Continental Resources Inc (CLR) 10-Q 3 Aug 20 2020 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information Document - shares	6 Months Ended
	Jun. 30, 2020	Jul. 24, 2020
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	001-32886
Entity Registrant Name	CONTINENTAL RESOURCES, INC
Entity Central Index Key	0000732834
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-0767549
Entity Address, Address Line One	20 N. Broadway,
Entity Address, City or Town	Oklahoma City,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73102
City Area Code	405
Local Phone Number	234-9000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		365,129,084
NEW YORK STOCK EXCHANGE, INC. [Member]
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $0.01 par value
Trading Symbol	CLR
Security Exchange Name	NYSE

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 6,656	$ 39,400
Receivables:
Crude oil and natural gas sales	176,090	726,876
Joint interest and other	151,162	317,018
Allowance for credit losses	(2,356)	(2,407)
Receivables, Net, Current	324,896	1,041,487
Derivative assets	9,442	0
Inventories	68,285	109,536
Prepaid expenses and other	19,111	16,592
Total current assets	428,390	1,207,015
Net property and equipment, based on successful efforts method of accounting	14,312,982	14,497,726
Operating lease right-of-use assets	11,478	9,128
Other noncurrent assets	13,508	14,038
Total assets	14,766,358	15,727,907
Current liabilities:
Accounts payable trade	311,935	629,264
Revenues and royalties payable	158,309	470,264
Accrued liabilities and other	122,353	230,368
Derivative liabilities	10,101	0
Current portion of operating leases	5,210	3,695
Current portion of long-term debt	2,206	2,435
Total current liabilities	610,114	1,336,026
Long-term debt, net of current portion	5,740,554	5,324,079
Other noncurrent liabilities:
Deferred income tax liabilities, net	1,664,970	1,787,125
Asset retirement obligations, net of current portion	159,474	151,774
Operating lease liabilities, net of current portion	6,148	5,433
Other noncurrent liabilities	13,846	15,119
Total other noncurrent liabilities	1,844,438	1,959,451
Commitments and contingencies (Note 10)
Equity:
Preferred stock, $0.01 par value; 25,000,000 shares authorized; no shares issued and outstanding	0	0
Common stock, $0.01 par value; 1,000,000,000 shares authorized; 365,144,243 shares issued and outstanding at June 30, 2020; 371,074,036 shares issued and outstanding at December 31, 2019	3,651	3,711
Additional paid-in capital	1,172,932	1,274,732
Retained earnings	5,019,561	5,463,224
Total shareholders’ equity attributable to Continental Resources	6,196,144	6,741,667
Noncontrolling interests	375,108	366,684
Total Equity	6,571,252	7,108,351
Total liabilities and equity	$ 14,766,358	$ 15,727,907

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	25,000,000	25,000,000
Preferred stock, shares issued
Preferred stock, shares outstanding
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	1,000,000,000	1,000,000,000
Common Stock, Shares, Issued	365,144,243	371,074,036
Common Stock, Shares, Outstanding	365,144,243	371,074,036

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Revenues:
Crude oil and natural gas sales	$ 174,652	$ 1,137,425	$ 1,037,395	$ 2,247,009
Gain (loss) on derivative instruments, net	(7,782)	53,448	(7,782)	52,324
Crude oil and natural gas service operations	8,789	17,509	26,847	33,284
Total revenues	175,659	1,208,382	1,056,460	2,332,617
Operating costs and expenses:
Production expenses	64,673	112,430	183,151	219,396
Production taxes	11,067	93,866	82,291	180,306
Transportation expenses	32,305	53,393	92,807	102,531
Exploration expenses	1,960	3,090	13,597	4,927
Crude oil and natural gas service operations	6,062	11,206	11,972	18,392
Depreciation, depletion, amortization and accretion	290,298	485,621	826,994	980,641
Property impairments	23,929	21,339	246,458	46,655
General and administrative expenses	41,529	47,226	84,440	94,844
Net (gain) loss on sale of assets and other	612	364	5,114	112
Total operating costs and expenses	472,435	828,535	1,546,824	1,647,804
Income (loss) from operations	(296,776)	379,847	(490,364)	684,813
Other income (expense):
Interest expense	(65,069)	(68,471)	(128,663)	(136,308)
Gain on extinguishment of debt	46,942	0	64,573	0
Other	629	723	1,161	2,077
Total other income (expense)	(17,498)	(67,748)	(62,929)	(134,231)
Income (loss) before income taxes	(314,274)	312,099	(553,293)	550,582
(Provision) benefit for income taxes	72,143	(75,649)	124,378	(127,639)
Net income (loss)	(242,131)	236,450	(428,915)	422,943
Net loss attributable to noncontrolling interests	(2,845)	(107)	(3,965)	(590)
Net income (loss) attributable to Continental Resources	$ (239,286)	$ 236,557	$ (424,950)	$ 423,533
Basic net income (loss) per share (in dollars per share)	$ (0.66)	$ 0.63	$ (1.17)	$ 1.14
Diluted net income (loss) per share (in dollars per share)	$ (0.66)	$ 0.63	$ (1.17)	$ 1.13
Foreign currency translation adjustments	$ 0	$ 30	$ 0	$ 146
Total other comprehensive income, net of tax	0	30	0	146
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(242,131)	236,480	(428,915)	423,089
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(2,845)	(107)	(3,965)	(590)
Comprehensive income (loss)	$ (239,286)	$ 236,587	$ (424,950)	$ 423,679

Condensed Consolidated Statemen

Condensed Consolidated Statements of Shareholders Equity - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-In Capital	Treasury Stock [Member]	Accumulated Other Comprehensive Income	Retained Earnings	Continental Resources Shareholders' Equity	Noncontrolling Interest
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								$ 276,728
Total Equity	$ 6,421,861
Balance at Dec. 31, 2018		$ 3,760	$ 1,434,823		$ 415	$ 4,706,135	$ 6,145,133
Balance, shares at Dec. 31, 2018		376,021,575
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources						186,976	186,976
Net loss attributable to noncontrolling interests								(483)
Net income (loss)	186,493
Other comprehensive income, net of tax (unaudited)	116				116		116
Contributions from Noncontrolling Interests	42,204							42,204
Distributions to Noncontrolling Interests	(3,856)							(3,856)
Stock-based compensation (unaudited)	12,095		12,095				12,095
Restricted stock:
Granted (unaudited)	13	$ 13					13
Granted (unaudited), shares		1,333,602
Repurchased and canceled (unaudited)	(20,622)	$ (4)	(20,618)				(20,622)
Repurchased and canceled (unaudited), shares		(439,419)
Forfeited (unaudited), shares		(147,074)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Mar. 31, 2019		$ 3,768	1,426,300		531	4,893,111	6,323,710
Balance, shares at Mar. 31, 2019		376,768,684
Balance at Dec. 31, 2018		$ 3,760	1,434,823		415	4,706,135	6,145,133
Balance, shares at Dec. 31, 2018		376,021,575
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	423,533
Net loss attributable to noncontrolling interests	(590)
Net income (loss)	422,943
Other comprehensive income, net of tax (unaudited)	146
Balance at Jun. 30, 2019		$ 3,749	1,368,272		561	5,110,921	6,483,503
Balance, shares at Jun. 30, 2019		374,943,548
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								314,593
Total Equity	6,638,303
Balance at Mar. 31, 2019		$ 3,768	1,426,300		531	4,893,111	6,323,710
Balance, shares at Mar. 31, 2019		376,768,684
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	236,557					236,557	236,557
Net loss attributable to noncontrolling interests	(107)							(107)
Net income (loss)	236,450
Dividends, Common Stock, Cash	(18,747)					(18,747)	(18,747)
Treasury Stock, Value, Acquired, Cost Method	(69,661)			$ (69,661)			(69,661)
Treasury Stock, Shares, Retired		(1,800,000)
Treasury Stock, Retired, Cost Method, Amount		$ (18)	(69,643)	(69,661)
Other comprehensive income, net of tax (unaudited)	30				30		30
Contributions from Noncontrolling Interests	35,118							35,118
Distributions to Noncontrolling Interests	(3,272)							(3,272)
Stock-based compensation (unaudited)	12,176		12,176				12,176
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		59,639
Repurchased and canceled (unaudited)	(562)	$ 1	(561)				(562)
Repurchased and canceled (unaudited), shares		(13,335)
Forfeited (unaudited), shares		(71,440)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Jun. 30, 2019		$ 3,749	1,368,272		561	5,110,921	6,483,503
Balance, shares at Jun. 30, 2019		374,943,548
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								346,332
Total Equity	6,829,835
Noncontrolling interests	366,684							366,684
Total Equity	7,108,351
Balance at Dec. 31, 2019	$ 6,741,667	$ 3,711	1,274,732		0	5,463,224	6,741,667
Balance, shares at Dec. 31, 2019	371,074,036	371,074,036
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources						(185,664)	(185,664)
Net loss attributable to noncontrolling interests								(1,120)
Net income (loss)	$ (186,784)
Cumulative effect adjustment from adoption of ASU 2016-13	(137)					(137)	(137)
Dividends, Common Stock, Cash	(18,580)					(18,580)	(18,580)
Change in dividends payable	2					2	2
Treasury Stock, Value, Acquired, Cost Method	(126,906)			(126,906)			(126,906)
Treasury Stock, Shares, Retired		(8,122,104)
Treasury Stock, Retired, Cost Method, Amount		$ (81)	(126,825)	$ (126,906)
Contributions from Noncontrolling Interests	16,950							16,950
Distributions to Noncontrolling Interests	(5,618)							(5,618)
Stock-based compensation (unaudited)	16,411		16,411				16,411
Restricted stock:
Granted (unaudited)	24	$ 24					24
Granted (unaudited), shares		2,454,235
Repurchased and canceled (unaudited)	(6,454)	$ (2)	(6,452)				(6,454)
Repurchased and canceled (unaudited), shares		(246,346)
Forfeited (unaudited), shares		(42,818)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Mar. 31, 2020		$ 3,651	1,157,866		0	5,258,845	6,420,362
Balance, shares at Mar. 31, 2020		365,117,003
Balance at Dec. 31, 2019	$ 6,741,667	$ 3,711	1,274,732		0	5,463,224	6,741,667
Balance, shares at Dec. 31, 2019	371,074,036	371,074,036
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	$ (424,950)
Net loss attributable to noncontrolling interests	(3,965)
Net income (loss)	(428,915)
Treasury Stock, Retired, Cost Method, Amount	(126,900)
Other comprehensive income, net of tax (unaudited)	$ 0
Restricted stock:
Granted (unaudited), shares	2,539,749
Repurchased and canceled (unaudited), shares	(8,100,000)
Forfeited (unaudited), shares	(82,055)
Balance at Jun. 30, 2020	$ 6,196,144	$ 3,651	1,172,932		0	5,019,561	6,196,144
Balance, shares at Jun. 30, 2020	365,144,243	365,144,243
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								376,896
Total Equity	$ 6,797,258
Balance at Mar. 31, 2020		$ 3,651	1,157,866		0	5,258,845	6,420,362
Balance, shares at Mar. 31, 2020		365,117,003
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	(239,286)					(239,286)	(239,286)
Net loss attributable to noncontrolling interests	(2,845)							(2,845)
Net income (loss)	(242,131)
Change in dividends payable	2					2	2
Other comprehensive income, net of tax (unaudited)	0
Contributions from Noncontrolling Interests	4,015							4,015
Distributions to Noncontrolling Interests	(2,958)							(2,958)
Stock-based compensation (unaudited)	15,313		15,313				15,313
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		85,514
Repurchased and canceled (unaudited)	(247)	$ 0	(247)				(247)
Repurchased and canceled (unaudited), shares		(19,037)
Forfeited (unaudited), shares		(39,237)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Jun. 30, 2020	$ 6,196,144	$ 3,651	$ 1,172,932		$ 0	$ 5,019,561	$ 6,196,144
Balance, shares at Jun. 30, 2020	365,144,243	365,144,243
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests	$ 375,108							$ 375,108
Total Equity	$ 6,571,252

Unaudited Condensed Consolida_2

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Statement of Cash Flows [Abstract]
Net income (loss)	$ (428,915)	$ 422,943
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, Depletion, Amortization and Accretion	828,728	983,183
Property impairments	246,458	46,655
Non-cash (gain) loss on derivatives	659	(30,592)
Stock-based compensation	31,755	24,283
Provision (benefit) for deferred income taxes	(122,155)	127,639
Dry hole costs	6,316	0
Net (gain) loss on sale of assets and other	5,114	112
Gain on extinguishment of debt	(64,573)	0
Other, net	5,785	4,536
Changes in assets and liabilities:
Accounts receivable	710,434	(15,144)
Inventories	16,731	(22,438)
Other current assets	(1,497)	(7,150)
Accounts payable trade	(169,762)	38,176
Revenues and royalties payable	(311,442)	(61,472)
Accrued liabilities and other	(108,628)	(5,732)
Other noncurrent assets and liabilities	(1,438)	(95)
Net cash provided by operating activities	643,570	1,504,904
Cash flows from investing activities
Exploration and development	(984,430)	(1,528,022)
Purchase of producing crude oil and natural gas properties	(19,328)	(20,527)
Purchase of other property and equipment	(17,222)	(9,848)
Proceeds from sale of assets	2,037	652
Net cash used in investing activities	(1,018,943)	(1,557,745)
Cash flows from financing activities
Credit facility borrowings	1,395,000	245,000
Repayment of credit facility	(863,000)	(245,000)
Redemption of Senior Notes	74,032	0
Proceeds from other debt	26,000	0
Repayment of other debt	(5,587)	(1,162)
Debt issuance costs	(112)	0
Contributions from noncontrolling interests	26,071	75,717
Distributions to noncontrolling interests	(9,644)	(7,166)
Payments for Repurchase of Common Stock	(126,906)	(69,661)
Repurchase of restricted stock for tax withholdings	(6,701)	(21,184)
Payments of Dividends	(18,460)	0
Net cash provided by (used in) financing activities	342,629	(23,456)
Effect of exchange rate changes on cash	0	30
Net change in cash and cash equivalents	(32,744)	(76,267)
Cash and cash equivalents, at beginning of period	39,400	282,749
Cash and cash equivalents, at end of period	$ 6,656	$ 206,482

Organization and Nature of Busi

Organization and Nature of Business	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Business	Organization and Nature of Business Continental Resources, Inc. (the “Company”) was formed in 1967 and is incorporated under the laws of the State of Oklahoma. The Company’s principal business is crude oil and natural gas exploration, development and production with properties primarily located in the North, South, and East regions of the United States. Additionally, the Company pursues the acquisition and management of perpetually owned minerals located in certain of its key operating areas. The North region consists of properties north of Kansas and west of the Mississippi River and includes North Dakota Bakken, Montana Bakken, and the Red River units. The South region includes all properties south of Nebraska and west of the Mississippi River including various plays in the SCOOP and STACK areas of Oklahoma. The East region is primarily comprised of undeveloped leasehold acreage east of the Mississippi River with no significant drilling or production operations. The Company's operations in the North region comprised 54% of its crude oil and natural gas production and 67% of its crude oil and natural gas revenues for the six months ended June 30, 2020 . The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. The Company's operations in the South region comprised 46% of its crude oil and natural gas production and 33% of its crude oil and natural gas revenues for the six months ended June 30, 2020 . The Company's principal producing properties in the South region are located in the SCOOP and STACK areas of Oklahoma. For the six months ended June 30, 2020 , crude oil accounted for 52% of the Company’s total production and 90%

Basis of Presentation and Signi

Basis of Presentation and Significant Accounting Policies	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Basis of Presentation and Significant Accounting Policies	Basis of Presentation and Significant Accounting Policies Basis of presentation The condensed consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries, and entities in which the Company has a controlling financial interest. Intercompany accounts and transactions have been eliminated upon consolidation. Noncontrolling interests reflected herein represent third party ownership in the net assets of consolidated subsidiaries. The portions of consolidated net income (loss) and equity attributable to the noncontrolling interests are presented separately in the Company’s financial statements. This report has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information. Because this is an interim period filing presented using a condensed format, it does not include all disclosures required by accounting principles generally accepted in the United States (“U.S. GAAP”), although the Company believes the disclosures are adequate to make the information not misleading. You should read this Quarterly Report on Form 10-Q (“Form 10-Q”) together with the Company’s Annual Report on Form 10-K for the year ended December 31, 2019 (“ 2019 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures. The condensed consolidated financial statements as of June 30, 2020 and for the three and six month periods ended June 30, 2020 and 2019 are unaudited. The condensed consolidated balance sheet as of December 31, 2019 was derived from the audited balance sheet included in the 2019 Form 10-K. The Company has evaluated events or transactions through the date this report on Form 10-Q was filed with the SEC in conjunction with its preparation of these condensed consolidated financial statements. The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure and estimation of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results may differ from those estimates. The most significant estimates and assumptions impacting reported results are estimates of the Company’s crude oil and natural gas reserves, which are used to compute depreciation, depletion, amortization and impairment of proved crude oil and natural gas properties. In the opinion of management, all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation in accordance with U.S. GAAP have been included in these unaudited condensed consolidated financial statements. The results of operations for any interim period are not necessarily indicative of the results of operations that may be expected for any other interim period or for an entire year. Earnings per share Basic net income (loss) per share is computed by dividing net income (loss) attributable to the Company by the weighted-average number of shares outstanding for the period. In periods where the Company has net income, diluted earnings per share reflects the potential dilution of non-vested restricted stock awards, which are calculated using the treasury stock method. The following table presents the calculation of basic and diluted weighted average shares outstanding and net income (loss) per share attributable to the Company for the three and six months ended June 30, 2020 and 2019 . Three months ended June 30, Six months ended June 30, In thousands, except per share data 2020 2019 2020 2019 Net income (loss) attributable to Continental Resources (numerator) $ (239,286 ) $ 236,557 $ (424,950 ) $ 423,533 Weighted average shares (denominator): Weighted average shares - basic 360,204 372,835 362,804 372,700 Non-vested restricted stock (1) — 1,174 — 1,857 Weighted average shares - diluted 360,204 374,009 362,804 374,557 Net income (loss) per share attributable to Continental Resources: Basic $ (0.66 ) $ 0.63 $ (1.17 ) $ 1.14 Diluted $ (0.66 ) $ 0.63 $ (1.17 ) $ 1.13 (1) For the three and six months ended June 30, 2020 the Company had a net loss and therefore the potential dilutive effect of approximately 23,000 and 243,000 weighted average non-vested restricted shares, respectively, were not included in the calculation of diluted net loss per share because to do so would have been anti-dilutive to the computations. Inventories Inventory is comprised of crude oil held in storage or as line fill in pipelines, pipeline imbalances, and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or net realizable value primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued primarily using a weighted average cost method applied to specific classes of inventory items. The components of inventory as of June 30, 2020 and December 31, 2019 consisted of the following: In thousands June 30, 2020 December 31, 2019 Tubular goods and equipment $ 14,415 $ 14,880 Crude oil 53,870 94,656 Total $ 68,285 $ 109,536 In the first quarter of 2020 the Company recognized a $24.5 million impairment to reduce its crude oil inventory to estimated net realizable value at March 31, 2020. The impairment is included in the caption “Property impairments” in the unaudited condensed consolidated statements of comprehensive income (loss) for the six month period ended June 30, 2020 . Adoption of new accounting pronouncement On January 1, 2020 the Company adopted Accounting Standards Update ("ASU") 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . See Note 5. Allowance for Credit Losses for discussion of the adoption impact and the applicable disclosures required by the new standard. New accounting pronouncement not yet adopted In December 2019, the Financial Accounting Standards Board ("FASB") issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2020
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information The following table discloses supplemental cash flow information about cash paid for interest and income tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments. Six months ended June 30, In thousands 2020 2019 Supplemental cash flow information: Cash paid for interest $ 125,208 $ 132,064 Cash paid for income taxes 8 9 Cash received for income tax refunds (1) 9,485 7 Non-cash investing activities: Asset retirement obligation additions and revisions, net 3,725 5,266 (1) Amount received in the 2020 period primarily represents alternative minimum tax refunds. As of June 30, 2020 and December 31, 2019 , the Company had $109.2 million and $262.7 million , respectively, of accrued capital expenditures included in “Net property and equipment” with an offsetting amount in “Accounts payable trade” in the condensed consolidated balance sheets. As of June 30, 2020 and December 31, 2019 , the Company had $0.5 million and $5.6 million , respectively, of accrued contributions from noncontrolling interests included in "Receivables – Joint interest and other" with an offsetting amount in "Equity – Noncontrolling interests" in the condensed consolidated balance sheets. As of June 30, 2020 and December 31, 2019 , the Company had $0.5 million and $1.5 million , respectively, of accrued distributions to noncontrolling interests included in "Revenues and royalties payable" with an offsetting amount in "Equity –

Revenues

Revenues	6 Months Ended
	Jun. 30, 2020
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Text Block]	Revenues Below is a discussion of the nature, timing, and presentation of revenues arising from the Company's major revenue-generating arrangements. Operated crude oil revenues – The Company pays third parties to transport the majority of its operated crude oil production from lease locations to downstream market centers, at which time the Company's customers take title and custody of the product in exchange for prices based on the particular market where the product was delivered. Operated crude oil revenues are recognized during the month in which control transfers to the customer and it is probable the Company will collect the consideration it is entitled to receive. Crude oil sales proceeds from operated properties are generally received by the Company within one month after the month in which a sale has occurred. Operated crude oil revenues are presented separately from transportation expenses as the Company controls the operated production prior to its transfer to customers. Transportation expenses associated with the Company's operated crude oil production totaled $23.5 million and $46.0 million for the three months ended June 30, 2020 and 2019 , respectively, and $73.9 million and $87.6 million for the six months ended June 30, 2020 and 2019 , respectively. Operated natural gas revenues – The Company sells the majority of its operated natural gas production to midstream customers at its lease locations based on market prices in the field where the sales occur. Under these arrangements, the midstream customers obtain control of the unprocessed gas stream at the lease location and the Company's revenues from each sale are determined using contractually agreed pricing formulas which contain multiple components, including the volume and Btu content of the natural gas sold, the midstream customer's proceeds from the sale of residue gas and natural gas liquids ("NGLs") at secondary downstream markets, and contractual pricing adjustments reflecting the midstream customer's estimated recoupment of its investment over time. Such revenues are recognized net of pricing adjustments applied by the midstream customer during the month in which control transfers to the customer at the delivery point and it is probable the Company will collect the consideration it is entitled to receive. Natural gas sales proceeds from operated properties are generally received by the Company within one month after the month in which a sale has occurred. Under certain arrangements, in periods of significantly depressed prices for natural gas and NGLs the contractual pricing adjustments applied by the midstream customer in a particular month may exceed the consideration to be received by the Company under the arrangement, resulting in a net payment owed by the Company to the midstream customer. In these situations, the net amounts paid or payable by the Company are reflected as a reduction of natural gas sales in the caption "Crude oil and natural gas sales" in the unaudited condensed consolidated statements of comprehensive income (loss). Such payments, which are referred to herein as negative gas revenues, totaled $22.7 million for operated properties for the three and six months ended June 30, 2020 . Under certain arrangements, the Company has the right to take a volume of processed residue gas and/or NGLs in-kind at the tailgate of the midstream customer's processing plant in lieu of a monetary settlement for the sale of the Company's operated natural gas production. The Company currently takes certain processed residue gas volumes in kind in lieu of monetary settlement, but does not currently take NGL volumes. When the Company elects to take volumes in kind, it pays third parties to transport the processed products it took in-kind to downstream delivery points, where it then sells to customers at prices applicable to those downstream markets. In such situations, operated revenues are recognized during the month in which control transfers to the customer at the delivery point and it is probable the Company will collect the consideration it is entitled to receive. Operated sales proceeds are generally received by the Company within one month after the month in which a sale has occurred. In these scenarios, the Company's revenues include the pricing adjustments applied by the midstream processing entity according to the applicable contractual pricing formula, but exclude the transportation expenses the Company incurs to transport the processed products to downstream customers. Transportation expenses associated with these arrangements totaled $8.8 million and $7.4 million for the three months ended June 30, 2020 and 2019 , respectively, and $18.9 million and $14.9 million for the six months ended June 30, 2020 and 2019 , respectively. Non-operated crude oil and natural gas revenues – The Company's proportionate share of production from non-operated properties is generally marketed at the discretion of the operators. For non-operated properties, the Company receives a net payment from the operator representing its proportionate share of sales proceeds which is net of costs incurred by the operator, if any. Such non-operated revenues are recognized at the net amount of proceeds to be received by the Company during the month in which production occurs and it is probable the Company will collect the consideration it is entitled to receive. Proceeds are generally received by the Company within two to three months after the month in which production occurs. In periods of significantly depressed prices for natural gas and NGLs the costs incurred by the outside operator in a particular month may exceed the consideration to be received by the Company, resulting in a net payment owed by the Company to the outside operator. In these situations, the net amounts paid or payable by the Company are reflected as a reduction of natural gas sales in the caption "Crude oil and natural gas sales" in the unaudited condensed consolidated statements of comprehensive income (loss). Such negative gas revenues associated with non-operated properties totaled $7.8 million for the three and six months ended June 30, 2020 . Revenues from derivative instruments – See Note 6. Derivative Instruments for discussion of the Company's accounting for its derivative instruments. Revenues from service operations – Revenues from the Company's crude oil and natural gas service operations consist primarily of revenues associated with water gathering, recycling, and disposal activities and the treatment and sale of crude oil reclaimed from waste products. Revenues associated with such activities, which are derived using market-based rates or rates commensurate with industry guidelines, are recognized during the month in which services are performed, the Company has an unconditional right to receive payment, and collectability is probable. Payment is generally received by the Company within one month after the month in which services are provided. Disaggregation of crude oil and natural gas revenues The following tables present the disaggregation of the Company's crude oil and natural gas revenues for the three and six months ended June 30, 2020 and 2019 . Three months ended June 30, 2020 Three months ended June 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 96,410 $ 30,075 $ 126,485 $ 608,442 $ 176,086 $ 784,528 Non-operated properties 28,368 3,867 32,235 207,782 12,836 220,618 Total crude oil revenues 124,778 33,942 158,720 816,224 188,922 1,005,146 Natural gas revenues: Operated properties (1) (22,512 ) 39,704 17,192 21,650 94,712 116,362 Non-operated properties (2) (4,622 ) 3,362 (1,260 ) 5,051 10,866 15,917 Total natural gas revenues (27,134 ) 43,066 15,932 26,701 105,578 132,279 Crude oil and natural gas sales $ 97,644 $ 77,008 $ 174,652 $ 842,925 $ 294,500 $ 1,137,425 Timing of revenue recognition Goods transferred at a point in time $ 97,644 $ 77,008 $ 174,652 $ 842,925 $ 294,500 $ 1,137,425 Goods transferred over time — — — — — — $ 97,644 $ 77,008 $ 174,652 $ 842,925 $ 294,500 $ 1,137,425 Six months ended June 30, 2020 Six months ended June 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 545,340 $ 209,251 $ 754,591 $ 1,194,047 $ 312,633 $ 1,506,680 Non-operated properties 161,307 16,592 177,899 386,510 23,074 409,584 Total crude oil revenues 706,647 225,843 932,490 1,580,557 335,707 1,916,264 Natural gas revenues: Operated properties (1) (10,923 ) 112,010 101,087 73,111 219,410 292,521 Non-operated properties (2) (2,903 ) 6,721 3,818 15,917 22,307 38,224 Total natural gas revenues (13,826 ) 118,731 104,905 89,028 241,717 330,745 Crude oil and natural gas sales $ 692,821 $ 344,574 $ 1,037,395 $ 1,669,585 $ 577,424 $ 2,247,009 Timing of revenue recognition Goods transferred at a point in time $ 692,821 $ 344,574 $ 1,037,395 $ 1,669,585 $ 577,424 $ 2,247,009 Goods transferred over time — — — — — — $ 692,821 $ 344,574 $ 1,037,395 $ 1,669,585 $ 577,424 $ 2,247,009 (1) Operated natural gas revenues for the North region include negative gas revenues totaling $22.7 million for both the three and six month periods ended June 30, 2020 . (2) Non-operated natural gas revenues for the North region include negative gas revenues totaling $7.8 million for both the three and six month periods ended June 30, 2020 . Performance obligations The Company satisfies the performance obligations under its crude oil and natural gas sales contracts upon delivery of its production and related transfer of control to customers. Judgment may be required in determining the point in time when control transfers to customers. Upon delivery of production, the Company has a right to receive consideration from its customers in amounts determined by the sales contracts. All of the Company's outstanding crude oil sales contracts at June 30, 2020 are short-term in nature with contract terms of less than one year. For such contracts, the Company has utilized the practical expedient in Accounting Standards Codification ("ASC") 606-10-50-14 exempting the Company from disclosure of the transaction price allocated to remaining performance obligations, if any, if the performance obligation is part of a contract that has an original expected duration of one year or less. The majority of the Company's operated natural gas production is sold at lease locations to midstream customers under multi-year term contracts. For such contracts having a term greater than one year, the Company has utilized the practical expedient in ASC 606-10-50-14A which indicates an entity is not required to disclose the transaction price allocated to remaining performance obligations, if any, if variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under the Company's sales contracts, whether for crude oil or natural gas, each unit of production delivered to a customer represents a separate performance obligation; therefore, future volumes to be delivered are wholly unsatisfied at period-end and disclosure of the transaction price allocated to remaining performance obligations is not applicable. Contract balances Under the Company’s crude oil and natural gas sales contracts or activities that give rise to service revenues, the Company recognizes revenue after its performance obligations have been satisfied, at which point the Company has an unconditional right to receive payment. Accordingly, the Company’s commodity sales contracts and service activities generally do not give rise to contract assets or contract liabilities under ASC Topic 606. Instead, the Company's unconditional rights to receive consideration are presented as a receivable within "Receivables – Crude oil and natural gas sales" or "Receivables – Joint interest and other", as applicable, in its condensed consolidated balance sheets. Revenues from previously satisfied performance obligations To record revenues for commodity sales, at the end of each month the Company estimates the amount of production delivered and sold to customers and the prices to be received for such sales. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month payment is received from the customer and are reflected in the financial statements within the caption "Crude oil and natural gas sales". Revenues recognized during the three and six months ended June 30, 2020 and 2019 related to performance obligations satisfied in prior reporting periods were not material.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments From time to time the Company has entered into crude oil and natural gas swap and collar derivative contracts to economically hedge against the variability in cash flows associated with future sales of production. The Company recognizes its derivative instruments on the balance sheet as either assets or liabilities measured at fair value. The Company has not designated its derivatives as hedges for accounting purposes and, as a result, marks such derivative instruments to fair value and recognizes the changes in fair value in the unaudited condensed consolidated statements of comprehensive income (loss) under the caption " Gain (loss) on derivative instruments, net ". The Company's derivative contracts are settled based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on NYMEX West Texas Intermediate ("WTI") pricing and natural gas derivative settlements based on NYMEX Henry Hub pricing. The estimated fair value of derivative contracts is based upon various factors, including commodity exchange prices, over-the-counter quotations, and, in the case of collars, volatility, the risk-free interest rate, and the time to expiration. The calculation of the fair value of collars requires the use of an option-pricing model. See Note 7. Fair Value Measurements . At June 30, 2020 the Company had outstanding derivative contracts as set forth in the tables below. Crude oil derivatives Swaps Weighted Average Price Period and Type of Contract Bbls July 2020 Swaps - WTI 2,790,000 $ 35.67 Natural gas derivatives Collars Floors Ceilings Swaps Weighted Average Price Range Weighted Average Price Range Weighted Average Price Period and Type of Contract MMBtus July 2020 - December 2020 Swaps - Henry Hub 17,480,000 $ 2.63 January 2021 - March 2021 Swaps - Henry Hub 5,400,000 $ 2.74 January 2021 - March 2021 Collars - Henry Hub 11,700,000 $2.65 - $2.70 $ 2.67 $3.31 - $3.48 $ 3.40 Derivative gains and losses Cash receipts and payments in the following table reflect the gains or losses on derivative contracts which matured during the applicable period, calculated as the difference between the contract price and the market settlement price of matured contracts. Non-cash gains and losses below represent the change in fair value of derivative instruments which continued to be held at period end and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period. Three months ended June 30, Six months ended June 30, In thousands 2020 2019 2020 2019 Cash received (paid) on derivatives: Crude oil fixed price swaps (1) $ (7,123 ) $ — $ (7,123 ) $ — Natural gas fixed price swaps — 8,670 — 16,315 Natural gas collars — — — 5,417 Cash received (paid) on derivatives, net (7,123 ) 8,670 (7,123 ) 21,732 Non-cash gain (loss) on derivatives: Crude oil fixed price swaps (10,101 ) — (10,101 ) — Natural gas fixed price swaps 8,749 44,778 8,749 36,074 Natural gas collars 693 — 693 (5,482 ) Non-cash gain (loss) on derivatives, net (659 ) 44,778 (659 ) 30,592 Gain (loss) on derivative instruments, net $ (7,782 ) $ 53,448 $ (7,782 ) $ 52,324 (1) Represents realized losses on crude oil derivatives totaling 1,920,000 barrels at a weighted average price of $29.94 per barrel that were executed and settled during the three months ended June 30, 2020 . Balance sheet offsetting of derivative assets and liabilities The Company’s derivative contracts are recorded at fair value in the condensed consolidated balance sheets under the captions “Derivative assets,” “Noncurrent derivative assets,” “Derivative liabilities,” and “Noncurrent derivative liabilities,” as applicable. Derivative assets and liabilities with the same counterparty that are subject to contractual terms which provide for net settlement are reported on a net basis in the condensed consolidated balance sheets. The following table presents the gross amounts of recognized derivative assets and liabilities, as applicable, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value. In thousands June 30, 2020 December 31, 2019 Commodity derivative assets: Gross amounts of recognized assets $ 9,471 $ — Gross amounts offset on balance sheet (29 ) — Net amounts of assets on balance sheet 9,442 — Commodity derivative liabilities: Gross amounts of recognized liabilities (10,130 ) — Gross amounts offset on balance sheet 29 — Net amounts of liabilities on balance sheet $ (10,101 ) $ — The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets. In thousands June 30, 2020 December 31, 2019 Derivative assets $ 9,442 $ — Noncurrent derivative assets — — Net amounts of assets on balance sheet 9,442 — Derivative liabilities (10,101 ) — Noncurrent derivative liabilities — — Net amounts of liabilities on balance sheet (10,101 ) — Total derivative liabilities, net $ (659 ) $ —

Allowance for Credit Losses (No

Allowance for Credit Losses (Notes)	6 Months Ended
	Jun. 30, 2020
Allowance for Credit Losses [Abstract]
Credit Loss, Financial Instrument [Text Block]	Allowance for Credit Losses In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . This standard changes how entities measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The standard replaced the previously required incurred loss approach with a forward-looking expected credit loss model for accounts receivable and other financial instruments measured at amortized cost. The standard became effective for reporting periods beginning after December 15, 2019. The Company adopted the new standard on January 1, 2020 using a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the effective date. The Company's cumulative effect adjustment resulted in a $0.1 million decrease in retained earnings and corresponding decrease in receivables via the recognition of an incremental allowance for credit losses at January 1, 2020. The Company's principal exposure to credit risk is through the sale of its crude oil and natural gas production and its receivables associated with billings to joint interest owners. Accordingly, the Company classifies its receivables into two portfolio segments as depicted on the condensed consolidated balance sheets as "Receivables — Crude oil and natural gas sales” and "Receivables — Joint interest and other.” Presented below are applicable disclosures required by ASU 2016-13 for each portfolio segment. Historically, the Company's credit losses on receivables have been immaterial. The Company’s aggregate allowance for credit losses totaled $2.4 million and $2.4 million at June 30, 2020 and December 31, 2019 , which is reported as "Allowance for credit losses" in the condensed consolidated balance sheets. Aggregate credit loss expenses totaled $0.7 million and $0.1 million for the three months ended June 30, 2020 and 2019 , respectively, and $1.5 million and $0.1 million for the six months ended June 30, 2020 and 2019 , respectively, which are included in “General and administrative expenses” in the unaudited condensed consolidated statements of comprehensive income (loss). Receivables—Crude oil and natural gas sales The Company's crude oil and natural gas production from operated properties is generally sold to energy marketing companies, crude oil refining companies, and natural gas gathering and processing companies. The Company monitors its credit loss exposure to these counterparties primarily by reviewing credit ratings, financial statements, and payment history. Credit terms are extended based on an evaluation of each counterparty’s credit worthiness. The Company has not generally required its counterparties to provide collateral to secure its crude oil and natural gas sales receivables. Receivables associated with crude oil and natural gas sales are short term in nature. Receivables from the sale of crude oil and natural gas from operated properties are generally collected within one month after the month in which a sale has occurred, while receivables associated with non-operated properties are generally collected within two to three months after the month in which production occurs. The Company’s allowance for credit losses on crude oil and natural gas sales was negligible at both June 30, 2020 and December 31, 2019 . The allowance was determined by considering a number of factors, primarily including the Company’s history of credit losses with adjustment as needed to reflect current conditions, the length of time accounts are past due, whether amounts relate to operated properties or non-operated properties, and the counterparty's ability to pay. There were no significant write-offs, recoveries, or changes in the provision for credit losses on this portfolio segment during the three and six month periods ended June 30, 2020 . Receivables—Joint interest and other Joint interest and other receivables primarily arise from billing the individuals and entities who own a partial interest in the wells we operate. Joint interest receivables are due within 30 days and are considered delinquent after 60 days. In order to minimize our exposure to credit risk with these counterparties we generally request prepayment of drilling costs where it is allowed by contract or state law. Such prepayments are used to offset future capital costs when billed, thereby reducing the Company's credit risk. We may have the right to place a lien on a co-owner's interest in the well, to net production proceeds against amounts owed in order to secure payment or, if necessary, foreclose on the co-owner's interest. The Company’s allowance for credit losses on joint interest receivables totaled $2.3 million and $2.4 million at June 30, 2020 and December 31, 2019 , respectively. The allowance was determined by considering a number of factors, primarily including the Company’s history of credit losses with adjustment as needed to reflect current conditions, the length of time accounts are past due, the ability to recoup amounts owed through netting of production proceeds, the balance of co-owner prepayments if any, and the co-owner's ability to pay. There were no significant write-offs, recoveries, or changes in the provision for credit losses on this portfolio segment during the three and six month periods ended June 30, 2020

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The Company follows a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows: • Level 1: Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date. • Level 2: Observable market-based inputs or unobservable inputs corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. • Level 3: Unobservable inputs not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value. A financial instrument’s categorization within the hierarchy is based upon the lowest level of input that is significant to the fair value measurement. Level 1 inputs are given the highest priority in the fair value hierarchy while Level 3 inputs are given the lowest priority. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the hierarchy. As Level 1 inputs generally provide the most reliable evidence of fair value, the Company uses Level 1 inputs when available. Assets and Liabilities Measured at Fair Value on a Recurring Basis The Company's derivative instruments are reported at fair value on a recurring basis. In determining the fair values of swap contracts, a discounted cash flow method is used due to the unavailability of relevant comparable market data for the Company’s exact contracts. The discounted cash flow method estimates future cash flows based on quoted market prices for forward commodity prices and a risk-adjusted discount rate. The fair values of swap contracts are calculated mainly using significant observable inputs (Level 2). Calculation of the fair values of collars requires the use of an industry-standard option pricing model that considers various inputs including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. These assumptions are observable in the marketplace or can be corroborated by active markets or broker quotes and are therefore designated as Level 2 within the valuation hierarchy. The Company’s calculation of fair value for each of its derivative positions is compared to the counterparty valuation for reasonableness. The following table summarizes the valuation of derivative instruments by pricing levels that were accounted for at fair value on a recurring basis as of June 30, 2020 . The Company had no outstanding derivative instruments at December 31, 2019 . Fair value measurements at June 30, 2020 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets (liabilities): Swaps $ — $ (1,352 ) $ — $ (1,352 ) Collars — 693 — 693 Total $ — $ (659 ) $ — $ (659 ) Assets Measured at Fair Value on a Nonrecurring Basis Certain assets are reported at fair value on a nonrecurring basis in the condensed consolidated financial statements. The following methods and assumptions were used to estimate the fair values for those assets. Asset impairments – Proved crude oil and natural gas properties are reviewed for impairment on a field-by-field basis each quarter. The estimated future cash flows expected in connection with the field are compared to the carrying amount of the field to determine if the carrying amount is recoverable. If the carrying amount of the field exceeds its estimated undiscounted future cash flows, the carrying amount of the field is reduced to its estimated fair value. Risk-adjusted probable and possible reserves may be taken into consideration when determining estimated future net cash flows and fair value when such reserves exist and are economically recoverable. Due to the unavailability of relevant comparable market data, a discounted cash flow method is used to determine the fair value of proved properties. Significant unobservable inputs (Level 3) utilized in the determination of discounted future net cash flows include future commodity prices adjusted for differentials, forecasted production based on decline curve analysis, estimated future operating and development costs, property ownership interests, and a 10% discount rate. At June 30, 2020 , the Company's commodity price assumptions were based on forward NYMEX strip prices through year-end 2024 and were then escalated at 3% per year thereafter. Operating cost assumptions were based on current costs escalated at 3% per year beginning in 2021. Unobservable inputs to the Company's fair value assessments are reviewed and revised as warranted based on a number of factors, including reservoir performance, new drilling, crude oil and natural gas prices, changes in costs, technological advances, new geological or geophysical data, or other economic factors. Fair value measurements of proved properties are reviewed and approved by certain members of the Company’s management. For the six months ended June 30, 2020 the Company determined the carrying amounts of certain proved properties were not recoverable from future cash flows and therefore were impaired. Such impairments, all of which were recognized in the 2020 first quarter, totaled $181.0 million which reflect fair value adjustments on legacy properties in the Red River Units ( $166.5 million ) and various non-core properties in the North and South regions ( $14.5 million ). The impaired properties were written down to their estimated fair value at the time of impairment of $145.6 million . Impairments for the six months ended June 30, 2020 also include a $24.5 million impairment recognized in the 2020 first quarter to reduce the Company's crude oil inventory to estimated net realizable value at the time of impairment. No proved property impairments were recognized during the three months ended June 30, 2020 . For the three and six months ended June 30, 2019 , estimated future net cash flows were determined to be in excess of cost basis, therefore no impairment was recorded for the Company’s proved crude oil and natural gas properties for the 2019 periods. Certain unproved crude oil and natural gas properties were impaired during the three and six months ended June 30, 2020 and 2019 , reflecting recurring amortization of undeveloped leasehold costs on properties the Company expects will not be transferred to proved properties over the lives of the leases based on drilling plans, experience of successful drilling, and the average holding period. The following table sets forth the non-cash impairments of both proved and unproved properties for the indicated periods. Proved and unproved property impairments are recorded under the caption “Property impairments” in the unaudited condensed consolidated statements of comprehensive income (loss). Three months ended June 30, Six months ended June 30, In thousands 2020 2019 2020 2019 Proved property impairments $ — $ — $ 205,545 $ — Unproved property impairments 23,929 21,339 40,913 46,655 Total $ 23,929 $ 21,339 $ 246,458 $ 46,655 Financial Instruments Not Recorded at Fair Value The following table sets forth the estimated fair values of financial instruments that are not recorded at fair value in the condensed consolidated financial statements. June 30, 2020 December 31, 2019 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 587,000 $ 587,000 $ 55,000 $ 55,000 Notes payable 25,676 26,200 5,351 5,400 5% Senior Notes due 2022 1,099,306 1,082,700 1,099,165 1,108,700 4.5% Senior Notes due 2023 1,442,434 1,393,400 1,491,339 1,571,400 3.8% Senior Notes due 2024 906,370 864,400 994,310 1,034,200 4.375% Senior Notes due 2028 990,197 882,900 989,661 1,063,700 4.9% Senior Notes due 2044 691,777 559,900 691,688 742,000 Total debt $ 5,742,760 $ 5,396,500 $ 5,326,514 $ 5,580,400 The fair value of credit facility borrowings approximate carrying value based on borrowing rates available to the Company for bank loans with similar terms and maturities and are classified as Level 2 in the fair value hierarchy. The fair value of notes payable is determined using a discounted cash flow approach based on the interest rate and payment terms of the notes payable and an assumed discount rate. The fair value of notes payable is significantly influenced by the discount rate assumption, which is derived by the Company and is unobservable. Accordingly, the fair value of notes payable is classified as Level 3 in the fair value hierarchy. See Note 8. Long-Term Debt for discussion of the changes in the Company's notes payable in June 2020. The fair values of the 5% Senior Notes due 2022 (“2022 Notes”), the 4.5% Senior Notes due 2023 (“2023 Notes”), the 3.8% Senior Notes due 2024 (“2024 Notes”), the 4.375% Senior Notes due 2028 (“2028 Notes”), and the 4.9% Senior Notes due 2044 (“2044 Notes”) are based on quoted market prices and, accordingly, are classified as Level 1 in the fair value hierarchy. The carrying values of all classes of cash and cash equivalents, trade receivables, and trade payables are considered to be representative of their respective fair values due to the short term maturities of those instruments.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $30.7 million and $33.9 million at June 30, 2020 and December 31, 2019 , respectively, consists of the following. In thousands June 30, 2020 December 31, 2019 Credit facility $ 587,000 $ 55,000 Notes payable 25,676 5,351 5% Senior Notes due 2022 1,099,306 1,099,165 4.5% Senior Notes due 2023 1,442,434 1,491,339 3.8% Senior Notes due 2024 906,370 994,310 4.375% Senior Notes due 2028 990,197 989,661 4.9% Senior Notes due 2044 691,777 691,688 Total debt $ 5,742,760 $ 5,326,514 Less: Current portion of long-term debt 2,206 2,435 Long-term debt, net of current portion $ 5,740,554 $ 5,324,079 Credit Facility The Company has an unsecured credit facility, maturing on April 9, 2023 , with aggregate lender commitments totaling $1.5 billion . The Company had $587 million of outstanding borrowings on its credit facility at June 30, 2020 . Credit facility borrowings bear interest at market-based interest rates plus a margin based on the terms of the borrowing and the credit ratings assigned to the Company's senior, unsecured, long-term indebtedness. The weighted-average interest rate on outstanding credit facility borrowings at June 30, 2020 was 2.1% . The Company had approximately $908 million of borrowing availability on its credit facility at June 30, 2020 after considering outstanding borrowings and letters of credit. The Company incurs commitment fees based on currently assigned credit ratings of 0.25% per annum on the daily average amount of unused borrowing availability. The credit facility contains certain restrictive covenants including a requirement that the Company maintain a consolidated net debt to total capitalization ratio of no greater than 0.65 to 1.00. This ratio represents the ratio of net debt (calculated as total face value of debt plus outstanding letters of credit less cash and cash equivalents) divided by the sum of net debt plus total shareholders' equity plus, to the extent resulting in a reduction of total shareholders’ equity, the amount of any non-cash impairment charges incurred, net of any tax effect, after June 30, 2014. The Company was in compliance with the credit facility covenants at June 30, 2020 . Senior Notes The following table summarizes the face values, maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at June 30, 2020 . In March and April 2020 the Company repurchased a portion of its 2023 Notes and 2024 Notes in open market transactions as further discussed below under the heading Repurchase of Senior Notes . 2022 Notes (1) 2023 Notes 2024 Notes 2028 Notes 2044 Notes Face value (in thousands) $1,100,000 $1,449,625 $911,000 $1,000,000 $700,000 Maturity date Sep 15, 2022 April 15, 2023 June 1, 2024 January 15, 2028 June 1, 2044 Interest payment dates March 15, Sep 15 April 15, Oct 15 June 1, Dec 1 Jan 15, July 15 June 1, Dec 1 Make-whole redemption period (2) — Jan 15, 2023 Mar 1, 2024 Oct 15, 2027 Dec 1, 2043 (1) The Company has the option to redeem all or a portion of its remaining 2022 Notes at the decreasing redemption prices specified in the indenture governing the 2022 Notes plus any accrued and unpaid interest to the date of redemption. (2) At any time prior to the indicated dates, the Company has the option to redeem all or a portion of its senior notes of the applicable series at the “make-whole” redemption amounts specified in the respective senior note indentures plus any accrued and unpaid interest to the date of redemption. On or after the indicated dates, the Company may redeem all or a portion of its senior notes at a redemption amount equal to 100% of the principal amount of the senior notes being redeemed plus any accrued and unpaid interest to the date of redemption. The Company’s senior notes are not subject to any mandatory redemption or sinking fund requirements. The indentures governing the Company’s senior notes contain covenants that, among other things, limit the Company’s ability to create liens securing certain indebtedness, enter into certain sale-leaseback transactions, or consolidate, merge or transfer certain assets. These covenants are subject to a number of important exceptions and qualifications. The Company was in compliance with these covenants at June 30, 2020 . Three of the Company’s wholly-owned subsidiaries, Banner Pipeline Company, L.L.C., CLR Asset Holdings, LLC, and The Mineral Resources Company, whose assets, equity, and results of operations are not material, fully and unconditionally guarantee the senior notes on a joint and several basis. The Company’s other subsidiaries, whose assets, equity, and results of operations attributable to the Company are not material, do not guarantee the senior notes. Repurchase of Senior Notes In March 2020, the Company repurchased a portion of its 2023 Notes and 2024 Notes in open market transactions at a substantial discount to the face value of the notes, including $33.4 million face value of its 2023 Notes at an aggregate cost of $19.5 million and $7.0 million face value of its 2024 Notes at an aggregate cost of $3.8 million , in each case, including accrued and unpaid interest to the repurchase dates. In April 2020, the Company repurchased an additional $17.0 million face value of its 2023 Notes at an aggregate cost of $9.8 million and an additional $82.0 million face value of its 2024 Notes at an aggregate cost of $43.1 million , in each case, including accrued and unpaid interest to the repurchase dates. The repurchased notes were canceled by the Company. The Company recognized pre-tax gains on extinguishment of debt in the 2020 first quarter related to the March 2020 repurchases totaling $17.6 million and additional pre-tax gains on extinguishment of debt in the 2020 second quarter related to the April 2020 repurchases totaling $47.0 million , which included the pro-rata write-off of deferred financing costs and unamortized debt discount associated with the notes. The gains are reflected in the caption “Gain on extinguishment of debt” in the unaudited condensed consolidated statements of comprehensive income (loss). Notes payable In June 2020, the Company borrowed an aggregate of $26.0 million under two 10 -year amortizing term loans secured by the Company’s corporate office building and its interest in parking facilities in Oklahoma City, Oklahoma. The loans mature in May 2030 and bear interest at a fixed rate of 3.50% per annum through June 9, 2025, at which time the interest rate will be reset and fixed through the maturity date. Principal and interest are payable monthly through the maturity date and, accordingly, $2.2 million is reflected as a current liability under the caption “Current portion of long-term debt” in the condensed consolidated balance sheets as of June 30, 2020 associated with the loans. A portion of the proceeds from the new loans was used to fully repay the Company's previous note payable that was set to mature in February 2022, which had a balance at pay-off of $4.4 million

Leases

Leases	6 Months Ended
	Jun. 30, 2020
Leases [Abstract]
Lessee, Operating Leases [Text Block]	Leases The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $11.4 million as of June 30, 2020 at discounted present value, which is comprised of the asset classes reflected in the table below. All leases recognized on the Company's balance sheet are classified as operating leases. The amounts disclosed herein primarily represent costs associated with properties operated by the Company that are presented on a gross basis and do not reflect the Company's net proportionate share of such amounts. A portion of these costs have been or will be billed to other working interest owners. Once paid, the Company's share of these costs are included in property and equipment, production expenses, or general and administrative expenses, as applicable. The Company's leasing activities as a lessor are negligible. In thousands Amount Drilling rig commitments $ 4,625 Surface use agreements 5,065 Field equipment 1,078 Other 590 Total $ 11,358 Drilling rig commitments reflected above represent minimum payment obligations expected to be incurred on enforceable commitments with durations in excess of one year at the inception of the lease. Minimum future commitments by year for the Company's operating leases as of June 30, 2020 are presented in the table below. Such commitments are reflected at undiscounted values and are reconciled to the discounted present value recognized on the balance sheet. In thousands Amount Remainder of 2020 $ 3,371 2021 2,658 2022 865 2023 812 2024 537 Thereafter 6,682 Total operating lease liabilities, at undiscounted value $ 14,925 Less: Imputed interest (3,567 ) Total operating lease liabilities, at discounted present value $ 11,358 Less: Current portion of operating lease liabilities (5,210 ) Operating lease liabilities, net of current portion $ 6,148 Additional information for the Company's operating leases is presented below. Lease costs, which are presented on a gross basis and do not reflect the Company's net proportionate share of such amounts, primarily represent costs incurred for drilling rigs, most of which are short term contracts that are not recognized as right-of-use assets and lease liabilities on the balance sheet. Variable lease costs primarily represent differences between minimum payment obligations and actual operating day-rate charges incurred by the Company for its long term drilling rig contracts. Short-term lease costs primarily represent operating day-rate charges for drilling rig contracts with durations of one year or less and month-to-month field equipment rentals. Three months ended June 30, Six months ended June 30, In thousands, except weighted average data 2020 2019 2020 2019 Lease costs: Operating lease costs $ 1,641 $ 3,273 $ 2,901 $ 6,546 Variable lease costs 912 4,691 4,135 7,813 Short-term lease costs 29,460 39,517 80,808 94,678 Total lease costs $ 32,013 $ 47,481 $ 87,844 $ 109,037 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 337 $ — $ 7,339 $ — Operating cash flows from operating leases included in lease liabilities 187 199 415 398 Weighted average remaining lease term as of June 30 (in years) 10.7 6.8 Weighted average discount rate as of June 30 4.3 % 4.7 %

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Included below is a discussion of certain future commitments and contingencies of the Company as of June 30, 2020 . Drilling rig commitments – As of June 30, 2020 , the Company has drilling rig contracts with various terms extending to April 2021 . Future operating day-rate commitments as of June 30, 2020 total approximately $27 million , of which $23 million is expected to be incurred in the remainder of 2020 and $4 million will be incurred in 2021 . A portion of these future costs will be borne by other interest owners. Such future commitments include minimum payment obligations with a discounted present value totaling $4.6 million that are required to be recognized on the Company's balance sheet at June 30, 2020 in accordance with ASC Topic 842 as discussed in Note 9. Leases . Other lease commitments – The Company has various other lease commitments primarily associated with surface use agreements and field equipment. See Note 9. Leases for additional information. Transportation, gathering, and processing commitments – The Company has entered into transportation, gathering, and processing commitments to guarantee capacity on crude oil and natural gas pipelines and natural gas processing facilities. The commitments, which have varying terms extending as far as 2031, require the Company to pay per-unit transportation, gathering, or processing charges regardless of the amount of capacity used. Future commitments remaining as of June 30, 2020 under the arrangements amount to approximately $1.55 billion , of which $107 million is expected to be incurred in the remainder of 2020 , $226 million in 2021 , $255 million in 2022 , $255 million in 2023 , $220 million in 2024, and $483 million thereafter. A portion of these future costs will be borne by other interest owners. The Company is not committed under the above contracts to deliver fixed and determinable quantities of crude oil or natural gas in the future. These commitments do not qualify as leases under ASC Topic 842 and are not recognized on the Company's balance sheet. Litigation – On April 15, 2020, Casillas Petroleum Resource Partners II, LLC filed a petition against the Company in the District Court of Tulsa County, State of Oklahoma. In its petition, Casillas alleges the Company breached a Purchase and Sale Agreement (“PSA”) to purchase oil and gas interests in Oklahoma for $200 million . Casillas seeks specific performance. The Company terminated the PSA due to Casillas’ breach of the agreement and denies the allegations and is vigorously defending the claims and seeking affirmative relief. The Company is not currently able to estimate what impact, if any, the ultimate resolution of the action will have on its financial condition, results of operations, or cash flows due to the preliminary status of the matter. The Company is involved in various other legal proceedings including, but not limited to, commercial disputes, claims from royalty and surface owners, property damage claims, personal injury claims, regulatory compliance matters, disputes with tax authorities and other matters. While the outcome of these legal matters cannot be predicted with certainty, the Company does not expect them to have a material effect on its financial condition, results of operations or cash flows. As of June 30, 2020 and December 31, 2019 , the Company had recognized a liability within “Other noncurrent liabilities” of $7.5 million and $8.7 million , respectively, for various matters, none of which are believed to be individually significant. Environmental risk – Due to the nature of the crude oil and natural gas business, the Company is exposed to possible environmental risks. The Company is not aware of any material environmental issues or claims.

Stock-Based Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 2020
Share-based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation The Company has granted restricted stock to employees and directors pursuant to the Continental Resources, Inc. 2013 Long-Term Incentive Plan, as amended ("2013 Plan"). The Company’s associated compensation expense, which is included in the caption “General and administrative expenses” in the unaudited condensed consolidated statements of comprehensive income (loss), was $15.3 million and $12.2 million for the three months ended June 30, 2020 and 2019 , respectively, and $31.7 million and $24.3 million for the six months ended June 30, 2020 and 2019 , respectively. In March 2019, the Company amended and restated its 2013 Plan and specified 12,983,543 shares of common stock may be issued pursuant to the amended plan. Subject to limited exceptions, the 2013 Plan allows previously issued shares to be reissued if such shares are subsequently forfeited or withheld to satisfy tax withholdings. As of June 30, 2020 , the Company had 10,844,493 shares of common stock available for long-term incentive awards to employees and directors under the 2013 Plan. Restricted stock is awarded in the name of the recipient and constitutes issued and outstanding shares of the Company’s common stock for all corporate purposes during the period of restriction and, except as otherwise provided under the 2013 Plan or agreement relevant to a given award, includes the right to vote the restricted stock and to receive dividends if any, subject to forfeiture. Restricted stock grants generally vest over periods ranging from 1 to 3 years. A summary of changes in non-vested restricted shares outstanding for the six months ended June 30, 2020 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2019 3,461,908 $ 46.82 Granted 2,539,749 27.91 Vested (1,011,002 ) 46.26 Forfeited (82,055 ) 38.21 Non-vested restricted shares outstanding at June 30, 2020 4,908,600 $ 37.29 The grant date fair value of restricted stock represents the closing market price of the Company’s common stock on the date of grant. Compensation expense for a restricted stock grant is determined at the grant date fair value and is recognized over the vesting period as services are rendered by employees and directors. The Company estimates the number of forfeitures expected to occur in determining the amount of stock-based compensation expense to recognize. There are no post-vesting restrictions related to the Company’s restricted stock. The fair value at the vesting date of restricted stock that vested during the six months ended June 30, 2020 was approximately $25 million . As of June 30, 2020 , there was approximately $100 million of unrecognized compensation expense related to non-vested restricted stock. This expense is expected to be recognized over a weighted average period of 1.7

Shareholders' Equity

Shareholders' Equity	6 Months Ended
	Jun. 30, 2020
Shareholders' Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Shareholders' Equity Share repurchases During the three months ended March 31, 2020, the Company repurchased and retired approximately 8.1 million shares of its common stock at an aggregate cost of $126.9 million . No share repurchases were made during the three months ended June 30, 2020 . Through June 30, 2020 , the Company had repurchased and retired a cumulative total of approximately 13.8 million shares at an aggregate cost of $317.1 million since the inception of its $1 billion share repurchase program in June 2019. The timing and amount of the Company's share repurchases are subject to market conditions and management discretion. The share repurchase program does not require the Company to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board of Directors at any time. Dividend payment On January 27, 2020 the Company declared a quarterly cash dividend of $0.05 per share on its outstanding common stock, which amounted to $18.4 million and was paid on February 21, 2020 to shareholders of record as of February 7, 2020.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2020
Income Taxes [Abstract]
Income Tax Disclosure [Text Block]	Income Taxes Income taxes are accounted for using the liability method under which deferred income taxes are recognized for the future tax effects of temporary differences between financial statement carrying amounts and the tax basis of existing assets and liabilities using the enacted statutory tax rates in effect at period-end. The effect on deferred taxes for a change in tax rates is recognized in income in the period that includes the enactment date. The Company’s policy is to recognize penalties and interest related to unrecognized tax benefits, if any, in income tax expense. The Company's provision (benefit) for income taxes and resulting effective tax rates were as follows for the periods presented. Three months ended June 30, Six months ended June 30, 2020 2019 2020 2019 Provision (benefit) for income taxes (in thousands) $ (72,143 ) $ 75,649 $ (124,378 ) $ 127,639 Effective tax rate 23.0 % 24.2 % 22.5 % 23.2 % The Company computes its quarterly income tax provision (benefit) under the effective tax rate method based on applying an anticipated annual effective tax rate to year-to-date pre-tax income (loss), except for discrete items. Income taxes for discrete items are computed and recorded in the period in which the specific transaction occurs. The Company's effective tax rate differs from the United States federal statutory tax rate due to the effect of state income taxes, equity compensation, valuation allowances, and other tax items as reflected in the table below. Three months ended June 30, Six months ended June 30, In thousands, except tax rates 2020 2019 2020 2019 Income (loss) before income taxes $ (314,274 ) $ 312,099 $ (553,293 ) $ 550,582 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % 21.0 % Expected income tax provision (benefit) based on U.S. federal statutory tax rate (65,998 ) 65,541 (116,192 ) 115,622 Items impacting the effective tax rate: State and local income taxes, net of federal benefit (10,305 ) 11,538 (17,908 ) 19,337 Equity compensation 585 102 4,471 (8,216 ) Other, net 560 (1,532 ) (2,629 ) 896 Valuation allowance 3,015 — 7,880 — Provision (benefit) for income taxes $ (72,143 ) $ 75,649 $ (124,378 ) $ 127,639 Effective tax rate 23.0 % 24.2 % 22.5 % 23.2 % The Company reduces its deferred tax assets by a valuation allowance if, based upon the weight of available evidence, it is more-likely-than-not that the Company will not realize some portion or all of the deferred tax assets. The Company considers relevant evidence, both positive and negative, to determine the need for a valuation allowance. Information evaluated includes the Company's financial position and results of operations for the current and preceding years, the availability of deferred tax liabilities and tax carrybacks, as well as an evaluation of currently available information about future years. In the first quarter of 2020 the Company determined it was more-likely-than-not that a portion of its Oklahoma net operating loss ("NOL") carryforwards would not be able to be utilized before expiration, and a valuation allowance of approximately $4.9 million was established at March 31, 2020 for the deferred tax assets associated with such NOL carryforwards. The Company recognized an additional valuation allowance of $3.0 million against such deferred tax assets during the three months ended June 30, 2020 , bringing the cumulative valuation allowance to $7.9 million as of June 30, 2020 . The Company will continue to evaluate both the positive and negative evidence on a quarterly basis in determining the need for a valuation allowance with respect to its deferred tax assets. Changes in positive and negative evidence, including differences between estimated and actual results, could result in changes in the valuation of our deferred tax assets that could have a material impact on our consolidated financial statements. Changes in existing tax laws could also affect actual tax results and the realization of deferred tax assets over time.

Basis of Presentation and Sig_2

Basis of Presentation and Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Description of the Company	Continental Resources, Inc. (the “Company”) was formed in 1967 and is incorporated under the laws of the State of Oklahoma. The Company’s principal business is crude oil and natural gas exploration, development and production with properties primarily located in the North, South, and East regions of the United States. Additionally, the Company pursues the acquisition and management of perpetually owned minerals located in certain of its key operating areas. The North region consists of properties north of Kansas and west of the Mississippi River and includes North Dakota Bakken, Montana Bakken, and the Red River units. The South region includes all properties south of Nebraska and west of the Mississippi River including various plays in the SCOOP and STACK areas of Oklahoma. The East region is primarily comprised of undeveloped leasehold acreage east of the Mississippi River with no significant drilling or production operations. The Company's operations in the North region comprised 54% of its crude oil and natural gas production and 67% of its crude oil and natural gas revenues for the six months ended June 30, 2020 . The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. The Company's operations in the South region comprised 46% of its crude oil and natural gas production and 33% of its crude oil and natural gas revenues for the six months ended June 30, 2020 . The Company's principal producing properties in the South region are located in the SCOOP and STACK areas of Oklahoma. For the six months ended June 30, 2020 , crude oil accounted for 52% of the Company’s total production and 90%
Basis of Presentation	Basis of presentation The condensed consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries, and entities in which the Company has a controlling financial interest. Intercompany accounts and transactions have been eliminated upon consolidation. Noncontrolling interests reflected herein represent third party ownership in the net assets of consolidated subsidiaries. The portions of consolidated net income (loss) and equity attributable to the noncontrolling interests are presented separately in the Company’s financial statements. This report has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information. Because this is an interim period filing presented using a condensed format, it does not include all disclosures required by accounting principles generally accepted in the United States (“U.S. GAAP”), although the Company believes the disclosures are adequate to make the information not misleading. You should read this Quarterly Report on Form 10-Q (“Form 10-Q”) together with the Company’s Annual Report on Form 10-K for the year ended December 31, 2019 (“ 2019 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures. The condensed consolidated financial statements as of June 30, 2020 and for the three and six month periods ended June 30, 2020 and 2019 are unaudited. The condensed consolidated balance sheet as of December 31, 2019 was derived from the audited balance sheet included in the 2019 Form 10-K. The Company has evaluated events or transactions through the date this report on Form 10-Q was filed with the SEC in conjunction with its preparation of these condensed consolidated financial statements. The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure and estimation of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results may differ from those estimates. The most significant estimates and assumptions impacting reported results are estimates of the Company’s crude oil and natural gas reserves, which are used to compute depreciation, depletion, amortization and impairment of proved crude oil and natural gas properties. In the opinion of management, all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation in accordance with U.S. GAAP have been included in these unaudited condensed consolidated financial statements. The results of operations for any interim period are not necessarily indicative of the results of operations that may be expected for any other interim period or for an entire year.
Earnings Per Share	Earnings per share
Inventories	Inventories Inventory is comprised of crude oil held in storage or as line fill in pipelines, pipeline imbalances, and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or net realizable value primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued primarily using a weighted average cost method applied to specific classes of inventory items.
New Accounting Pronouncements	Adoption of new accounting pronouncement On January 1, 2020 the Company adopted Accounting Standards Update ("ASU") 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . See Note 5. Allowance for Credit Losses for discussion of the adoption impact and the applicable disclosures required by the new standard. New accounting pronouncement not yet adopted In December 2019, the Financial Accounting Standards Board ("FASB") issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.

Basis of Presentation and Sig_3

Basis of Presentation and Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Components of Inventories	The components of inventory as of June 30, 2020 and December 31, 2019 consisted of the following: In thousands June 30, 2020 December 31, 2019 Tubular goods and equipment $ 14,415 $ 14,880 Crude oil 53,870 94,656 Total $ 68,285 $ 109,536
Calculation of Basic and Diluted Weighted Average Shares and Net Income Per Share	The following table presents the calculation of basic and diluted weighted average shares outstanding and net income (loss) per share attributable to the Company for the three and six months ended June 30, 2020 and 2019 . Three months ended June 30, Six months ended June 30, In thousands, except per share data 2020 2019 2020 2019 Net income (loss) attributable to Continental Resources (numerator) $ (239,286 ) $ 236,557 $ (424,950 ) $ 423,533 Weighted average shares (denominator): Weighted average shares - basic 360,204 372,835 362,804 372,700 Non-vested restricted stock (1) — 1,174 — 1,857 Weighted average shares - diluted 360,204 374,009 362,804 374,557 Net income (loss) per share attributable to Continental Resources: Basic $ (0.66 ) $ 0.63 $ (1.17 ) $ 1.14 Diluted $ (0.66 ) $ 0.63 $ (1.17 ) $ 1.13

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2020
Supplemental Cash Flow Elements [Abstract]
Summary of Supplemental Cash Flow Information	The following table discloses supplemental cash flow information about cash paid for interest and income tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments. Six months ended June 30, In thousands 2020 2019 Supplemental cash flow information: Cash paid for interest $ 125,208 $ 132,064 Cash paid for income taxes 8 9 Cash received for income tax refunds (1) 9,485 7 Non-cash investing activities: Asset retirement obligation additions and revisions, net 3,725 5,266

Revenues (Tables)

Revenues (Tables)	6 Months Ended
	Jun. 30, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	The following tables present the disaggregation of the Company's crude oil and natural gas revenues for the three and six months ended June 30, 2020 and 2019 . Three months ended June 30, 2020 Three months ended June 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 96,410 $ 30,075 $ 126,485 $ 608,442 $ 176,086 $ 784,528 Non-operated properties 28,368 3,867 32,235 207,782 12,836 220,618 Total crude oil revenues 124,778 33,942 158,720 816,224 188,922 1,005,146 Natural gas revenues: Operated properties (1) (22,512 ) 39,704 17,192 21,650 94,712 116,362 Non-operated properties (2) (4,622 ) 3,362 (1,260 ) 5,051 10,866 15,917 Total natural gas revenues (27,134 ) 43,066 15,932 26,701 105,578 132,279 Crude oil and natural gas sales $ 97,644 $ 77,008 $ 174,652 $ 842,925 $ 294,500 $ 1,137,425 Timing of revenue recognition Goods transferred at a point in time $ 97,644 $ 77,008 $ 174,652 $ 842,925 $ 294,500 $ 1,137,425 Goods transferred over time — — — — — — $ 97,644 $ 77,008 $ 174,652 $ 842,925 $ 294,500 $ 1,137,425 Six months ended June 30, 2020 Six months ended June 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 545,340 $ 209,251 $ 754,591 $ 1,194,047 $ 312,633 $ 1,506,680 Non-operated properties 161,307 16,592 177,899 386,510 23,074 409,584 Total crude oil revenues 706,647 225,843 932,490 1,580,557 335,707 1,916,264 Natural gas revenues: Operated properties (1) (10,923 ) 112,010 101,087 73,111 219,410 292,521 Non-operated properties (2) (2,903 ) 6,721 3,818 15,917 22,307 38,224 Total natural gas revenues (13,826 ) 118,731 104,905 89,028 241,717 330,745 Crude oil and natural gas sales $ 692,821 $ 344,574 $ 1,037,395 $ 1,669,585 $ 577,424 $ 2,247,009 Timing of revenue recognition Goods transferred at a point in time $ 692,821 $ 344,574 $ 1,037,395 $ 1,669,585 $ 577,424 $ 2,247,009 Goods transferred over time — — — — — — $ 692,821 $ 344,574 $ 1,037,395 $ 1,669,585 $ 577,424 $ 2,247,009

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2020
Realized and Unrealized Gains and Losses on Derivative Instruments	Cash receipts and payments in the following table reflect the gains or losses on derivative contracts which matured during the applicable period, calculated as the difference between the contract price and the market settlement price of matured contracts. Non-cash gains and losses below represent the change in fair value of derivative instruments which continued to be held at period end and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period. Three months ended June 30, Six months ended June 30, In thousands 2020 2019 2020 2019 Cash received (paid) on derivatives: Crude oil fixed price swaps (1) $ (7,123 ) $ — $ (7,123 ) $ — Natural gas fixed price swaps — 8,670 — 16,315 Natural gas collars — — — 5,417 Cash received (paid) on derivatives, net (7,123 ) 8,670 (7,123 ) 21,732 Non-cash gain (loss) on derivatives: Crude oil fixed price swaps (10,101 ) — (10,101 ) — Natural gas fixed price swaps 8,749 44,778 8,749 36,074 Natural gas collars 693 — 693 (5,482 ) Non-cash gain (loss) on derivatives, net (659 ) 44,778 (659 ) 30,592 Gain (loss) on derivative instruments, net $ (7,782 ) $ 53,448 $ (7,782 ) $ 52,324

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2020
Fair Value Disclosures [Abstract]
Property Impairments	The following table sets forth the non-cash impairments of both proved and unproved properties for the indicated periods. Proved and unproved property impairments are recorded under the caption “Property impairments” in the unaudited condensed consolidated statements of comprehensive income (loss). Three months ended June 30, Six months ended June 30, In thousands 2020 2019 2020 2019 Proved property impairments $ — $ — $ 205,545 $ — Unproved property impairments 23,929 21,339 40,913 46,655 Total $ 23,929 $ 21,339 $ 246,458 $ 46,655
Fair Values of Financial Instruments not Recorded at Fair Value	The following table sets forth the estimated fair values of financial instruments that are not recorded at fair value in the condensed consolidated financial statements. June 30, 2020 December 31, 2019 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 587,000 $ 587,000 $ 55,000 $ 55,000 Notes payable 25,676 26,200 5,351 5,400 5% Senior Notes due 2022 1,099,306 1,082,700 1,099,165 1,108,700 4.5% Senior Notes due 2023 1,442,434 1,393,400 1,491,339 1,571,400 3.8% Senior Notes due 2024 906,370 864,400 994,310 1,034,200 4.375% Senior Notes due 2028 990,197 882,900 989,661 1,063,700 4.9% Senior Notes due 2044 691,777 559,900 691,688 742,000 Total debt $ 5,742,760 $ 5,396,500 $ 5,326,514 $ 5,580,400

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations	Notes The following table summarizes the face values, maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at June 30, 2020 . In March and April 2020 the Company repurchased a portion of its 2023 Notes and 2024 Notes in open market transactions as further discussed below under the heading Repurchase of Senior Notes . 2022 Notes (1) 2023 Notes 2024 Notes 2028 Notes 2044 Notes Face value (in thousands) $1,100,000 $1,449,625 $911,000 $1,000,000 $700,000 Maturity date Sep 15, 2022 April 15, 2023 June 1, 2024 January 15, 2028 June 1, 2044 Interest payment dates March 15, Sep 15 April 15, Oct 15 June 1, Dec 1 Jan 15, July 15 June 1, Dec 1 Make-whole redemption period (2) — Jan 15, 2023 Mar 1, 2024 Oct 15, 2027 Dec 1, 2043 (1) The Company has the option to redeem all or a portion of its remaining 2022 Notes at the decreasing redemption prices specified in the indenture governing the 2022 Notes plus any accrued and unpaid interest to the date of redemption. (2)
Schedule of Long-term Debt Instruments [Table Text Block]	Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $30.7 million and $33.9 million at June 30, 2020 and December 31, 2019 , respectively, consists of the following. In thousands June 30, 2020 December 31, 2019 Credit facility $ 587,000 $ 55,000 Notes payable 25,676 5,351 5% Senior Notes due 2022 1,099,306 1,099,165 4.5% Senior Notes due 2023 1,442,434 1,491,339 3.8% Senior Notes due 2024 906,370 994,310 4.375% Senior Notes due 2028 990,197 989,661 4.9% Senior Notes due 2044 691,777 691,688 Total debt $ 5,742,760 $ 5,326,514 Less: Current portion of long-term debt 2,206 2,435 Long-term debt, net of current portion $ 5,740,554 $ 5,324,079

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2020
Leases [Abstract]
Operating lease liabilities [Table Text Block]	The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $11.4 million as of June 30, 2020 at discounted present value, which is comprised of the asset classes reflected in the table below. All leases recognized on the Company's balance sheet are classified as operating leases. The amounts disclosed herein primarily represent costs associated with properties operated by the Company that are presented on a gross basis and do not reflect the Company's net proportionate share of such amounts. A portion of these costs have been or will be billed to other working interest owners. Once paid, the Company's share of these costs are included in property and equipment, production expenses, or general and administrative expenses, as applicable. The Company's leasing activities as a lessor are negligible. In thousands Amount Drilling rig commitments $ 4,625 Surface use agreements 5,065 Field equipment 1,078 Other 590 Total $ 11,358
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Minimum future commitments by year for the Company's operating leases as of June 30, 2020 are presented in the table below. Such commitments are reflected at undiscounted values and are reconciled to the discounted present value recognized on the balance sheet. In thousands Amount Remainder of 2020 $ 3,371 2021 2,658 2022 865 2023 812 2024 537 Thereafter 6,682 Total operating lease liabilities, at undiscounted value $ 14,925 Less: Imputed interest (3,567 ) Total operating lease liabilities, at discounted present value $ 11,358 Less: Current portion of operating lease liabilities (5,210 ) Operating lease liabilities, net of current portion $ 6,148
Lease, Cost [Table Text Block]	Additional information for the Company's operating leases is presented below. Lease costs, which are presented on a gross basis and do not reflect the Company's net proportionate share of such amounts, primarily represent costs incurred for drilling rigs, most of which are short term contracts that are not recognized as right-of-use assets and lease liabilities on the balance sheet. Variable lease costs primarily represent differences between minimum payment obligations and actual operating day-rate charges incurred by the Company for its long term drilling rig contracts. Short-term lease costs primarily represent operating day-rate charges for drilling rig contracts with durations of one year or less and month-to-month field equipment rentals. Three months ended June 30, Six months ended June 30, In thousands, except weighted average data 2020 2019 2020 2019 Lease costs: Operating lease costs $ 1,641 $ 3,273 $ 2,901 $ 6,546 Variable lease costs 912 4,691 4,135 7,813 Short-term lease costs 29,460 39,517 80,808 94,678 Total lease costs $ 32,013 $ 47,481 $ 87,844 $ 109,037 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 337 $ — $ 7,339 $ — Operating cash flows from operating leases included in lease liabilities 187 199 415 398 Weighted average remaining lease term as of June 30 (in years) 10.7 6.8 Weighted average discount rate as of June 30 4.3 % 4.7 %

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2020
Restricted stock [Member]
Summary of Changes in Non-vested Shares of Restricted Stock Outstanding	A summary of changes in non-vested restricted shares outstanding for the six months ended June 30, 2020 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2019 3,461,908 $ 46.82 Granted 2,539,749 27.91 Vested (1,011,002 ) 46.26 Forfeited (82,055 ) 38.21 Non-vested restricted shares outstanding at June 30, 2020 4,908,600 $ 37.29

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2020
Effective Tax Rate Reconciliation Table [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	The Company's provision (benefit) for income taxes and resulting effective tax rates were as follows for the periods presented. Three months ended June 30, Six months ended June 30, 2020 2019 2020 2019 Provision (benefit) for income taxes (in thousands) $ (72,143 ) $ 75,649 $ (124,378 ) $ 127,639 Effective tax rate 23.0 % 24.2 % 22.5 % 23.2 %
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The Company's effective tax rate differs from the United States federal statutory tax rate due to the effect of state income taxes, equity compensation, valuation allowances, and other tax items as reflected in the table below. Three months ended June 30, Six months ended June 30, In thousands, except tax rates 2020 2019 2020 2019 Income (loss) before income taxes $ (314,274 ) $ 312,099 $ (553,293 ) $ 550,582 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % 21.0 % Expected income tax provision (benefit) based on U.S. federal statutory tax rate (65,998 ) 65,541 (116,192 ) 115,622 Items impacting the effective tax rate: State and local income taxes, net of federal benefit (10,305 ) 11,538 (17,908 ) 19,337 Equity compensation 585 102 4,471 (8,216 ) Other, net 560 (1,532 ) (2,629 ) 896 Valuation allowance 3,015 — 7,880 — Provision (benefit) for income taxes $ (72,143 ) $ 75,649 $ (124,378 ) $ 127,639 Effective tax rate 23.0 % 24.2 % 22.5 % 23.2 % The Company reduces its deferred tax assets by a valuation allowance if, based upon the weight of available evidence, it is more-likely-than-not that the Company will not realize some portion or all of the deferred tax assets. The Company considers relevant evidence, both positive and negative, to determine the need for a valuation allowance. Information evaluated includes the Company's financial position and results of operations for the current and preceding years, the availability of deferred tax liabilities and tax carrybacks, as well as an evaluation of currently available information about future years. In the first quarter of 2020 the Company determined it was more-likely-than-not that a portion of its Oklahoma net operating loss ("NOL") carryforwards would not be able to be utilized before expiration, and a valuation allowance of approximately $4.9 million was established at March 31, 2020 for the deferred tax assets associated with such NOL carryforwards. The Company recognized an additional valuation allowance of $3.0 million against such deferred tax assets during the three months ended June 30, 2020 , bringing the cumulative valuation allowance to $7.9 million as of June 30, 2020 . The Company will continue to evaluate both the positive and negative evidence on a quarterly basis in determining the need for a valuation allowance with respect to its deferred tax assets. Changes in positive and negative evidence, including differences between estimated and actual results, could result in changes in the valuation of our deferred tax assets that could have a material impact on our consolidated financial statements. Changes in existing tax laws could also affect actual tax results and the realization of deferred tax assets over time.

Organization and Nature of Bu_2

Organization and Nature of Business - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of crude oil and natural gas production concentrated in crude oil	52.00%
Percentage of crude oil and natural gas revenue concentrated in crude oil	90.00%
North Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	54.00%
Percentage of revenues concentrated in geographic areas	67.00%
South Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	46.00%
Percentage of revenues concentrated in geographic areas	33.00%

Basis of Presentation and Sig_4

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Tubular goods and equipment	$ 14,415	$ 14,880
Crude oil	53,870	94,656
Total	$ 68,285	$ 109,536

Basis of Presentation and Sig_5

Basis of Presentation and Significant Accounting Policies - Earnings Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Accounting Policies [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment	23,000		243,000
Net income (loss) attributable to Continental Resources (numerator)
Net income (loss) attributable to Continental Resources (numerator)	$ (239,286)	$ 236,557	$ (424,950)	$ 423,533
Weighted average shares - basic	360,204,000	372,835,000	362,804,000	372,700,000
Non-vested restricted stock (1)	0	1,174,000	0	1,857,000
Weighted average shares - diluted	360,204,000	374,009,000	362,804,000	374,557,000
Net income (loss) per share attributable to Continental Resources:
Basic (in dollars per share)	$ (0.66)	$ 0.63	$ (1.17)	$ 1.14
Diluted (in dollars per share)	$ (0.66)	$ 0.63	$ (1.17)	$ 1.13

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	$ 125,208	$ 132,064
Cash paid for income taxes	8	9
Cash received for income tax refunds (1)	9,485	7
Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	109,200	262,700
Increase (Decrease) in Asset Retirement Obligations	3,725	5,266
Accrued contributions from noncontrolling interests	500	5,600
Accrued distributions to noncontrolling interests	$ 500	$ 1,500

Revenues Disaggregation of Reve

Revenues Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 174,652	$ 1,137,425	$ 1,037,395	$ 2,247,009
Transportation expenses	32,305	53,393	92,807	102,531
Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	174,652	1,137,425	1,037,395	2,247,009
Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0	0	0
North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	97,644	842,925	692,821	1,669,585
North Region [Member] | Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	97,644	842,925	692,821	1,669,585
North Region [Member] | Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0	0	0
South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	77,008	294,500	344,574	577,424
South Region [Member] | Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	77,008	294,500	344,574	577,424
South Region [Member] | Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0	0	0
Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	158,720	1,005,146	932,490	1,916,264
Transportation expenses	23,500	46,000	73,900	87,600
Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	124,778	816,224	706,647	1,580,557
Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	33,942	188,922	225,843	335,707
Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	15,932	132,279	104,905	330,745
Transportation expenses	8,800	7,400	18,900	14,900
Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	(27,134)	26,701	(13,826)	89,028
Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	43,066	105,578	118,731	241,717
Operated properties | Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	126,485	784,528	754,591	1,506,680
Operated properties | Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	96,410	608,442	545,340	1,194,047
Operated properties | Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	30,075	176,086	209,251	312,633
Operated properties | Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	17,192	116,362	101,087	292,521
negative gas revenues			22,700
Operated properties | Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	(22,512)	21,650	(10,923)	73,111
Operated properties | Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	39,704	94,712	112,010	219,410
Non-operated Properties | Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	32,235	220,618	177,899	409,584
Non-operated Properties | Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	28,368	207,782	161,307	386,510
Non-operated Properties | Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	3,867	12,836	16,592	23,074
Non-operated Properties | Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	(1,260)	15,917	3,818	38,224
negative gas revenues			7,800
Non-operated Properties | Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	(4,622)	5,051	(2,903)	15,917
Non-operated Properties | Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 3,362	$ 10,866	$ 6,721	$ 22,307

Derivative Instruments - Summar

Derivative Instruments - Summary of Outstanding Contracts with Respect to Crude Oil (Detail) - Crude Oil [Member] - July 2020 Oil Swap [Member] bbl in Thousands	6 Months Ended
	Jun. 30, 2020$ / bblbbl
Derivative [Line Items]
crude oil production derivative volume | bbl	2,790
Swaps Weighted Average Price | $ / bbl	35.67

Derivative Instruments - Summ_2

Derivative Instruments - Summary of Outstanding Contracts with Respect to Natural Gas (Detail) - Natural Gas [Member] MMBTU in Thousands	6 Months Ended
	Jun. 30, 2020MMBTU$ / MMBTU
Jan 2021 to Mar 2021 Swaps
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	5,400
Swaps Weighted Average Price	2.74
July 2020 to Dec 2020 Swaps [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	17,480
Swaps Weighted Average Price	2.63
Collars
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	11,700
Derivative, Average Floor Price	2.67
Derivative, Average Cap Price	3.40
Minimum [Member] | Collars
Derivative [Line Items]
Derivative, Floor Price	2.65
Derivative, Cap Price	3.31
Maximum [Member] | Collars
Derivative [Line Items]
Derivative, Floor Price	2.70
Derivative, Cap Price	3.48

Derivative Instruments - Realiz

Derivative Instruments - Realized and Unrealized Gains and Losses on Derivative Instruments (Detail) bbl in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020USD ($)$ / bblbbl	Jun. 30, 2019USD ($)	Jun. 30, 2020USD ($)$ / bbl	Jun. 30, 2019USD ($)
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net			$ (659)	$ 30,592
Gain (loss) on derivative instruments, net	$ (7,782)	$ 53,448	$ (7,782)	52,324
April 2020 to June 2020 Oil Swap [Member] | Crude Oil [Member]
Derivatives, Fair Value [Line Items]
crude oil production derivative volume | bbl	1,920
Non-cash gain (loss) on derivatives:
Swaps Weighted Average Price | $ / bbl	29.94		29.94
Swap [Member] | Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	$ (7,123)	0	$ (7,123)	0
Swap [Member] | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	8,670	0	16,315
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	8,749	44,778	8,749	36,074
Collars | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	0	0	5,417
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	693	0	693	(5,482)
Crude Oil and Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(7,123)	8,670	(7,123)	21,732
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(659)	44,778	(659)	30,592
Gain (loss) on derivative instruments, net	$ (7,782)	$ 53,448	$ (7,782)	$ 52,324

Derivative Instruments - Gross

Derivative Instruments - Gross Amounts of Recognized Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gross amounts of recognized assets	$ 9,471	$ 0
Gross amounts offset on balance sheet	(29)	0
Net amounts of assets on balance sheet	9,442	0
Gross amounts of recognized liabilities	(10,130)	0
Gross amounts offset on balance sheet	29	0
Net amounts of liabilities on balance sheet	$ (10,101)	$ 0

Derivative Instruments - Reconc

Derivative Instruments - Reconciles Net Amounts Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative assets	$ 9,442	$ 0
Noncurrent derivative assets	0	0
Net amounts of assets on balance sheet	9,442	0
Derivative liabilities	(10,101)	0
Noncurrent derivative liabilities	0	0
Net amounts of liabilities on balance sheet	(10,101)	0
Total derivative assets (liabilities), net	$ (659)	$ 0

Allowance for Credit Losses (De

Allowance for Credit Losses (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 2.4		$ 2.4		$ 2.4
Cumulative Effect of New Accounting Principle in Period of Adoption			0.1
Accounts Receivable, Credit Loss Expense (Reversal)	0.7	$ 0.1	1.5	$ 0.1
Allowance for credit losses on joint interest receivables [Member]
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 2.3		$ 2.3		$ 2.4

Fair Value Measurements - Valua

Fair Value Measurements - Valuation of Financial Instruments by Pricing Levels (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Derivative assets (liabilities):
Derivative assets (liabilities)	$ (659)	$ 0
Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(1,352)
Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	693
Fair Value, Inputs, Level 1 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 1 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 1 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 2 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(659)
Fair Value, Inputs, Level 2 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(1,352)
Fair Value, Inputs, Level 2 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	693
Fair Value, Inputs, Level 3 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 3 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	$ 0

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020
Fair Value Measurements [Line Items]
Discount factor utilized as standardized measure for future net cash flows	10.00%
Forward commodity price assumption for proved crude oil and natural gas property impairment	3.00%
Forward operating price assumption for proved crude oil and natural gas impairment	3.00%

Fair Value Measurements - Prope

Fair Value Measurements - Property Impairments (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	$ 0	$ 0	$ 205,545	$ 0
Unproved property impairments	23,929	21,339	40,913	46,655
Property impairments	23,929	$ 21,339	246,458	$ 46,655
Proved Oil And Gas Property Fair Value After Impairment	145,600		$ 145,600
Red River Units [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	166,500
Non-core [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	14,500
Property, Plant and Equipment [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	181,000
Inventory Valuation and Obsolescence [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Inventory Write-down	$ 24,500

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values of Financial Instruments not Recorded at Fair Value (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	5.00%
Debt Instrument, Maturity Date, Description	2022
4.5% Senior Notes due 2023
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.50%
Debt Instrument, Maturity Date, Description	2023
3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	3.80%
Debt Instrument, Maturity Date, Description	2024
4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.375%
Debt Instrument, Maturity Date, Description	2028
4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.90%
Debt Instrument, Maturity Date, Description	2044
Carrying Amount
Fair Value Measurements [Line Items]
Credit facility	$ 587,000	$ 55,000
Notes payable	25,676	5,351
Total debt	5,742,760	5,326,514
Carrying Amount | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,099,306	1,099,165
Carrying Amount | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,442,434	1,491,339
Carrying Amount | 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	906,370	994,310
Carrying Amount | 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	990,197	989,661
Carrying Amount | 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	691,777	691,688
Estimated Fair Value
Fair Value Measurements [Line Items]
Credit facility	587,000	55,000
Notes payable	26,200	5,400
Total debt	5,396,500	5,580,400
Estimated Fair Value | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,082,700	1,108,700
Estimated Fair Value | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,393,400	1,571,400
Estimated Fair Value | 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	864,400	1,034,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	882,900	1,063,700
Estimated Fair Value | 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	$ 559,900	$ 742,000

Long-Term Debt - Long-Term Debt

Long-Term Debt - Long-Term Debt (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Less: Current portion of long-term debt	$ (2,206)	$ (2,435)
Long-term debt, net of current portion	$ 5,740,554	5,324,079
5% Senior Notes due 2022
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.00%
Notes payable
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.50%
Notes payable	$ 26,000
3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.80%
4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.375%
4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%
Carrying Amount
Debt Instrument [Line Items]
Credit facility	$ 587,000	55,000
Notes payable	25,676	5,351
Total debt	5,742,760	5,326,514
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,306	1,099,165
Carrying Amount | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,442,434	1,491,339
Carrying Amount | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	906,370	994,310
Carrying Amount | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	990,197	989,661
Carrying Amount | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	691,777	691,688
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	587,000	55,000
Notes payable	26,200	5,400
Total debt	5,396,500	5,580,400
Estimated Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,082,700	1,108,700
Estimated Fair Value | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,393,400	1,571,400
Estimated Fair Value | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	864,400	1,034,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	882,900	1,063,700
Estimated Fair Value | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 559,900	$ 742,000

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	$ 30,700			$ 30,700		$ 33,900
Line of credit facility, maturity date				Apr. 9, 2023
Aggregate amount of lender commitments on credit facility	1,500,000			$ 1,500,000
Line of credit facility, commitment fee percentage, per annum				0.25%
Current portion of long-term debt	2,206			$ 2,206		2,435
Line of Credit Facility, Covenant Terms				0.65
Gain on extinguishment of debt	$ (46,942)	$ (17,600)	$ 0	$ (64,573)	$ 0
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	2.10%			2.10%
Line of Credit Facility, Remaining Borrowing Capacity	$ 908,000			$ 908,000
Senior Notes Due Two Thousand And Twenty Three [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	17,000	33,400		17,000
Debt Instrument, Repurchase Amount	9,800	19,500		$ 9,800
Debt Instrument, Maturity Date				Apr. 15, 2023
Gain on extinguishment of debt	$ (47,000)
2022 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date				Sep. 15, 2022
4.5% Senior Notes due 2023
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.50%			4.50%
Debt Instrument, Maturity Date, Description				2023
Notes payable
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	$ 4,400			$ 4,400
Notes Payable	$ 26,000			$ 26,000
Loan term				10 years
Debt Instrument, stated interest rate	3.50%			3.50%
5% Senior Notes due 2022
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.00%			5.00%
Debt Instrument, Maturity Date, Description				2022
3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	$ 82,000	7,000		$ 82,000
Debt Instrument, Repurchase Amount	$ 43,100	$ 3,800		$ 43,100
Debt Instrument, stated interest rate	3.80%			3.80%
Debt Instrument, Maturity Date, Description				2024
4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.375%			4.375%
Debt Instrument, Maturity Date, Description				2028
4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%			4.90%
Debt Instrument, Maturity Date, Description				2044
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	$ 587,000			$ 587,000		55,000
Notes Payable	26,200			26,200		5,400
Estimated Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,082,700			1,082,700		1,108,700
Estimated Fair Value | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	864,400			864,400		1,034,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	882,900			882,900		1,063,700
Estimated Fair Value | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	559,900			559,900		742,000
Carrying Amount
Debt Instrument [Line Items]
Credit facility	587,000			587,000		55,000
Notes Payable	25,676			25,676		5,351
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,306			1,099,306		1,099,165
Carrying Amount | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	906,370			906,370		994,310
Carrying Amount | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	990,197			990,197		989,661
Carrying Amount | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 691,777			$ 691,777		$ 691,688

Long-Term Debt Long-Term Debt -

Long-Term Debt Long-Term Debt - Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2020USD ($)
2022 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,100,000
Maturity date	Sep. 15, 2022
Interest payment dates	March 15, Sep 15
2023 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,449,625
Maturity date	Apr. 15, 2023
Interest payment dates	April 15, Oct 15
Debt Instrument, Redemption Period, Start Date	Jan. 15, 2023
2024 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 911,000
Maturity date	Jun. 1, 2024
Interest payment dates	June 1, Dec 1
Debt Instrument, Redemption Period, Start Date	Mar. 1, 2024
2028 Notes
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,000,000
Maturity date	Jan. 15, 2028
Interest payment dates	Jan 15, July 15
Debt Instrument, Redemption Period, Start Date	Oct. 15, 2027
2044 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 700,000
Maturity date	Jun. 1, 2044
Interest payment dates	June 1, Dec 1
Debt Instrument, Redemption Period, Start Date	Dec. 1, 2043

Leases (Details)

Leases (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 11,358		$ 11,358
Operating lease costs	1,641	$ 3,273	2,901	$ 6,546
Variable Lease, Cost	912	4,691	4,135	7,813
Short-term Lease, Cost	29,460	39,517	80,808	94,678
Lease, Cost	32,013	47,481	87,844	109,037
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	337	0	7,339	0
Operating cash flows from operating leases	$ 187	$ 199	$ 415	$ 398
Operating Lease, Weighted Average Remaining Lease Term	10 years 8 months 12 days	6 years 9 months 18 days	10 years 8 months 12 days	6 years 9 months 18 days
Weighted average discount rate	4.30%	4.70%	4.30%	4.70%
Drilling rig commitments [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 4,625		$ 4,625
Surface use agreements [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	5,065		5,065
Field equipment [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	1,078		1,078
Other [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 590		$ 590

Leases Leases and lease commitm

Leases Leases and lease commitments, Maturities of operating leases (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease payments remainder of fiscal year	$ 3,371
Operating lease payments, due year two	2,658
Operating lease payments, due year three	865
Operating lease payments, due year four	812
Operating lease payments, due year five	537
Operating lease payments, remaining due thereafter	6,682
Operating lease payments due	14,925
Imputed interest	(3,567)
Operating Lease, Liability	11,358
Current portion of operating leases	(5,210)	$ (3,695)
Operating lease liabilities, net of current portion	$ 6,148	$ 5,433

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies - Additional Information (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2020USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation Agreement Expiration Date	2031
Future Drilling Commitments At Balance Sheet Date	$ 27,000
Drilling Commitments Year One	23,000
Drilling Commitments Year Two	4,000
Operating Lease, Liability	11,358
Purchase Obligation	1,550,000
Purchase Obligation, to be Paid, Remainder of Fiscal Year	107,000
Purchase Obligation, to be Paid, Year Two	226,000
Purchase Obligation, to be Paid, Year Three	255,000
Purchase Obligation, to be Paid, Year Four	255,000
Purchase Obligation, to be Paid, Year Five	220,000
Purchase Obligation, to be Paid, after Year Five	$ 483,000
Future Drilling Commitments End Date	2021-04
Drilling rig commitments [Member]
Long-term Purchase Commitment [Line Items]
Operating Lease, Liability	$ 4,625

Commitments and Contingencies L

Commitments and Contingencies Loss Contingencies (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
Casillas potential legal exposure	$ 200
Legal proceedings recorded as a liability under other noncurrent liabilities	$ 7.5	$ 8.7

Stock Based Compensation - Stoc

Stock Based Compensation - Stock Based Compensation Expenses (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Share-based Payment Arrangement [Abstract]
Non-cash equity compensation	$ 15.3	$ 12.2	$ 31.7	$ 24.3

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)shares
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock available to grant | shares	10,844,493
Fair value at vesting date | $	$ 25
Unrecognized compensation expense related to non-vested | $	$ 100
Unrecognized compensation expense related to non-vested, period for recognition, in years	1 year 8 months 12 days
Restricted stock [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants vest over periods, in years	1 year
Restricted stock [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants vest over periods, in years	3 years
2013 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock available for issue | shares	12,983,543

Stock Based Compensation - Summ

Stock Based Compensation - Summary of Changes in Non Vested Shares of Restricted Stock Outstanding (Detail)	6 Months Ended
	Jun. 30, 2020$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested shares, beginning balance | shares	3,461,908
Granted (unaudited), shares | shares	2,539,749
Vested shares | shares	(1,011,002)
Forfeited (unaudited), shares | shares	(82,055)
Non-vested shares, ending balance | shares	4,908,600
Non-vested, weighted average grant-date fair value, beginning of period | $ / shares	$ 46.82
Granted, weighted average grant-date fair value | $ / shares	27.91
Vested, weighted average grant-date fair value | $ / shares	46.26
Forfeited, weighted average grant-date fair value | $ / shares	38.21
Non-vested, weighted average grant-date fair value, end of period | $ / shares	$ 37.29

Shareholders' Equity Share Repu

Shareholders' Equity Share Repurchase (Details) - USD ($) shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2020	May 31, 2019
Shareholders' Equity [Abstract]
Stock Repurchase Program, Authorized Amount		$ 1,000
Stock Repurchased and Retired During Period, Shares	8.1
Stock Repurchased and Retired During Period, Value	$ 126.9
Cumulative shares repurchased under share repurchase program	13.8
Cumulative treasury stock, retired, cost method, amount	$ 317.1

Shareholders' Equity Dividend (

Shareholders' Equity Dividend (Details) - USD ($) $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2020	Feb. 21, 2020
Dividend [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.05
Dividends payable		$ 18.4

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Taxes [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%		21.00%	21.00%	21.00%
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	$ (65,998)		$ 65,541	$ (116,192)	$ 115,622
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	(10,305)		11,538	(17,908)	19,337
Income Tax Reconciliation Equity Compensation	585		102	4,471	(8,216)
Effective Income Tax Rate Reconciliation, Other Adjustments, Amount	560		(1,532)	(2,629)	896
Income Tax Expense	$ (72,143)		$ 75,649	$ (124,378)	$ 127,639
Effective Income Tax Rate Reconciliation, Percent	23.00%		24.20%	22.50%	23.20%
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	$ 3,015	$ 4,900	$ 0	$ 7,880	$ 0

Income Taxes Provision for inco

Income Taxes Provision for income taxes (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Deferred Tax Assets, Valuation Allowance	$ 7,900		$ 7,900
Income Tax Expense	$ (72,143)	$ 75,649	$ (124,378)	$ 127,639
Effective Income Tax Rate Reconciliation, Percent	23.00%	24.20%	22.50%	23.20%