, 2020 (in thousands) Level 1 Level 2 Level 3 Total gross fair value Amounts offset Net fair value presented on the Assets: Current: Commodity - Oil $ — $ 32,958 $ — $ 32,958 $ (24,930) $ 8,028 Commodity - NGL — 2,720 — 2,720 (2,720) — Commodity - Natural gas — 521 — 521 (656) (135) Noncurrent: Commodity - Oil $ — $ — $ — $ — $ — $ — Commodity - NGL — — — — — — Commodity - Natural gas — 535 — 535 (535) — Liabilities: Current: Commodity - Oil $ — $ (25,118) $ — $ (25,118) $ 24,930 $ (188) Commodity - NGL — (16,185) — (16,185) 2,720 (13,465) Commodity - Natural gas — (17,958) — (17,958) 656 (17,302) Interest rate - LIBOR — (206) — (206) — (206) Contingent consideration — (665) — (665) — (665) Noncurrent: Commodity - Oil $ — $ (10,932) $ — $ (10,932) $ — $ (10,932) Commodity - NGL — — — — — — Commodity - Natural gas — (1,476) — (1,476) 535 (941) Interest rate - LIBOR — (63) — (63) — (63) Contingent consideration — (115) — (115) — (115) Net derivative liability positions $ — $ (35,984) $ — $ (35,984) $ — $ (35,984)
Schedule of carrying amount and fair value of debt instruments	The Company has not elected to account for its debt instruments at fair value. The following table presents the carrying amounts and fair values of the Company's debt as of the dates presented: June 30, 2021 December 31, 2020 (in thousands) Long-term Fair value (1) Long-term Fair value (1) January 2025 Notes $ 577,913 $ 608,953 $ 577,913 $ 499,299 January 2028 Notes 361,044 396,607 361,044 299,667 Senior Secured Credit Facility 380,000 380,611 255,000 255,187 Total $ 1,318,957 $ 1,386,171 $ 1,193,957 $ 1,054,153 ______________________________________________________________________________ (1) The fair values of the outstanding notes were determined using the Level 1 fair value hierarchy quoted market prices for each respective instrument as of June 30, 2021 and December 31, 2020. The fair values of the outstanding debt under the Senior Secured Credit Facility were estimated utilizing the Level 2 fair value hierarchy pricing model for similar instruments as of June 30, 2021 and December 31, 2020.

Net loss per common share (Tabl

Net loss per common share (Tables)	6 Months Ended
	Jun. 30, 2021
Earnings Per Share [Abstract]
Schedule of calculation of basic and diluted weighted-average common shares outstanding and net loss per common share	The following table reflects the calculations of basic and diluted (i) weighted-average common shares outstanding and (ii) net loss per common share for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands, except for per share data) 2021 2020 2021 2020 Net loss (numerator) $ (132,661) $ (545,455) $ (208,100) $ (470,809) Weighted-average common shares outstanding (denominator): Basic 12,674 11,667 12,298 11,642 Diluted 12,674 11,667 12,298 11,642 Net loss per common share: Basic $ (10.47) $ (46.75) $ (16.92) $ (40.44) Diluted $ (10.47) $ (46.75) $ (16.92) $ (40.44)

Supplemental cash flow and no_2

Supplemental cash flow and non-cash information (Tables)	6 Months Ended
	Jun. 30, 2021
Supplemental Cash Flow Elements [Abstract]
Schedule of non-cash investing & financing and supplemental cash flow information	The following table presents supplemental cash flow and non-cash information for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Supplemental cash flow information: Cash paid for interest, net of $890 and $1,822 of capitalized interest, respectively $ 49,966 $ 25,595 Supplemental non-cash investing information: Fair value of contingent consideration on acquisition date (1) $ — $ 225 Change in accrued capital expenditures $ 4,366 $ (15,024) Capitalized share-settled equity-based compensation $ 712 $ 1,647 Capitalized asset retirement cost $ 730 $ 1,082 _____________________________________________________________________________ (1) See Notes 3.b and 9.c for discussion of the Company's 2020 acquisition of oil and natural gas properties that includes contingent consideration. See Note 10.a for discussion of the quarterly remeasurement of this contingent consideration. The following table presents supplemental non-cash adjustments information related to operating leases for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Right-of-use assets obtained in exchange for operating lease liabilities (1) $ 7,532 $ 2,349 _____________________________________________________________________________ (1) See Note 4 for additional discussion of the Company's leases.

Asset retirement obligations (T

Asset retirement obligations (Tables)	6 Months Ended
	Jun. 30, 2021
Asset Retirement Obligation Disclosure [Abstract]
Schedule of asset retirement obligation liability	The following table reconciles the Company's asset retirement obligation liability associated with tangible long-lived assets for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Liability at beginning of period $ 68,326 $ 62,718 Liabilities added due to acquisitions, drilling, midstream service asset construction and other 730 1,082 Accretion expense (1) 2,301 2,223 Liabilities settled due to plugging and abandonment or removed due to sale (150) (778) Liability at end of period $ 71,206 $ 65,245 _____________________________________________________________________________ (1) Accretion expense is included in "Other operating expenses" on the unaudited consolidated statements of operations.

Related parties (Tables)

Related parties (Tables)	6 Months Ended
	Jun. 30, 2021
Related Party Transactions [Abstract]
Schedule of related party transactions	The following table presents the capital expenditures for oil and natural gas properties paid to Halliburton included in the unaudited consolidated statements of cash flows for the periods presented: Six months ended June 30, (in thousands) 2021 2020 Capital expenditures for oil and natural gas properties $ 25,657 $ 18,104

Subsequent events (Tables)

Subsequent events (Tables)	6 Months Ended
	Jun. 30, 2021
Subsequent Events [Abstract]
Schedule of subsequent events	The following table summarizes open derivative positions as of June 30, 2021, updated for derivative transactions entered into from June 30, 2021 through August 3, 2021, for the settlement periods presented: Remaining Year 2021 Year 2022 Oil: WTI NYMEX - Swaps: Volume (Bbl) 612,000 365,000 Weighted-average price ($/Bbl) $ 69.46 $ 64.40 WTI NYMEX - Collars: Volume (Bbl) 153,000 3,394,500 Weighted-average floor price ($/Bbl) $ 63.00 $ 58.23 Weighted-average ceiling price ($/Bbl) $ 67.65 $ 69.39 Total WTI NYMEX: Total volume (Bbl) 765,000 3,759,500 Weighted-average floor price ($/Bbl) $ 68.16 $ 58.83 Weighted-average ceiling price ($/Bbl) $ 69.09 $ 68.91 Brent ICE - Swaps: Volume (Bbl) 3,781,200 4,124,500 Weighted-average price ($/Bbl) $ 51.29 $ 48.34 Brent ICE - Collars: Volume (Bbl) 662,400 1,551,250 Weighted-average floor price ($/Bbl) $ 55.00 $ 56.65 Weighted-average ceiling price ($/Bbl) $ 66.53 $ 65.44 Total Brent ICE: Total volume (Bbl) 4,443,600 5,675,750 Weighted-average floor price ($/Bbl) $ 51.84 $ 50.61 Weighted-average ceiling price ($/Bbl) $ 53.56 $ 53.01 NGL: Purity Ethane - Swaps: Volume (Bbl) 460,000 1,533,000 Weighted-average price ($/Bbl) $ 12.01 $ 11.42 Non-TET Propane - Swaps: Volume (Bbl) 1,221,576 1,168,000 Weighted-average price ($/Bbl) $ 22.90 $ 35.91 Non-TET Normal Butane - Swaps: Volume (Bbl) 407,192 365,000 Weighted-average price ($/Bbl) $ 25.87 $ 41.58 Non-TET Isobutane - Swaps: Volume (Bbl) 111,136 109,500 Weighted-average price ($/Bbl) $ 26.55 $ 42.00 Non-TET Natural Gasoline - Swaps: Volume (Bbl) 444,176 365,000 Weighted-average price ($/Bbl) $ 38.16 $ 60.65 Total NGL volume (Bbl) 2,644,080 3,540,500 CONTINUED ON NEXT PAGE Remaining Year 2021 Year 2022 Natural gas: Henry Hub NYMEX - Swaps: Volume (MMBtu) 21,436,000 3,650,000 Weighted-average price ($/MMBtu) $ 2.59 $ 2.73 Henry Hub NYMEX - Collars: Volume (MMBtu) — 18,250,000 Weighted-average floor price ($/MMBtu) $ — $ 3.00 Weighted-average ceiling price ($/MMBtu) $ — $ 3.31 Total Henry Hub NYMEX: Total volume with floor price (MMBtu) 21,436,000 21,900,000 Weighted-average floor price ($/MMBtu) $ 2.59 $ 2.96 Total volume with ceiling price (MMBtu) 21,436,000 21,900,000 Weighted-average ceiling price ($/MMBtu) $ 2.59 $ 3.22 Waha Inside FERC to Henry Hub NYMEX - Basis Swaps: Volume (MMBtu) 28,556,800 18,067,500 Weighted-average differential ($/MMBtu) $ (0.47) $ (0.41)

Organization and basis of pre_4

Organization and basis of presentation - Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Thousands	Jun. 30, 2021		Dec. 31, 2020	Jun. 30, 2020		Dec. 31, 2019
Asset Acquisition [Line Items]
Cash and cash equivalents	$ 193,543		$ 48,757	$ 15,747
Restricted cash	71,441			0
Total cash, cash equivalents and restricted cash	264,984	[1]	$ 48,757	$ 15,747	[1]	$ 40,857
Other Noncurrent Assets
Asset Acquisition [Line Items]
Escrow deposit	$ 71,400
[1]	See Note 1 for further discussion of the Company's cash, cash equivalents and restricted cash.

Organization and basis of pre_5

Organization and basis of presentation - Narrative (Details)	6 Months Ended
	Jun. 30, 2021operating_segment
Accounting Policies [Abstract]
Number of operating segments	1

Acquisitions and divestitures (

Acquisitions and divestitures (Details) $ / shares in Units, $ in Thousands	Jun. 30, 2021USD ($)$ / shares	May 07, 2021USD ($)shares	Apr. 30, 2020USD ($)a	Apr. 09, 2020USD ($)awell	Feb. 04, 2020USD ($)a	Nov. 16, 2020USD ($)aBoe	Jun. 30, 2021USD ($)$ / shares	Jun. 30, 2020USD ($)	Jun. 30, 2021USD ($)$ / shares	Jun. 30, 2020USD ($)	Dec. 31, 2022USD ($)	May 06, 2021	Feb. 23, 2021$ / shares	Dec. 31, 2020$ / shares	Oct. 16, 2020a	Jun. 01, 2020$ / shares
Asset Acquisition [Line Items]
Common stock par value (in USD per share) | $ / shares	$ 0.01						$ 0.01		$ 0.01				$ 0.01	$ 0.01		$ 0.01
Average working interest (as a percent)	97.00%						97.00%		97.00%
Transaction costs associated with disposition							$ 1,741	$ 0	$ 1,741	$ 0
Other Noncurrent Assets
Asset Acquisition [Line Items]
Escrow deposit	$ 71,400						71,400		71,400
Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Asset Acquisition [Line Items]
Proceeds from dispositions after transaction costs		$ 405,000
Average working interest (as a percent)		37.50%
Transaction costs associated with disposition							1,700
Balloon payment of additional cash contingent consideration		$ 55,000
Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Minimum
Asset Acquisition [Line Items]
Pre-acquisition reserves (as a percent)												25.00%
Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Maximum
Asset Acquisition [Line Items]
Additional cash contingent consideration		93,700
Aggregate quarterly payments of additional cash contingent consideration		38,700
Howard County Net Acres | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Asset Acquisition [Line Items]
Area of land (in acres) | a					80
Glasscock County Net Acres | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Asset Acquisition [Line Items]
Proceeds from dispositions after transaction costs				$ 700
Area of land (in acres) | a				80
Number of producing wells sold | well				2
Sabalo/Shad
Asset Acquisition [Line Items]
Consideration transferred in acquisition		864,300
Payments to acquire productive assets		$ 624,300
Stock issued in asset acquisition (shares) | shares		2,506,964
Sabalo/Shad | Other Noncurrent Assets
Asset Acquisition [Line Items]
Escrow deposit	71,400						$ 71,400		$ 71,400
Consideration transferred, transaction cost	$ 3,900
Acquired Evaluated and Unevaluated Oil and Natural Gas Properties in Howard County, Texas
Asset Acquisition [Line Items]
Production reserve (BOE per day) | Boe						210
Howard County Net Acres
Asset Acquisition [Line Items]
Consideration transferred in acquisition			$ 600		$ 22,500	$ 11,600
Area of land (in acres) | a			180		1,180	80									2,758
Fair value of contingent consideration			$ 200
Howard County Net Acres | Forecast | WTI NYMEX | Not Designated as Hedges | Oil put January 2021 - December 2022 | Crude Oil
Asset Acquisition [Line Items]
Notional amount of derivative											$ 1,200

Leases (Details)

Leases (Details)	Jun. 30, 2021
Leases [Abstract]
Average working interest (as a percent)	97.00%

Property and equipment - Compan

Property and equipment - Company Property and Equipment (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Evaluated oil and natural gas properties	$ 8,053,975	$ 7,874,932
Less accumulated depletion and impairment	(6,889,399)	(6,817,949)
Evaluated oil and natural gas properties, net	1,164,576	1,056,983
Unevaluated oil and natural gas properties not being depleted	62,248	70,020
Midstream service assets, net	109,681	112,697
Depreciable other fixed assets, net	31,548	32,011
Property and equipment, net	1,368,053	1,271,711
Midstream service assets
Property, Plant and Equipment [Line Items]
Midstream service assets	183,079	181,718
Less accumulated depreciation and impairment	(73,398)	(69,021)
Depreciable other fixed assets
Property, Plant and Equipment [Line Items]
Less accumulated depreciation and impairment	(25,563)	(24,344)
Depreciable other fixed assets	38,210	37,454
Depreciable other fixed assets, net	12,647	13,110
Land
Property, Plant and Equipment [Line Items]
Depreciable other fixed assets, net	$ 18,901	$ 18,901

Property and equipment - Costs

Property and equipment - Costs Incurred in the Acquisition, Exploration and Development of Oil and Natural Gas Properties (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Property acquisition costs:
Evaluated	$ 0	$ 0	$ 0	$ 7,586
Unevaluated	0	912	0	16,468
Exploration costs	15,313	3,374	19,270	10,084
Development costs	87,509	72,567	152,001	218,725
Total oil and natural gas properties incurred capital expenditures	$ 102,822	$ 76,853	$ 171,271	$ 252,863

Property and equipment - Other

Property and equipment - Other Property and Equipment Information (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021USD ($)$ / Boe	Jun. 30, 2020USD ($)$ / Boe	Jun. 30, 2021USD ($)$ / Boe	Jun. 30, 2020USD ($)$ / Boe
Property, Plant and Equipment [Abstract]
Capitalized employee-related costs	$ 4,848	$ 4,092	$ 9,089	$ 8,597
Depletion expense of evaluated oil and natural gas properties	$ 36,650	$ 63,305	$ 71,375	$ 121,057
Depletion expense (in USD per BOE) | $ / Boe	4.69	7.39	4.78	7.36
Discount rate used in calculating full cost ceiling (as a percent)			10.00%

Property and equipment - Benchm

Property and equipment - Benchmark Prices and Realized Prices (Details)	3 Months Ended
	Jun. 30, 2021$ / MMBTU$ / MMcf$ / bbl	Mar. 31, 2021$ / bbl$ / MMBTU$ / MMcf	Dec. 31, 2020$ / MMBTU$ / bbl$ / MMcf	Sep. 30, 2020$ / MMBTU$ / bbl$ / MMcf
Oil ($/Bbl)
Property, Plant and Equipment [Line Items]
Benchmark Prices (in USD per unit)	46.26	36.49	36.04	39.88
Realized Prices (in USD per unit)	47.31	38.28	37.69	41.08
NGL ($/Bbl)
Property, Plant and Equipment [Line Items]
Benchmark Prices (in USD per unit)	23.69	19.24	16.63	16.95
Realized Prices (in USD per unit)	14.01	9.92	7.43	7.71
Natural gas ($/MMBtu/Mcf)
Property, Plant and Equipment [Line Items]
Benchmark Prices (in USD per unit) | $ / MMBTU	2.06	1.69	1.21	1.06
Realized Prices (in USD per unit) | $ / MMcf	1.51	1.20	0.79	0.68

Property and equipment - Full C

Property and equipment - Full Cost Ceiling Impairment (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Property, Plant and Equipment [Abstract]
Full cost ceiling impairment expense	$ 0	$ 406,448	$ 0	$ 583,630

Debt - January 2025 and 2028 No

Debt - January 2025 and 2028 Notes (Details) - USD ($)	Jan. 24, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020	Nov. 30, 2020
Debt Instrument [Line Items]
Authorized amount of bond repurchase program					$ 50,000,000
Extinguishment of debt		$ 0	$ 808,855,000
Gain on extinguishment of debt		$ 0	$ (13,320,000)
Senior Notes
Debt Instrument [Line Items]
Proceeds from senior notes	$ 982,000,000
Senior Notes | January 2025 Notes
Debt Instrument [Line Items]
Face amount of debt	$ 600,000,000
Interest rate (as a percent)	9.50%
Repurchased aggregate principal amount				$ 22,100,000
Extinguishment of debt				13,900,000
Senior Notes | January 2028 Notes
Debt Instrument [Line Items]
Face amount of debt	$ 400,000,000
Interest rate (as a percent)	10.125%
Repurchased aggregate principal amount				39,000,000
Extinguishment of debt				24,200,000
Senior Notes | Senior Note 9.500 Percent Due 2025 & Senior Note 10.125 Percent Due 2028
Debt Instrument [Line Items]
Gain on extinguishment of debt				$ 22,300,000

Debt - January 2022 and March 2

Debt - January 2022 and March 2023 Notes (Details) - USD ($)	Mar. 15, 2020	Feb. 06, 2020	Jan. 29, 2020	Jan. 24, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020	Mar. 18, 2015	Jan. 23, 2014
Debt Instrument [Line Items]
Outstanding debt					$ 1,306,112,000		$ 1,179,266,000
Extinguishment of debt					0	$ 808,855,000
Loss on extinguishment of debt					0	$ (13,320,000)
Senior Notes | January 2022 Notes and March 2023 Notes
Debt Instrument [Line Items]
Loss on extinguishment of debt					$ (13,300,000)
Senior Notes | January 2022 Notes
Debt Instrument [Line Items]
Face amount of debt									$ 450,000,000
Interest rate (as a percent)									5.625%
Outstanding debt				$ 428,900,000
Extinguishment of debt			$ 21,100,000	$ 431,600,000
Debt call price (as a percent)			100.00%
Senior Notes | March 2023 Notes
Debt Instrument [Line Items]
Face amount of debt								$ 350,000,000
Interest rate (as a percent)								6.25%
Outstanding debt		$ 299,400,000
Extinguishment of debt	$ 50,600,000	$ 304,100,000
Debt call price (as a percent)	101.563%

Debt - Senior Secured Credit Fa

Debt - Senior Secured Credit Facility (Details) - Secured Debt - USD ($)	Jun. 30, 2021	May 07, 2021	Dec. 31, 2020
Senior Secured Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 2,000,000,000
Current borrowing capacity	725,000,000	$ 725,000,000
Amount outstanding	$ 380,000,000
Credit facility, interest rate at period end (as a percent)	3.658%
Letter of Credit
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 80,000,000
Letters of credit outstanding	$ 44,100,000		$ 44,100,000

Debt - Debt Issuance Costs (Det

Debt - Debt Issuance Costs (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Debt Disclosure [Abstract]
Debt issuance costs capitalized	$ 1,500,000	$ 18,400,000	$ 1,500,000	$ 18,400,000
Write-off of debt issuance costs	0	$ 1,103,000	0	$ 1,103,000
Total debt issuance costs, including line of credit	16,000,000		16,000,000		$ 17,000,000
Accumulated amortization	$ 24,200,000		$ 24,200,000		$ 22,100,000

Debt - Long-term Debt, Net (Det

Debt - Long-term Debt, Net (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Long-term debt	$ 1,318,957	$ 1,193,957
Debt issuance costs, net	(12,845)	(14,691)
Long-term debt, net	1,306,112	1,179,266
Senior Notes | January 2025 Notes
Debt Instrument [Line Items]
Long-term debt	577,913	577,913
Debt issuance costs, net	(7,402)	(8,676)
Long-term debt, net	570,511	569,237
Senior Notes | January 2028 Notes
Debt Instrument [Line Items]
Long-term debt	361,044	361,044
Debt issuance costs, net	(5,443)	(6,015)
Long-term debt, net	355,601	355,029
Secured Debt | Senior Secured Credit Facility
Debt Instrument [Line Items]
Long-term debt	380,000	255,000
Debt issuance costs, net	0	0
Long-term debt, net	380,000	255,000
Secured Debt | Senior Secured Credit Facility | Other Noncurrent Assets
Debt Instrument [Line Items]
Debt issuance costs related to line of credit arrangements	$ 3,200	$ 2,300

Stockholders' equity (Details)

Stockholders' equity (Details) $ / shares in Units, $ in Millions	Feb. 23, 2021USD ($)$ / shares	Jun. 01, 2020$ / sharesshares	Jun. 30, 2021USD ($)$ / sharesshares	Dec. 31, 2020$ / sharesshares	May 31, 2020shares
Class of Stock [Line Items]
Common stock par value (in USD per share) | $ / shares	$ 0.01	$ 0.01	$ 0.01	$ 0.01
Conversation ratio of reverse stock split		0.05
Common stock authorized (in shares)		22,500,000	22,500,000	22,500,000	450,000,000
Preferred stock authorized (in shares)		50,000,000	50,000,000	50,000,000
Preferred stock par value (in USD per share) | $ / shares		$ 0.01	$ 0.01	$ 0.01
Capital stock authorized (shares)		72,500,000
At-the-Market Offering
Class of Stock [Line Items]
Consideration received from sale of stock | $			$ 72.5
Stock issued in sale (in shares)			1,438,105
At-the-Market Offering | Maximum
Class of Stock [Line Items]
Consideration received from sale of stock | $	$ 75

Equity Incentive Plan - Equity

Equity Incentive Plan - Equity Incentive Plan (Details) - Equity Incentive Plan - shares	May 20, 2021	Jun. 01, 2020
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock authorized for issuance (in shares)	1,492,500	1,492,500
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock authorized for issuance (in shares)	2,432,500

Equity Incentive Plan - Restric

Equity Incentive Plan - Restricted Stock Awards (Details) - Restricted stock awards $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation not yet recognized	$ 8.8
Recognition period for costs not yet recognized	1 year 11 months 12 days
Vesting Alternative One, One Year from Grant Date
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate (as a percent)	33.00%
Vesting Alternative One, Two Years from Grant Date
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate (as a percent)	33.00%
Vesting Alternative One, Three Years from Grant Date
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate (as a percent)	34.00%

Equity Incentive Plan - Restr_2

Equity Incentive Plan - Restricted Stock Award Activity (Details) - Restricted stock awards $ / shares in Units, shares in Thousands, $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)$ / sharesshares
Restricted stock awards
Outstanding at the beginning of the period (in shares) | shares	309
Granted (in shares) | shares	194
Forfeited (in shares) | shares	(41)
Vested (in shares) | shares	(125)
Outstanding at the end of the period (in shares) | shares	337
Weighted-average grant-date fair value (per share)
Outstanding at the beginning of the period (in USD per share) | $ / shares	$ 44.88
Granted (in USD per share) | $ / shares	36.04
Forfeited (in USD per share) | $ / shares	44.67
Vested (in USD per share) | $ / shares	64.14
Outstanding at the end of the period (in USD per share) | $ / shares	$ 32.70
Equity instruments other than options, aggregate intrinsic value, vested | $	$ 4.9

Equity Incentive Plan - Stock O

Equity Incentive Plan - Stock Option Awards (Details) - Stock Option Awards	6 Months Ended
	Jun. 30, 2021$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding (in shares) | shares	11,362
Weighted-average exercise price of options outstanding (in USD per share) | $ / shares	$ 257.42
Weighted-average remaining contractual term of options outstanding	3 years 3 months 14 days

Equity Incentive Plan - Perform

Equity Incentive Plan - Performance Share Awards (Details) - Performance Share Awards - USD ($) $ / shares in Units, $ in Millions	Feb. 28, 2019	Feb. 16, 2018	Jun. 30, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Requisite service period of the awards	3 years	3 years
Stock-based compensation not yet recognized			$ 1.4
Recognition period for costs not yet recognized			8 months 1 day
Combined expense per award (in USD per share)			$ 86.64
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout range (as a percent)			0.00%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout range (as a percent)			200.00%

Equity Incentive Plan - Perfo_2

Equity Incentive Plan - Performance Share Award Activity (Details) - Performance Share Awards - $ / shares	6 Months Ended	36 Months Ended
	Jun. 30, 2021	Dec. 31, 2020
Performance unit/share awards
Outstanding at the beginning of the period (in shares)	97,000
Forfeited (in shares)	(10,000)
Vested (in shares)	(15,000)
Outstanding at the end of the period (in shares)	72,000	97,000
Weighted-average grant-date fair value (per award)
Outstanding at the beginning of the period (in USD per share)	$ 84.06
Forfeited (in USD per share)	74.70
Vested (in USD per share)	184.43
Outstanding at the end of the period (in USD per share)	$ 64.78	$ 84.06
Actual payout (as a percent)		43.00%
Performance share conversion (in shares)	6,343

Equity Incentive Plan - Outperf

Equity Incentive Plan - Outperformance Share Awards (Details) - Outperformance Share Awards $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Threshold consecutive trading days	50 days
Stock-based compensation not yet recognized | $	$ 0.3
Recognition period for costs not yet recognized	2 years 1 month 20 days
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outperformance payout range (in shares)	0
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outperformance payout range (in shares)	50,000

Equity Incentive Plan - Perfo_3

Equity Incentive Plan - Performance Unit Awards (Details) - Performance Unit Awards $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)$ / shares
March 5, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Requisite service period of the awards	3 years
Combined expense per award (in USD per share)	$ 145.77
March 5, 2020 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout range (as a percent)	0.00%
March 5, 2020 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout range (as a percent)	200.00%
Payout range if ATSR Appreciation is zero or less (as a percent)	100.00%
March 9, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation not yet recognized | $	$ 21.5
Recognition period for costs not yet recognized	2 years 3 months 21 days
Combined expense per award (in USD per share)	$ 135.58
March 9, 2021 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout rate of market criteria awards (as a percent)	0.00%
Payout rate of performance criteria awards (as a percent)	0.00%
March 9, 2021 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout rate of market criteria awards (as a percent)	250.00%
Payout rate of performance criteria awards (as a percent)	200.00%

Equity Incentive Plan - Assumpt

Equity Incentive Plan - Assumptions Used to Estimate Fair Value of Performance Unit Awards (Details) - $ / shares	6 Months Ended
	Jun. 30, 2021	Mar. 05, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Closing stock price (in USD per share)		$ 34.24
Performance Unit Awards | March 9, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining performance period	2 years 9 months 21 days
Risk-free interest rate (as a percent)	0.32%
Dividend yield (as a percent)	0.00%
Expected volatility (as a percent)	114.60%
Closing stock price (in USD per share)	$ 34.66

Equity Incentive Plan - Perfo_4

Equity Incentive Plan - Performance Unit Award Activity (Details) - Performance Unit Awards	6 Months Ended
	Jun. 30, 2021shares
Performance unit/share awards
Outstanding at the beginning of the period (in shares)	99,000
Granted (in shares)	110,000
Outstanding at the end of the period (in shares)	209,000

Equity Incentive Plan - Phantom

Equity Incentive Plan - Phantom Unit Aawards (Details) - Phantom Unit Awards $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)
Awarded in 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation not yet recognized	$ 2.6
Recognition period for costs not yet recognized	1 year 9 months 25 days
Vesting Alternative One, One Year from Grant Date
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate (as a percent)	33.00%
Vesting Alternative One, Two Years from Grant Date
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate (as a percent)	33.00%
Vesting Alternative One, Three Years from Grant Date
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate (as a percent)	34.00%

Equity Incentive Plan - Phant_2

Equity Incentive Plan - Phantom Unit Award Activity (Details) - $ / shares shares in Thousands	6 Months Ended
	Jun. 30, 2021	Mar. 05, 2021
Phantom units
Stock price (in USD per share)		$ 34.24
Phantom Unit Awards
Phantom units
Outstanding at the beginning of the period (in shares)	75
Granted (in shares)	5
Forfeited (in shares)	(22)
Vested (in shares)	(25)
Outstanding at the end of the period (in shares)	33

Equity Incentive Plan - Equity-

Equity Incentive Plan - Equity-based Compensation (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Less amounts capitalized			$ (712)	$ (1,647)
Total equity-based compensation, net	$ 8,414	$ 1,913	11,610	4,328
Share-settled
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	1,772	2,376	4,510	5,717
Less amounts capitalized	(42)	(682)	(712)	(1,647)
Total equity-based compensation, net	1,730	1,694	3,798	4,070
Restricted stock awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	1,857	2,044	3,820	4,542
Performance share awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	(129)	282	596	1,038
Outperformance share award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	44	43	87	87
Stock option awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	0	7	7	50
Cash-settled
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	6,779	252	8,105	301
Less amounts capitalized	(95)	(33)	(293)	(43)
Total equity-based compensation, net	6,684	219	7,812	258
Performance unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	6,352	166	7,172	190
Phantom unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total equity-based compensation, gross	$ 427	$ 86	$ 933	$ 111

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) $ in Thousands	Feb. 01, 2021USD ($)	Jun. 30, 2021USD ($)derivative$ / bblbbl	Jun. 30, 2020USD ($)	Dec. 31, 2022USD ($)
Derivative [Line Items]
Number of types of derivative instruments | derivative		3
Premiums paid (received) for derivative financial instruments		$ (9,041)	$ 51,070
Commodity - Oil | WTI NYMEX | Oil put January 2021 - December 2022 | Forecast | Not Designated as Hedges | Howard County Net Acres
Derivative [Line Items]
Notional amount of derivative				$ 1,200
Commodity - Oil | Derivatives Sold | Brent ICE | Put
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl		2,254,500
Premiums paid (received) for derivative financial instruments		$ (9,000)
Weighted-average price (in USD per unit) | $ / bbl		55
Commodity - Oil | Derivatives Sold | Brent ICE | Swap
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl		2,254,500
Premiums paid (received) for derivative financial instruments	$ 50,600
Weighted-average price (in USD per unit) | $ / bbl		55.09

Derivatives - Gain (Loss) on De

Derivatives - Gain (Loss) on Derivatives (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Derivative [Line Items]
Gain (loss) on derivatives, net	$ (216,942)	$ (90,537)	$ (371,307)	$ 207,299
Commodity
Derivative [Line Items]
Gain (loss) on derivatives, net	(216,869)	(90,864)	(370,902)	200,497
Interest rate
Derivative [Line Items]
Gain (loss) on derivatives, net	(30)	(338)	(26)	(338)
Contingent consideration
Derivative [Line Items]
Gain (loss) on derivatives, net	$ (43)	$ 665	$ (379)	$ 7,140

Derivatives - Derivatives Termi

Derivatives - Derivatives Terminated (Details) - Early Contract Termination - WTI NYMEX - Commodity - Oil - Swap	6 Months Ended
	Jun. 30, 2021$ / bblbbl
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	912,500
Floor price ($/Bbl)	45
Ceiling price ($/Bbl)	71

Derivatives - Summary (Details)

Derivatives - Summary (Details) - Forecast - Outstanding at End of Period - Not Designated as Hedges	6 Months Ended	12 Months Ended
	Dec. 31, 2021MMBTU$ / bbl$ / MMBTUbbl	Dec. 31, 2025MMBTU$ / bbl$ / MMBTUbbl	Dec. 31, 2024MMBTU$ / bbl$ / MMBTUbbl	Dec. 31, 2023MMBTU$ / bbl$ / MMBTUbbl	Dec. 31, 2022MMBTU$ / bbl$ / MMBTUbbl
Commodity - Oil | WTI NYMEX
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	0				1,204,500
Commodity - Oil | WTI NYMEX | Floor
Derivative [Line Items]
Weighted-average price/differential (in USD per unit)	0				55
Commodity - Oil | WTI NYMEX | Ceiling
Derivative [Line Items]
Weighted-average price/differential (in USD per unit)	0				74.35
Commodity - Oil | WTI NYMEX | Swap | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	786,242	730,509	847,480	1,017,720	1,280,111
Weighted-average price/differential (in USD per unit)	63.38	53.52	54.70	56.70	59.79
Commodity - Oil | WTI Midland to WTI NYMEX | Swap | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	786,242	730,509	0	1,017,720	1,280,111
Weighted-average price/differential (in USD per unit)	0.24	0.40	0	0.50	0.50
Commodity - Oil | Brent ICE | Swap
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	3,781,200				4,124,500
Weighted-average price/differential (in USD per unit)	51.29				48.34
Commodity - Oil | Brent ICE | Collar
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	662,400				1,551,250
Commodity - Oil | Brent ICE | Collar | Floor
Derivative [Line Items]
Weighted-average price/differential (in USD per unit)	55				56.65
Commodity - Oil | Brent ICE | Collar | Ceiling
Derivative [Line Items]
Weighted-average price/differential (in USD per unit)	66.53				65.44
Commodity - Oil | Brent ICE | Commodity | Floor
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	4,443,600				5,675,750
Weighted-average price/differential (in USD per unit)	51.84				50.61
Commodity - Oil | Brent ICE | Commodity | Ceiling
Derivative [Line Items]
Weighted-average price/differential (in USD per unit)	53.56				53.01
Commodity - NGL | Swap | Ethane
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	460,000				0
Weighted-average price/differential (in USD per unit)	12.01				0
Commodity - NGL | Swap | Ethane | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	356,327	0	0	280,362	629,123
Weighted-average price/differential (in USD per unit)	10.50	0	0	8.87	9.56
Commodity - NGL | Swap | Propane
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	1,221,576				0
Weighted-average price/differential (in USD per unit)	22.90				0
Commodity - NGL | Swap | Propane | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	267,245	0	0	210,271	471,841
Weighted-average price/differential (in USD per unit)	33.60	0	0	24.89	28.19
Commodity - NGL | Swap | Normal Butane
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	407,192				0
Weighted-average price/differential (in USD per unit)	25.87				0
Commodity - NGL | Swap | Normal Butane | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	80,983	0	0	63,719	142,983
Weighted-average price/differential (in USD per unit)	37.70	0	0	27.77	31.55
Commodity - NGL | Swap | Isobutane
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	111,136				0
Weighted-average price/differential (in USD per unit)	26.55				0
Commodity - NGL | Swap | Isobutane | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	24,295	0	0	19,116	42,897
Weighted-average price/differential (in USD per unit)	37.54	0	0	27.67	31.45
Commodity - NGL | Swap | Natural Gasoline
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	444,176				0
Weighted-average price/differential (in USD per unit)	38.16				0
Commodity - NGL | Swap | Natural Gasoline | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	80,983	0	0	63,719	142,983
Weighted-average price/differential (in USD per unit)	58.38	0	0	48.20	52.92
Commodity - NGL | Commodity
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	2,644,080				0
Commodity - NGL | Commodity | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Aggregate volumes (Bbl) | bbl	809,833	0	0	637,187	1,429,827
Commodity - Natural gas | Henry Hub NYMEX | Swap
Derivative [Line Items]
Weighted-average price/differential (in USD per unit) | $ / MMBTU	2.59				2.73
Volume (MMBtu) | MMBTU	21,436,000				3,650,000
Commodity - Natural gas | Henry Hub NYMEX | Swap | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Weighted-average price/differential (in USD per unit) | $ / MMBTU	3	2.57	2.55	2.56	2.73
Volume (MMBtu) | MMBTU	9,219,072	11,112,681	12,385,310	14,038,618	16,276,973
Commodity - Natural gas | Waha Inside FERC to Henry Hub NYMEX | Basis Swap
Derivative [Line Items]
Weighted-average price/differential (in USD per unit) | $ / MMBTU	(0.47)				(0.41)
Volume (MMBtu) | MMBTU	28,556,800				18,067,500
Commodity - Natural gas | Waha Inside FERC to Henry Hub NYMEX | Basis Swap | Glasscock and Reagan County - Working Interest Sale in Oil and Gas Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Derivative [Line Items]
Weighted-average price/differential (in USD per unit) | $ / MMBTU	(0.04)	0	(0.42)	(0.41)	(0.26)
Volume (MMBtu) | MMBTU	9,219,072	0	12,385,310	14,038,618	16,276,973

Derivatives - Derivatives Enter

Derivatives - Derivatives Entered into (Details) - Interest Rate Swap - Not Designated as Hedges $ in Thousands	Jun. 30, 2021USD ($)
Derivative [Line Items]
Notional amount of derivative	$ 100,000
Fixed rate (as a percent)	0.345%

Fair value measurements - Fair

Fair value measurements - Fair value hierarchy (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Assets:
Net fair value presented on the unaudited consolidated balance sheets	$ 0	$ 7,893
Net fair value presented on the unaudited consolidated balance sheets	423	0
Liabilities:
Net fair value presented on the unaudited consolidated balance sheets	(256,460)	(31,826)
Net fair value presented on the unaudited consolidated balance sheets	(61,514)	(12,051)
Net derivative liability positions	(317,551)	(35,984)
Interest rate - LIBOR
Liabilities:
Net fair value presented on the unaudited consolidated balance sheets	(179)	(206)
Net fair value presented on the unaudited consolidated balance sheets	0	(63)
Commodity - Oil | Commodity Derivatives
Assets:
Net fair value presented on the unaudited consolidated balance sheets	0	8,028
Net fair value presented on the unaudited consolidated balance sheets	423	0
Liabilities:
Net fair value presented on the unaudited consolidated balance sheets	(144,872)	(188)
Net fair value presented on the unaudited consolidated balance sheets	(51,519)	(10,932)
Commodity - Oil | Contingent Consideration
Liabilities:
Net fair value presented on the unaudited consolidated balance sheets	(1,159)	(665)
Net fair value presented on the unaudited consolidated balance sheets	0	(115)
Commodity - NGL | Commodity Derivatives
Assets:
Net fair value presented on the unaudited consolidated balance sheets	0	0
Net fair value presented on the unaudited consolidated balance sheets	0	0
Liabilities:
Net fair value presented on the unaudited consolidated balance sheets	(65,144)	(13,465)
Net fair value presented on the unaudited consolidated balance sheets	(6,087)	0
Commodity - Natural gas | Commodity Derivatives
Assets:
Net fair value presented on the unaudited consolidated balance sheets	0	(135)
Net fair value presented on the unaudited consolidated balance sheets	0	0
Liabilities:
Net fair value presented on the unaudited consolidated balance sheets	(45,106)	(17,302)
Net fair value presented on the unaudited consolidated balance sheets	(3,908)	(941)
Current Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	5,993	32,958
Amounts offset	(5,993)	(24,930)
Current Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	27	2,720
Amounts offset	(27)	(2,720)
Current Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	1,650	521
Amounts offset	(1,650)	(656)
Noncurrent Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	6,678	0
Amounts offset	(6,255)	0
Noncurrent Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	0	0
Amounts offset	0	0
Noncurrent Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	6,542	535
Amounts offset	(6,542)	(535)
Current Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	(179)	(206)
Amounts offset	0	0
Current Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	(150,865)	(25,118)
Amounts offset	5,993	24,930
Current Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	(1,159)	(665)
Amounts offset	0	0
Current Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	(65,171)	(16,185)
Amounts offset	27	2,720
Current Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	(46,756)	(17,958)
Amounts offset	1,650	656
Noncurrent Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	0	(63)
Amounts offset	0	0
Noncurrent Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	(57,774)	(10,932)
Amounts offset	6,255	0
Noncurrent Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	0	(115)
Amounts offset	0	0
Noncurrent Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	(6,087)	0
Amounts offset	0	0
Noncurrent Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	(10,450)	(1,476)
Amounts offset	6,542	535
Level 1
Liabilities:
Net derivative liability positions	0	0
Level 1 | Current Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 1 | Current Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 1 | Current Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 1 | Noncurrent Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 1 | Noncurrent Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 1 | Noncurrent Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 1 | Current Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	0	0
Level 1 | Current Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 1 | Current Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	0	0
Level 1 | Current Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 1 | Current Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 1 | Noncurrent Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	0	0
Level 1 | Noncurrent Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 1 | Noncurrent Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	0	0
Level 1 | Noncurrent Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 1 | Noncurrent Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 2
Liabilities:
Net derivative liability positions	(317,551)	(35,984)
Level 2 | Current Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	5,993	32,958
Level 2 | Current Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	27	2,720
Level 2 | Current Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	1,650	521
Level 2 | Noncurrent Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	6,678	0
Level 2 | Noncurrent Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 2 | Noncurrent Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	6,542	535
Level 2 | Current Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	(179)	(206)
Level 2 | Current Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	(150,865)	(25,118)
Level 2 | Current Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	(1,159)	(665)
Level 2 | Current Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	(65,171)	(16,185)
Level 2 | Current Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	(46,756)	(17,958)
Level 2 | Noncurrent Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	0	(63)
Level 2 | Noncurrent Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	(57,774)	(10,932)
Level 2 | Noncurrent Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	0	(115)
Level 2 | Noncurrent Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	(6,087)	0
Level 2 | Noncurrent Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	(10,450)	(1,476)
Level 3
Liabilities:
Net derivative liability positions	0	0
Level 3 | Current Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 3 | Current Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 3 | Current Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 3 | Noncurrent Assets | Commodity - Oil | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 3 | Noncurrent Assets | Commodity - NGL | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 3 | Noncurrent Assets | Commodity - Natural gas | Commodity Derivatives
Assets:
Total gross fair value	0	0
Level 3 | Current Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	0	0
Level 3 | Current Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 3 | Current Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	0	0
Level 3 | Current Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 3 | Current Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 3 | Noncurrent Liabilities | Interest rate - LIBOR
Liabilities:
Total gross fair value	0	0
Level 3 | Noncurrent Liabilities | Commodity - Oil | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 3 | Noncurrent Liabilities | Commodity - Oil | Contingent Consideration
Liabilities:
Total gross fair value	0	0
Level 3 | Noncurrent Liabilities | Commodity - NGL | Commodity Derivatives
Liabilities:
Total gross fair value	0	0
Level 3 | Noncurrent Liabilities | Commodity - Natural gas | Commodity Derivatives
Liabilities:
Total gross fair value	$ 0	$ 0

Fair value measurements - Narra

Fair value measurements - Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment expense	$ 1,613,000	$ 406,448,000	$ 1,613,000	$ 593,147,000
Level 2 | Nonrecurring | Line-Fill and Other Inventories
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment expense			1,600,000	1,300,000
Level 2 | Commodity - Oil | Commodity Contract - Contingent Consideration #1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of derivative liability	$ 1,200,000		1,200,000		$ 800,000
Level 3 | Nonrecurring | Long-Lived Assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment expense			$ 0	$ 8,200,000

Fair value measurements - Carry

Fair value measurements - Carrying Amount of Debt Instruments (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Long-term debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	$ 1,318,957	$ 1,193,957
Long-term debt | Senior Secured Credit Facility | Secured Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	380,000	255,000
Long-term debt | January 2025 Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	577,913	577,913
Long-term debt | January 2028 Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	361,044	361,044
Fair value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	1,386,171	1,054,153
Fair value | Senior Secured Credit Facility | Secured Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	380,611	255,187
Fair value | January 2025 Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	608,953	499,299
Fair value | January 2028 Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	$ 396,607	$ 299,667

Net loss per common share - Sum

Net loss per common share - Summary (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Earnings Per Share [Abstract]
Net loss (numerator)	$ (132,661)	$ (545,455)	$ (208,100)	$ (470,809)
Weighted-average common shares outstanding (denominator):
Basic (in shares)	12,674	11,667	12,298	11,642
Diluted (in shares)	12,674	11,667	12,298	11,642
Net loss per common share:
Basic (in USD per share)	$ (10.47)	$ (46.75)	$ (16.92)	$ (40.44)
Diluted (in USD per share)	$ (10.47)	$ (46.75)	$ (16.92)	$ (40.44)

Commitments and contingencies (

Commitments and contingencies (Details)	6 Months Ended		12 Months Ended
	Jun. 30, 2021USD ($)operating_lease	Jun. 30, 2020USD ($)	Dec. 31, 2020USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
Minimum volume commitment deficiency payments	$ 1,100,000	$ 0
Minimum volume commitments deficiency payments liability	3,400,000
Accrual for environmental loss contingencies	0		$ 0
Sand Purchase Commitment
Unrecorded Unconditional Purchase Obligation [Line Items]
Purchase and supply commitment period			1 year
Minimum purchase commitment shortfall payment	1,700,000
Firm Sale and Transportation Commitments
Unrecorded Unconditional Purchase Obligation [Line Items]
Future commitments	$ 244,400,000
Drilling Rig Contract
Unrecorded Unconditional Purchase Obligation [Line Items]
Number of operating leases | operating_lease	2
Penalties incurred for early contract termination	$ 0	$ 0

Supplemental cash flow and no_3

Supplemental cash flow and non-cash information - Summary (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Supplemental cash flow information:
Cash paid for interest, net of $890 and $1,822 of capitalized interest, respectively	$ 49,966	$ 25,595
Capitalized interest	890	1,822
Supplemental non-cash investing information:
Fair value of contingent consideration on acquisition date	0	225
Change in accrued capital expenditures	4,366	(15,024)
Capitalized share-settled equity-based compensation	712	1,647
Capitalized asset retirement cost	730	1,082
Right-of-use assets obtained in exchange for operating lease liabilities	$ 7,532	$ 2,349

Asset retirement obligations -

Asset retirement obligations - Summary (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liability at beginning of period	$ 68,326	$ 62,718
Liabilities added due to acquisitions, drilling, midstream service asset construction and other	730	1,082
Accretion expense	2,301	2,223
Liabilities settled due to plugging and abandonment or removed due to sale	(150)	(778)
Liability at end of period	$ 71,206	$ 65,245

Income taxes (Details)

Income taxes (Details) $ in Millions	Jun. 30, 2021USD ($)
Operating loss carry-forward
Deferred tax assets, valuation allowance	$ 532.8
Federal | Internal Revenue Service (IRS)
Operating loss carry-forward
Operating loss carryforwards	2,200
Operating loss carryforwards subject to expiration	1,700
Operating loss carryforwards not subject to expiration	436.3
State | State of Oklahoma
Operating loss carry-forward
Operating loss carryforwards	34.5
State | Texas
Operating loss carry-forward
Net deferred tax asset	$ 3.6

Related parties - Summary (Deta

Related parties - Summary (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Related Party Transaction [Line Items]
Capital expenditures for oil and natural gas properties	$ 166,077	$ 241,939
Halliburton | Affiliated entity
Related Party Transaction [Line Items]
Capital expenditures for oil and natural gas properties	$ 25,657	$ 18,104

Organizational restructurings (

Organizational restructurings (Details) $ in Thousands	Jun. 29, 2021senior_officer	Jun. 17, 2020senior_officer	Jun. 30, 2021USD ($)	Jun. 30, 2020USD ($)	Jun. 30, 2021USD ($)	Jun. 30, 2020USD ($)
Restructuring Cost and Reserve [Line Items]
Workforce reduction (positions eliminated) | senior_officer	14	22
Workforce reduction (as a percent)	5.00%
Organizational restructuring expenses			$ 9,800	$ 4,200	$ 9,800	$ 4,200
Equity-based compensation			8,414	1,913	$ 11,610	$ 4,328
One-time Termination Benefits
Restructuring Cost and Reserve [Line Items]
Organizational restructuring expenses			9,800	4,200
Share Based Compensation Awards Forfeited
Restructuring Cost and Reserve [Line Items]
Equity-based compensation			$ (1,100)	$ (800)

Subsequent events - Narrative (

Subsequent events - Narrative (Details) - USD ($) $ in Thousands	Aug. 04, 2021	Jul. 26, 2021	Jul. 16, 2021	Jul. 14, 2021	Jul. 07, 2021	Jul. 01, 2021	May 07, 2021	Jan. 24, 2020	Jun. 30, 2021	Jun. 30, 2020
Subsequent Event [Line Items]
Repayments of long-term lines of credit									$ 120,000	$ 100,000
Sabalo/Shad
Subsequent Event [Line Items]
Stock issued in asset acquisition (shares)							2,506,964
Senior Notes
Subsequent Event [Line Items]
Proceeds from senior notes								$ 982,000
Secured Debt | Senior Secured Credit Facility
Subsequent Event [Line Items]
Amount outstanding									$ 380,000
Subsequent Event | Sabalo/Shad
Subsequent Event [Line Items]
Stock issued in asset acquisition (shares)						2,506,964
Subsequent Event | Secured Debt | Senior Secured Credit Facility
Subsequent Event [Line Items]
Proceeds from lines of credit	$ 40,000			$ 55,000	$ 30,000
Repayments of long-term lines of credit		$ 50,000	$ 385,000
Amount outstanding	$ 70,000
Subsequent Event | Senior Unsecured Notes Due 2029 | Senior Notes
Subsequent Event [Line Items]
Face amount of debt			$ 400,000
Interest rate (as a percent)			7.75%
Proceeds from senior notes			$ 392,000

Subsequent events - Derivatives

Subsequent events - Derivatives (Details) - Forecast - Subsequent to End of Period - Not Designated as Hedges	6 Months Ended	12 Months Ended
	Dec. 31, 2021MMBTU$ / bbl$ / bbl$ / MMBTUbbl	Dec. 31, 2022MMBTU$ / bbl$ / MMBTU$ / bblbbl
Commodity - Oil | WTI NYMEX | Swap
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	612,000	365,000
Weighted-average price (in USD per unit)	69.46	64.40
Commodity - Oil | WTI NYMEX | Collar
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	153,000	3,394,500
Commodity - Oil | WTI NYMEX | Collar | Minimum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	63	58.23
Commodity - Oil | WTI NYMEX | Collar | Maximum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	67.65	69.39
Commodity - Oil | WTI NYMEX | Commodity | Minimum
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	765,000	3,759,500
Weighted-average price (in USD per unit)	68.16	58.83
Commodity - Oil | WTI NYMEX | Commodity | Maximum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	69.09	68.91
Commodity - Oil | Brent ICE | Swap
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	3,781,200	4,124,500
Weighted-average price (in USD per unit)	51.29	48.34
Commodity - Oil | Brent ICE | Collar
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	662,400	1,551,250
Commodity - Oil | Brent ICE | Collar | Minimum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	55	56.65
Commodity - Oil | Brent ICE | Collar | Maximum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	66.53	65.44
Commodity - Oil | Brent ICE | Commodity | Minimum
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	4,443,600	5,675,750
Weighted-average price (in USD per unit)	51.84	50.61
Commodity - Oil | Brent ICE | Commodity | Maximum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	53.56	53.01
Commodity - NGL | Swap | Ethane
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	460,000	1,533,000
Weighted-average price (in USD per unit)	12.01	11.42
Commodity - NGL | Swap | Propane
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	1,221,576	1,168,000
Weighted-average price (in USD per unit)	22.90	35.91
Commodity - NGL | Swap | Normal Butane
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	407,192	365,000
Weighted-average price (in USD per unit)	25.87	41.58
Commodity - NGL | Swap | Isobutane
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	111,136	109,500
Weighted-average price (in USD per unit)	26.55	42
Commodity - NGL | Swap | Natural Gasoline
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	444,176	365,000
Weighted-average price (in USD per unit)	38.16	60.65
Commodity - NGL | Commodity
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	2,644,080	3,540,500
Commodity - Natural gas | Henry Hub NYMEX | Minimum
Subsequent Event [Line Items]
Aggregate volumes (Bbl) | bbl	0	18,250,000
Weighted-average price (in USD per unit)	0	3
Commodity - Natural gas | Henry Hub NYMEX | Maximum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	0	3.31
Commodity - Natural gas | Henry Hub NYMEX | Swap
Subsequent Event [Line Items]
Weighted-average price (in USD per unit) | $ / MMBTU	2.59	2.73
Volume (MMBtu) | MMBTU	21,436,000	3,650,000
Commodity - Natural gas | Henry Hub NYMEX | Commodity | Minimum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	2.59	2.96
Commodity - Natural gas | Henry Hub NYMEX | Commodity | Maximum
Subsequent Event [Line Items]
Weighted-average price (in USD per unit)	2.59	3.22
Volume (MMBtu) | MMBTU	21,436,000	21,900,000
Commodity - Natural gas | Waha Inside FERC to Henry Hub NYMEX | Basis Swap
Subsequent Event [Line Items]
Weighted-average price (in USD per unit) | $ / MMBTU	(0.47)	(0.41)
Volume (MMBtu) | MMBTU	28,556,800	18,067,500