Continental Resources Inc (CLR) 10-Q 5 Nov 20 2020 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information Document - shares	9 Months Ended
	Sep. 30, 2020	Oct. 31, 2020
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 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	Q3
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		365,234,283
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	Sep. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 21,237	$ 39,400
Receivables:
Crude oil and natural gas sales	475,187	726,876
Joint interest and other	126,135	317,018
Allowance for credit losses	(2,220)	(2,407)
Receivables, Net, Current	599,102	1,041,487
Derivative assets	346	0
Inventories	63,170	109,536
Prepaid expenses and other	15,907	16,592
Total current assets	699,762	1,207,015
Net property and equipment, based on successful efforts method of accounting	14,004,414	14,497,726
Operating lease right-of-use assets	10,396	9,128
Other noncurrent assets	13,652	14,038
Total assets	14,728,224	15,727,907
Current liabilities:
Accounts payable trade	321,975	629,264
Revenues and royalties payable	260,887	470,264
Accrued liabilities and other	151,662	230,368
Derivative liabilities	7,086	0
Current portion of operating leases	4,225	3,695
Current portion of long-term debt	2,225	2,435
Total current liabilities	748,060	1,336,026
Long-term debt, net of current portion	5,629,133	5,324,079
Other noncurrent liabilities:
Deferred income tax liabilities, net	1,650,998	1,787,125
Asset retirement obligations, net of current portion	173,762	151,774
Derivative liabilities, noncurrent	1,820	0
Operating lease liabilities, net of current portion	6,005	5,433
Other noncurrent liabilities	14,332	15,119
Total other noncurrent liabilities	1,846,917	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; 365,112,162 shares issued and outstanding at September 30, 2020; 371,074,036 shares issued and outstanding at December 31, 2019	3,651	3,711
Additional paid-in capital	1,188,891	1,274,732
Retained earnings	4,940,142	5,463,224
Total shareholders’ equity attributable to Continental Resources	6,132,684	6,741,667
Noncontrolling interests	371,430	366,684
Total Equity	6,504,114	7,108,351
Total liabilities and equity	$ 14,728,224	$ 15,727,907

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 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	365,112,162	371,074,036
Common Stock, Shares, Outstanding	365,112,162	371,074,036

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenues:
Crude oil and natural gas sales	$ 701,468	$ 1,081,400	$ 1,738,863	$ 3,328,409
Gain (loss) on derivative instruments, net	(17,853)	1,195	(25,635)	53,519
Crude oil and natural gas service operations	8,755	21,602	35,602	54,886
Total revenues	692,370	1,104,197	1,748,830	3,436,814
Operating costs and expenses:
Production expenses	88,701	114,050	271,852	333,446
Production taxes	50,153	86,931	132,444	267,237
Transportation expenses	55,272	62,038	148,079	164,569
Exploration expenses	1,041	2,472	14,638	7,399
Crude oil and natural gas service operations	3,316	8,224	15,288	26,616
Depreciation, depletion, amortization and accretion	461,191	484,031	1,288,185	1,464,672
Property impairments	18,518	20,199	264,976	66,854
General and administrative expenses	45,273	46,993	129,713	141,837
Net (gain) loss on sale of assets and other	800	535	5,914	647
Total operating costs and expenses	724,265	825,473	2,271,089	2,473,277
Income (loss) from operations	(31,895)	278,724	(522,259)	963,537
Other income (expense):
Interest expense	(63,884)	(68,090)	(192,547)	(204,398)
Gain (loss) on extinguishment of debt	0	(4,584)	64,573	(4,584)
Other	224	1,119	1,385	3,196
Total other income (expense)	(63,660)	(71,555)	(126,589)	(205,786)
Income (loss) before income taxes	(95,555)	207,169	(648,848)	757,751
(Provision) benefit for income taxes	13,972	(49,747)	138,350	(177,386)
Net income (loss)	(81,583)	157,422	(510,498)	580,365
Net loss attributable to noncontrolling interests	(2,161)	(740)	(6,126)	(1,330)
Net income (loss) attributable to Continental Resources	$ (79,422)	$ 158,162	$ (504,372)	$ 581,695
Basic net income (loss) per share (in dollars per share)	$ (0.22)	$ 0.43	$ (1.39)	$ 1.56
Diluted net income (loss) per share (in dollars per share)	$ (0.22)	$ 0.43	$ (1.39)	$ 1.56
Foreign currency translation adjustments	$ 0	$ (18)	$ 0	$ 128
Total other comprehensive income, net of tax	0	(18)	0	128
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(81,583)	157,404	(510,498)	580,493
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(2,161)	(740)	(6,126)	(1,330)
Comprehensive income (loss)	$ (79,422)	$ 158,144	$ (504,372)	$ 581,823

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	581,695
Net loss attributable to noncontrolling interests	(1,330)
Net income (loss)	580,365
Other comprehensive income, net of tax (unaudited)	128
Balance at Sep. 30, 2019		$ 3,717	1,278,482		543	5,269,243	6,551,985
Balance, shares at Sep. 30, 2019		371,730,488
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
Net loss attributable to noncontrolling interests								(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
Net income (loss) attributable to Continental Resources	158,162					158,162	158,162
Net loss attributable to noncontrolling interests	(740)							(740)
Net income (loss)	157,422
Change in dividends payable	160					160	160
Treasury Stock, Value, Acquired, Cost Method	(102,304)			(102,304)			(102,304)
Treasury Stock, Shares, Retired		(3,206,553)
Treasury Stock, Retired, Cost Method, Amount		$ (32)	(102,272)	(102,304)
Other comprehensive income, net of tax (unaudited)	(18)				(18)		(18)
Contributions from Noncontrolling Interests	19,713							19,713
Distributions to Noncontrolling Interests	(3,110)							(3,110)
Stock-based compensation (unaudited)	12,871		12,871				12,871
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		102,945
Repurchased and canceled (unaudited)	(389)	$ 0	(389)				(389)
Repurchased and canceled (unaudited), shares		(13,353)
Forfeited (unaudited), shares		(96,099)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Sep. 30, 2019		$ 3,717	1,278,482		543	5,269,243	6,551,985
Balance, shares at Sep. 30, 2019		371,730,488
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								362,195
Total Equity	6,914,180
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	(126,900)	$ (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	(8,100,000)	(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	$ (504,372)
Net loss attributable to noncontrolling interests	(6,126)
Net income (loss)	(510,498)
Other comprehensive income, net of tax (unaudited)	$ 0
Restricted stock:
Granted (unaudited), shares	2,582,990
Forfeited (unaudited), shares	(136,504)
Balance at Sep. 30, 2020	$ 6,132,684	$ 3,651	1,188,891		0	4,940,142	6,132,684
Balance, shares at Sep. 30, 2020	365,112,162	365,112,162
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)
Net loss attributable to noncontrolling interests								(2,845)
Net income (loss)	(242,131)
Change in dividends payable	2					2	2
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		$ 3,651	1,172,932		0	5,019,561	6,196,144
Balance, shares at Jun. 30, 2020		365,144,243
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								375,108
Total Equity	6,571,252
Net income (loss) attributable to Continental Resources	(79,422)					(79,422)	(79,422)
Net loss attributable to noncontrolling interests	(2,161)							(2,161)
Net income (loss)	(81,583)
Change in dividends payable	3					3	3
Other comprehensive income, net of tax (unaudited)	0
Contributions from Noncontrolling Interests	36							36
Distributions to Noncontrolling Interests	(1,553)							(1,553)
Stock-based compensation (unaudited)	16,330		16,330				16,330
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		43,241
Repurchased and canceled (unaudited)	(371)	$ 0	(371)				(371)
Repurchased and canceled (unaudited), shares		(20,873)
Forfeited (unaudited), shares		(54,449)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Sep. 30, 2020	$ 6,132,684	$ 3,651	$ 1,188,891		$ 0	$ 4,940,142	$ 6,132,684
Balance, shares at Sep. 30, 2020	365,112,162	365,112,162
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests	$ 371,430							$ 371,430
Total Equity	$ 6,504,114

Unaudited Condensed Consolida_2

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Statement of Cash Flows [Abstract]
Net income (loss)	$ (510,498)	$ 580,365
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, Depletion, Amortization and Accretion	1,286,889	1,465,856
Property impairments	264,976	66,854
Non-cash (gain) loss on derivatives	8,560	(1,303)
Stock-based compensation	48,086	37,153
Provision (benefit) for deferred income taxes	(136,127)	177,386
Dry hole costs	6,456	0
Net (gain) loss on sale of assets and other	5,914	647
Gain (Loss) on Extinguishment of Debt	(64,573)	4,584
Other, net	7,811	8,036
Changes in assets and liabilities:
Accounts receivable	435,862	(42,269)
Inventories	21,846	(21,867)
Other current assets	1,196	(3,808)
Accounts payable trade	(150,645)	56,624
Revenues and royalties payable	(209,258)	(309)
Accrued liabilities and other	(80,227)	(15,707)
Other noncurrent assets and liabilities	(1,501)	(366)
Net cash provided by operating activities	934,767	2,311,876
Cash flows from investing activities
Exploration and development	(1,139,447)	(2,268,594)
Purchase of producing crude oil and natural gas properties	(23,318)	(49,324)
Purchase of other property and equipment	(21,306)	(22,875)
Proceeds from sale of assets	2,205	86,866
Net cash used in investing activities	(1,181,866)	(2,253,927)
Cash flows from financing activities
Credit facility borrowings	1,657,000	776,000
Repayment of credit facility	(1,237,000)	(476,000)
Early Repayment of Senior Debt	74,032	500,000
Redemption Premium	0	(4,167)
Proceeds from other debt	26,000	0
Repayment of other debt	(6,130)	(1,754)
Debt issuance costs	(237)	0
Contributions from noncontrolling interests	26,587	104,494
Distributions to noncontrolling interests	(10,814)	(10,493)
Payments for Repurchase of Common Stock	(126,906)	(171,965)
Repurchase of restricted stock for tax withholdings	(7,072)	(21,573)
Payments of Dividends	(18,460)	0
Net cash provided by (used in) financing activities	228,936	(305,458)
Effect of exchange rate changes on cash	0	20
Net change in cash and cash equivalents	(18,163)	(247,489)
Cash and cash equivalents, at beginning of period	39,400	282,749
Cash and cash equivalents, at end of period	$ 21,237	$ 35,260

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 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. Nine months ended September 30, In thousands 2020 2019 Supplemental cash flow information: Cash paid for interest $ 178,082 $ 194,087 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 15,733 4,313 (1) Amount received in the 2020 period primarily represents alternative minimum tax refunds. As of September 30, 2020 and December 31, 2019, the Company ha d $100.1 million a nd $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 September 30, 2020 and December 31, 2019, the Company had $0.1 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 September 30, 2020 and December 31, 2019, the Company had $0.8 million and $1.5 million, respectively, of accrued distributions to noncontrolling interests included in "Revenues and royalties payable" with an offsetting amount in "Equity –

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information	9 Months Ended
	Sep. 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. Nine months ended September 30, In thousands 2020 2019 Supplemental cash flow information: Cash paid for interest $ 178,082 $ 194,087 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 15,733 4,313

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	$ 178,082	$ 194,087
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	100,100	262,700
Increase (Decrease) in Asset Retirement Obligations	15,733	4,313
Accrued contributions from noncontrolling interests	100	5,600
Accrued distributions to noncontrolling interests	$ 800	$ 1,500

Organization and Nature of Busi

Organization and Nature of Business	9 Months Ended
	Sep. 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 55% of its crude oil and natural gas production and 65% of its crude oil and natural gas revenues for the nine months ended September 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 45% of its crude oil and natural gas production and 35% of its crude oil and natural gas revenues for the nine months ended September 30, 2020. The Company's principal producing properties in the South region are located in the SCOOP and STACK areas of Oklahoma.

Basis of Presentation and Signi

Basis of Presentation and Significant Accounting Policies	9 Months Ended
	Sep. 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 September 30, 2020 and for the three and nine month periods ended September 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 nine months ended September 30, 2020 and 2019. Three months ended September 30, Nine months ended September 30, In thousands, except per share data 2020 2019 2020 2019 Net income (loss) attributable to Continental Resources (numerator) $ (79,422) $ 158,162 $ (504,372) $ 581,695 Weighted average shares (denominator): Weighted average shares - basic 360,257 369,739 361,948 371,702 Non-vested restricted stock (1) — 937 — 1,804 Weighted average shares - diluted 360,257 370,676 361,948 373,506 Net income (loss) per share attributable to Continental Resources: Basic $ (0.22) $ 0.43 $ (1.39) $ 1.56 Diluted $ (0.22) $ 0.43 $ (1.39) $ 1.56 (1) For the three and nine months ended September 30, 2020 the Company had a net loss and therefore the potential dilutive effect of approximately 50,000 and 609,000 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 September 30, 2020 and December 31, 2019 consisted of the following: In thousands September 30, 2020 December 31, 2019 Tubular goods and equipment $ 13,657 $ 14,880 Crude oil 49,513 94,656 Total $ 63,170 $ 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 nine month period ended September 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.

Revenues

Revenues	9 Months Ended
	Sep. 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 $46.9 million and $53.0 million for the three months ended September 30, 2020 and 2019, respectively, and $120.8 million and $140.7 million for the nine months ended September 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 $2.5 million and $25.2 million for operated properties for the three and nine months ended September 30, 2020, respectively. 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 $8.4 million and $9.0 million for the three months ended September 30, 2020 and 2019, respectively, and $27.3 million and $23.9 million for the nine months ended September 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 $4.7 million and $12.5 million for the three and nine months ended September 30, 2020, respectively. 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 nine months ended September 30, 2020 and 2019. Three months ended September 30, 2020 Three months ended September 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 346,580 $ 176,585 $ 523,165 $ 593,729 $ 210,851 $ 804,580 Non-operated properties 91,067 9,723 100,790 172,383 12,334 184,717 Total crude oil revenues 437,647 186,308 623,955 766,112 223,185 989,297 Natural gas revenues: Operated properties (1) 2,950 67,986 70,936 10,719 71,370 82,089 Non-operated properties (2) (2,499) 9,076 6,577 3,068 6,946 10,014 Total natural gas revenues 451 77,062 77,513 13,787 78,316 92,103 Crude oil and natural gas sales $ 438,098 $ 263,370 $ 701,468 $ 779,899 $ 301,501 $ 1,081,400 Timing of revenue recognition Goods transferred at a point in time $ 438,098 $ 263,370 $ 701,468 $ 779,899 $ 301,501 $ 1,081,400 Goods transferred over time — — — — — — $ 438,098 $ 263,370 $ 701,468 $ 779,899 $ 301,501 $ 1,081,400 Nine months ended September 30, 2020 Nine months ended September 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 891,920 $ 385,836 $ 1,277,756 $ 1,787,776 $ 523,484 $ 2,311,260 Non-operated properties 252,374 26,315 278,689 558,893 35,408 594,301 Total crude oil revenues 1,144,294 412,151 1,556,445 2,346,669 558,892 2,905,561 Natural gas revenues: Operated properties (1) (7,974) 179,996 172,022 83,831 290,780 374,611 Non-operated properties (2) (5,402) 15,798 10,396 18,985 29,252 48,237 Total natural gas revenues (13,376) 195,794 182,418 102,816 320,032 422,848 Crude oil and natural gas sales $ 1,130,918 $ 607,945 $ 1,738,863 $ 2,449,485 $ 878,924 $ 3,328,409 Timing of revenue recognition Goods transferred at a point in time $ 1,130,918 $ 607,945 $ 1,738,863 $ 2,449,485 $ 878,924 $ 3,328,409 Goods transferred over time — — — — — — $ 1,130,918 $ 607,945 $ 1,738,863 $ 2,449,485 $ 878,924 $ 3,328,409 (1) Operated natural gas revenues for the North region include negative gas revenues totaling $2.5 million and $25.2 million for the three and nine month periods ended September 30, 2020, respectively. (2) Non-operated natural gas revenues for the North region include negative gas revenues totaling $4.7 million and $12.5 million for the three and nine month periods ended September 30, 2020, respectively. 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 September 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 nine months ended September 30, 2020 and 2019 related to performance obligations satisfied in prior reporting periods were not material.

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 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 September 30, 2020 the Company had outstanding derivative contracts as set forth in the tables below. Natural gas derivatives Collars Floors Ceilings Swaps Weighted Average Price Range Weighted Average Price Range Weighted Average Price Period and Type of Contract MMBtus October 2020 - December 2020 Swaps - Henry Hub 17,480,000 $ 2.58 Collars - Henry Hub 8,280,000 $2.60 - $2.80 $ 2.73 $3.05 - $3.21 $ 3.10 January 2021 - December 2021 Swaps - Henry Hub 23,722,000 $ 2.72 Collars - Henry Hub 33,480,000 $2.60 - $3.00 $ 2.72 $3.06 - $4.00 $ 3.48 January 2022 - December 2022 Swaps - Henry Hub 5,475,000 $ 2.44 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 September 30, Nine months ended September 30, In thousands 2020 2019 2020 2019 Cash received (paid) on derivatives: Crude oil fixed price swaps $ (14,205) $ — $ (21,328) $ — Natural gas fixed price swaps 4,253 30,484 4,253 46,799 Natural gas collars — — — 5,417 Cash received (paid) on derivatives, net (9,952) 30,484 (17,075) 52,216 Non-cash gain (loss) on derivatives: Crude oil fixed price swaps 10,101 — — — Natural gas fixed price swaps (17,576) (32,606) (8,827) 3,468 Natural gas collars (426) 3,317 267 (2,165) Non-cash gain (loss) on derivatives, net (7,901) (29,289) (8,560) 1,303 Gain (loss) on derivative instruments, net $ (17,853) $ 1,195 $ (25,635) $ 53,519 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,” “Derivative assets, noncurrent,” “Derivative liabilities,” and “Derivative liabilities, noncurrent” 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 September 30, 2020 December 31, 2019 Commodity derivative assets: Gross amounts of recognized assets $ 2,682 $ — Gross amounts offset on balance sheet (2,336) — Net amounts of assets on balance sheet 346 — Commodity derivative liabilities: Gross amounts of recognized liabilities (11,242) — Gross amounts offset on balance sheet 2,336 — Net amounts of liabilities on balance sheet $ (8,906) $ — The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets. In thousands September 30, 2020 December 31, 2019 Derivative assets $ 346 $ — Derivative assets, noncurrent — — Net amounts of assets on balance sheet 346 — Derivative liabilities (7,086) — Derivative liabilities, noncurrent (1,820) — Net amounts of liabilities on balance sheet (8,906) — Total derivative liabilities, net $ (8,560) $ —

Allowance for Credit Losses (No

Allowance for Credit Losses (Notes)	9 Months Ended
	Sep. 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 $2.2 million and $2.4 million at September 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 less than $0.1 million and $1.4 million for the three months ended September 30, 2020 and 2019, respectively, and $1.4 million and $1.5 million for the nine months ended September 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 September 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 nine month periods ended September 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.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 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 September 30, 2020. The Company had no outstanding derivative instruments at December 31, 2019. Fair value measurements at September 30, 2020 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets (liabilities): Swaps $ — $ (8,827) $ — $ (8,827) Collars — 267 — $ 267 Total $ — $ (8,560) $ — $ (8,560) 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 September 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 three and nine months ended September 30, 2020 the Company determined the carrying amounts of certain proved properties were not recoverable from future cash flows and therefore were impaired. Impairments of proved properties amounted to $1.6 million and $182.6 million for the three and nine months ended September 30, 2020, respectively, which reflect fair value adjustments on legacy properties in the Red River Units totaling $168.1 million, including $1.6 million in the 2020 third quarter, and various non-core properties in the North and South regions totaling $14.5 million. The impaired properties were written down to their estimated fair value at the time of impairment of $145.7 million. Impairments for the nine months ended September 30, 2020 also include a $24.5 million impairment recognized in the first quarter of 2020 to reduce the Company's crude oil inventory to estimated net realizable value at the time of impairment. For the three and nine months ended September 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 nine months ended September 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 September 30, Nine months ended September 30, In thousands 2020 2019 2020 2019 Proved property impairments $ 1,574 $ — $ 207,119 $ — Unproved property impairments 16,944 20,199 57,857 66,854 Total $ 18,518 $ 20,199 $ 264,976 $ 66,854 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. September 30, 2020 December 31, 2019 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 475,000 $ 475,000 $ 55,000 $ 55,000 Notes payable 25,137 25,600 5,351 5,400 5% Senior Notes due 2022 1,099,378 1,090,600 1,099,165 1,108,700 4.5% Senior Notes due 2023 1,443,031 1,379,900 1,491,339 1,571,400 3.8% Senior Notes due 2024 906,645 847,400 994,310 1,034,200 4.375% Senior Notes due 2028 990,345 863,500 989,661 1,063,700 4.9% Senior Notes due 2044 691,822 530,300 691,688 742,000 Total debt $ 5,631,358 $ 5,212,300 $ 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	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $29.5 million and $33.9 million at September 30, 2020 and December 31, 2019, respectively, consists of the following. In thousands September 30, 2020 December 31, 2019 Credit facility $ 475,000 $ 55,000 Notes payable 25,137 5,351 5% Senior Notes due 2022 1,099,378 1,099,165 4.5% Senior Notes due 2023 1,443,031 1,491,339 3.8% Senior Notes due 2024 906,645 994,310 4.375% Senior Notes due 2028 990,345 989,661 4.9% Senior Notes due 2044 691,822 691,688 Total debt $ 5,631,358 $ 5,326,514 Less: Current portion of long-term debt 2,225 2,435 Long-term debt, net of current portion $ 5,629,133 $ 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 $475 million of outstanding borrowings on its credit facility at September 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 September 30, 2020 was 1.9%. The Company had approximately $1.02 billion of borrowing availability on its credit facility at September 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 September 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 September 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 Retirement 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 September 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. Retirement of Senior Notes 2020 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 (loss) on extinguishment of debt” in the unaudited condensed consolidated statements of comprehensive income (loss). 2019 In September 2019, the Company redeemed $500 million of its previously outstanding $1.6 billion of 2022 Notes. The redemption price was equal to 100.833% of the principal amount called for redemption plus accrued and unpaid interest to the redemption date. The aggregate of the principal amount, redemption premium, and accrued interest paid upon redemption was $516.5 million. The Company recorded a pre-tax loss on extinguishment of debt related to the redemption of $4.6 million, which included the redemption premium and pro-rata write-off of deferred financing costs and unamortized debt premium associated with the notes. Notes payable

Leases

Leases	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Lessee, Operating Leases [Text Block]	Leases The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $10.2 million as of September 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 represent 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 $ 3,661 Surface use agreements 4,998 Field equipment 1,026 Other 545 Total $ 10,230 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 September 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 $ 1,872 2021 2,914 2022 868 2023 814 2024 540 Thereafter 6,707 Total operating lease liabilities, at undiscounted value $ 13,715 Less: Imputed interest (3,485) Total operating lease liabilities, at discounted present value $ 10,230 Less: Current portion of operating lease liabilities (4,225) Operating lease liabilities, net of current portion $ 6,005 Additional information for the Company's operating leases is presented below. Lease costs 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. A portion of such lease costs are borne by other interest owners. Three months ended September 30, Nine months ended September 30, In thousands, except weighted average data 2020 2019 2020 2019 Lease costs: Operating lease costs $ 1,636 $ 2,784 $ 4,537 $ 9,330 Variable lease costs 55 3,820 4,190 11,633 Short-term lease costs 13,863 47,956 94,671 142,634 Total lease costs $ 15,554 $ 54,560 $ 103,398 $ 163,597 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 38 $ 615 $ 7,377 $ 615 Operating cash flows from operating leases included in lease liabilities 259 202 674 600 Weighted average remaining lease term as of September 30 (in years) 11.4 9.2 Weighted average discount rate as of September 30 4.4 % 4.8 %

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 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 September 30, 2020. Drilling rig commitments – As of September 30, 2020, the Company has drilling rig contracts with various terms extending to April 2021. Future operating day-rate commitments as of September 30, 2020 total approximately $18 million, of which $12 million is expected to be incurred in the remainder of 2020 and $6 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 $3.7 million that are required to be recognized on the Company's balance sheet at September 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 September 30, 2020 under the arrangements amount to approximately $1.50 billion, of which $54 million is expected to be incurred in the remainder of 2020, $224 million in 2021, $256 million in 2022, $257 million in 2023, $222 million in 2024, and $489 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 alleging the Company breached a Purchase and Sale Agreement (“PSA”) to purchase oil and gas interests in Oklahoma for $200 million. The Company asserted the PSA was terminated due to Casillas’ breach of the PSA and denied the allegations. On October 16, 2020, the parties entered into a settlement agreement to amend and supplement the terms of the PSA, close on the transaction contemplated by the PSA for a negotiated amount, and settle all disputes involved in the litigation or that could have been raised in the litigation. The parties subsequently dismissed their respective claims in the litigation. 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 September 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	9 Months Ended
	Sep. 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 $16.4 million and $12.9 million for the three months ended September 30, 2020 and 2019, respectively, and $48.1 million and $37.2 million for the nine months ended September 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 September 30, 2020, the Company had 10,876,574 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 nine months ended September 30, 2020 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2019 3,461,908 $ 46.82 Granted 2,582,990 27.73 Vested (1,077,656) 45.97 Forfeited (136,504) 36.85 Non-vested restricted shares outstanding at September 30, 2020 4,830,738 $ 37.08

Shareholders' Equity

Shareholders' Equity	9 Months Ended
	Sep. 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 month periods ended June 30, 2020 and September 30, 2020. Through September 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	9 Months Ended
	Sep. 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 September 30, Nine months ended September 30, 2020 2019 2020 2019 Provision (benefit) for income taxes (in thousands) $ (13,972) $ 49,747 $ (138,350) $ 177,386 Effective tax rate 14.6 % 24.0 % 21.3 % 23.4 % 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 September 30, Nine months ended September 30, In thousands, except tax rates 2020 2019 2020 2019 Income (loss) before income taxes $ (95,555) $ 207,169 $ (648,848) $ 757,751 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 (20,067) 43,505 (136,258) 159,128 Items impacting the effective tax rate: State and local income taxes, net of federal benefit (2,988) 7,312 (20,896) 26,648 Equity compensation 214 92 4,685 (8,124) Other, net 2,540 (1,162) (90) (266) Valuation allowance 6,329 — 14,209 — Provision (benefit) for income taxes $ (13,972) $ 49,747 $ (138,350) $ 177,386 Effective tax rate 14.6 % 24.0 % 21.3 % 23.4 % 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 additional valuation allowances of $3.0 million and $6.3 million against such deferred tax assets during the three month periods ended June 30, 2020 and September 30, 2020, respectively, bringing the cumulative valuation allowance to $14.2 million as of September 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)	9 Months Ended
	Sep. 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 55% of its crude oil and natural gas production and 65% of its crude oil and natural gas revenues for the nine months ended September 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 45% of its crude oil and natural gas production and 35% of its crude oil and natural gas revenues for the nine months ended September 30, 2020. The Company's principal producing properties in the South region are located in the SCOOP and STACK areas of Oklahoma.
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 September 30, 2020 and for the three and nine month periods ended September 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 shareBasic 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.
Inventories	InventoriesInventory 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)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Components of Inventories	The components of inventory as of September 30, 2020 and December 31, 2019 consisted of the following: In thousands September 30, 2020 December 31, 2019 Tubular goods and equipment $ 13,657 $ 14,880 Crude oil 49,513 94,656 Total $ 63,170 $ 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 nine months ended September 30, 2020 and 2019. Three months ended September 30, Nine months ended September 30, In thousands, except per share data 2020 2019 2020 2019 Net income (loss) attributable to Continental Resources (numerator) $ (79,422) $ 158,162 $ (504,372) $ 581,695 Weighted average shares (denominator): Weighted average shares - basic 360,257 369,739 361,948 371,702 Non-vested restricted stock (1) — 937 — 1,804 Weighted average shares - diluted 360,257 370,676 361,948 373,506 Net income (loss) per share attributable to Continental Resources: Basic $ (0.22) $ 0.43 $ (1.39) $ 1.56 Diluted $ (0.22) $ 0.43 $ (1.39) $ 1.56

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 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 nine months ended September 30, 2020 and 2019. Three months ended September 30, 2020 Three months ended September 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 346,580 $ 176,585 $ 523,165 $ 593,729 $ 210,851 $ 804,580 Non-operated properties 91,067 9,723 100,790 172,383 12,334 184,717 Total crude oil revenues 437,647 186,308 623,955 766,112 223,185 989,297 Natural gas revenues: Operated properties (1) 2,950 67,986 70,936 10,719 71,370 82,089 Non-operated properties (2) (2,499) 9,076 6,577 3,068 6,946 10,014 Total natural gas revenues 451 77,062 77,513 13,787 78,316 92,103 Crude oil and natural gas sales $ 438,098 $ 263,370 $ 701,468 $ 779,899 $ 301,501 $ 1,081,400 Timing of revenue recognition Goods transferred at a point in time $ 438,098 $ 263,370 $ 701,468 $ 779,899 $ 301,501 $ 1,081,400 Goods transferred over time — — — — — — $ 438,098 $ 263,370 $ 701,468 $ 779,899 $ 301,501 $ 1,081,400 Nine months ended September 30, 2020 Nine months ended September 30, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 891,920 $ 385,836 $ 1,277,756 $ 1,787,776 $ 523,484 $ 2,311,260 Non-operated properties 252,374 26,315 278,689 558,893 35,408 594,301 Total crude oil revenues 1,144,294 412,151 1,556,445 2,346,669 558,892 2,905,561 Natural gas revenues: Operated properties (1) (7,974) 179,996 172,022 83,831 290,780 374,611 Non-operated properties (2) (5,402) 15,798 10,396 18,985 29,252 48,237 Total natural gas revenues (13,376) 195,794 182,418 102,816 320,032 422,848 Crude oil and natural gas sales $ 1,130,918 $ 607,945 $ 1,738,863 $ 2,449,485 $ 878,924 $ 3,328,409 Timing of revenue recognition Goods transferred at a point in time $ 1,130,918 $ 607,945 $ 1,738,863 $ 2,449,485 $ 878,924 $ 3,328,409 Goods transferred over time — — — — — — $ 1,130,918 $ 607,945 $ 1,738,863 $ 2,449,485 $ 878,924 $ 3,328,409 (1) Operated natural gas revenues for the North region include negative gas revenues totaling $2.5 million and $25.2 million for the three and nine month periods ended September 30, 2020, respectively. (2) Non-operated natural gas revenues for the North region include negative gas revenues totaling $4.7 million and $12.5 million for the three and nine month periods ended September 30, 2020, respectively.

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2020
Summary of Outstanding Contracts with Respect to Natural Gas	At September 30, 2020 the Company had outstanding derivative contracts as set forth in the tables below. Natural gas derivatives Collars Floors Ceilings Swaps Weighted Average Price Range Weighted Average Price Range Weighted Average Price Period and Type of Contract MMBtus October 2020 - December 2020 Swaps - Henry Hub 17,480,000 $ 2.58 Collars - Henry Hub 8,280,000 $2.60 - $2.80 $ 2.73 $3.05 - $3.21 $ 3.10 January 2021 - December 2021 Swaps - Henry Hub 23,722,000 $ 2.72 Collars - Henry Hub 33,480,000 $2.60 - $3.00 $ 2.72 $3.06 - $4.00 $ 3.48 January 2022 - December 2022 Swaps - Henry Hub 5,475,000 $ 2.44
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 September 30, Nine months ended September 30, In thousands 2020 2019 2020 2019 Cash received (paid) on derivatives: Crude oil fixed price swaps $ (14,205) $ — $ (21,328) $ — Natural gas fixed price swaps 4,253 30,484 4,253 46,799 Natural gas collars — — — 5,417 Cash received (paid) on derivatives, net (9,952) 30,484 (17,075) 52,216 Non-cash gain (loss) on derivatives: Crude oil fixed price swaps 10,101 — — — Natural gas fixed price swaps (17,576) (32,606) (8,827) 3,468 Natural gas collars (426) 3,317 267 (2,165) Non-cash gain (loss) on derivatives, net (7,901) (29,289) (8,560) 1,303 Gain (loss) on derivative instruments, net $ (17,853) $ 1,195 $ (25,635) $ 53,519
Gross Amounts of Recognized Derivative Assets and Liabilities	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 September 30, 2020 December 31, 2019 Commodity derivative assets: Gross amounts of recognized assets $ 2,682 $ — Gross amounts offset on balance sheet (2,336) — Net amounts of assets on balance sheet 346 — Commodity derivative liabilities: Gross amounts of recognized liabilities (11,242) — Gross amounts offset on balance sheet 2,336 — Net amounts of liabilities on balance sheet $ (8,906) $ —
Derivatives Not Designated as Hedging Instruments	The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets. In thousands September 30, 2020 December 31, 2019 Derivative assets $ 346 $ — Derivative assets, noncurrent — — Net amounts of assets on balance sheet 346 — Derivative liabilities (7,086) — Derivative liabilities, noncurrent (1,820) — Net amounts of liabilities on balance sheet (8,906) — Total derivative liabilities, net $ (8,560) $ —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 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 September 30, Nine months ended September 30, In thousands 2020 2019 2020 2019 Proved property impairments $ 1,574 $ — $ 207,119 $ — Unproved property impairments 16,944 20,199 57,857 66,854 Total $ 18,518 $ 20,199 $ 264,976 $ 66,854
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. September 30, 2020 December 31, 2019 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 475,000 $ 475,000 $ 55,000 $ 55,000 Notes payable 25,137 25,600 5,351 5,400 5% Senior Notes due 2022 1,099,378 1,090,600 1,099,165 1,108,700 4.5% Senior Notes due 2023 1,443,031 1,379,900 1,491,339 1,571,400 3.8% Senior Notes due 2024 906,645 847,400 994,310 1,034,200 4.375% Senior Notes due 2028 990,345 863,500 989,661 1,063,700 4.9% Senior Notes due 2044 691,822 530,300 691,688 742,000 Total debt $ 5,631,358 $ 5,212,300 $ 5,326,514 $ 5,580,400

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations	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 September 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 Retirement 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.
Schedule of Long-term Debt Instruments [Table Text Block]	Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $29.5 million and $33.9 million at September 30, 2020 and December 31, 2019, respectively, consists of the following. In thousands September 30, 2020 December 31, 2019 Credit facility $ 475,000 $ 55,000 Notes payable 25,137 5,351 5% Senior Notes due 2022 1,099,378 1,099,165 4.5% Senior Notes due 2023 1,443,031 1,491,339 3.8% Senior Notes due 2024 906,645 994,310 4.375% Senior Notes due 2028 990,345 989,661 4.9% Senior Notes due 2044 691,822 691,688 Total debt $ 5,631,358 $ 5,326,514 Less: Current portion of long-term debt 2,225 2,435 Long-term debt, net of current portion $ 5,629,133 $ 5,324,079

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Operating lease liabilities [Table Text Block]	The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $10.2 million as of September 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 represent 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 $ 3,661 Surface use agreements 4,998 Field equipment 1,026 Other 545 Total $ 10,230
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Minimum future commitments by year for the Company's operating leases as of September 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 $ 1,872 2021 2,914 2022 868 2023 814 2024 540 Thereafter 6,707 Total operating lease liabilities, at undiscounted value $ 13,715 Less: Imputed interest (3,485) Total operating lease liabilities, at discounted present value $ 10,230 Less: Current portion of operating lease liabilities (4,225) Operating lease liabilities, net of current portion $ 6,005
Lease, Cost [Table Text Block]	Additional information for the Company's operating leases is presented below. Lease costs 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. A portion of such lease costs are borne by other interest owners. Three months ended September 30, Nine months ended September 30, In thousands, except weighted average data 2020 2019 2020 2019 Lease costs: Operating lease costs $ 1,636 $ 2,784 $ 4,537 $ 9,330 Variable lease costs 55 3,820 4,190 11,633 Short-term lease costs 13,863 47,956 94,671 142,634 Total lease costs $ 15,554 $ 54,560 $ 103,398 $ 163,597 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 38 $ 615 $ 7,377 $ 615 Operating cash flows from operating leases included in lease liabilities 259 202 674 600 Weighted average remaining lease term as of September 30 (in years) 11.4 9.2 Weighted average discount rate as of September 30 4.4 % 4.8 %

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 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 nine months ended September 30, 2020 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2019 3,461,908 $ 46.82 Granted 2,582,990 27.73 Vested (1,077,656) 45.97 Forfeited (136,504) 36.85 Non-vested restricted shares outstanding at September 30, 2020 4,830,738 $ 37.08

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 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 September 30, Nine months ended September 30, 2020 2019 2020 2019 Provision (benefit) for income taxes (in thousands) $ (13,972) $ 49,747 $ (138,350) $ 177,386 Effective tax rate 14.6 % 24.0 % 21.3 % 23.4 %
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 September 30, Nine months ended September 30, In thousands, except tax rates 2020 2019 2020 2019 Income (loss) before income taxes $ (95,555) $ 207,169 $ (648,848) $ 757,751 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 (20,067) 43,505 (136,258) 159,128 Items impacting the effective tax rate: State and local income taxes, net of federal benefit (2,988) 7,312 (20,896) 26,648 Equity compensation 214 92 4,685 (8,124) Other, net 2,540 (1,162) (90) (266) Valuation allowance 6,329 — 14,209 — Provision (benefit) for income taxes $ (13,972) $ 49,747 $ (138,350) $ 177,386 Effective tax rate 14.6 % 24.0 % 21.3 % 23.4 % 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 additional valuation allowances of $3.0 million and $6.3 million against such deferred tax assets during the three month periods ended June 30, 2020 and September 30, 2020, respectively, bringing the cumulative valuation allowance to $14.2 million as of September 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)	9 Months Ended
	Sep. 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	54.00%
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	55.00%
Percentage of revenues concentrated in geographic areas	65.00%
South Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	45.00%
Percentage of revenues concentrated in geographic areas	35.00%

Basis of Presentation and Sig_4

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Tubular goods and equipment	$ 13,657	$ 14,880
Crude oil	49,513	94,656
Total	$ 63,170	$ 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		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Accounting Policies [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment	50,000		609,000
Net income (loss) attributable to Continental Resources (numerator)
Net income (loss) attributable to Continental Resources (numerator)	$ (79,422)	$ 158,162	$ (504,372)	$ 581,695
Weighted average shares - basic	360,257,000	369,739,000	361,948,000	371,702,000
Non-vested restricted stock (1)	0	937,000	0	1,804,000
Weighted average shares - diluted	360,257,000	370,676,000	361,948,000	373,506,000
Net income (loss) per share attributable to Continental Resources:
Basic (in dollars per share)	$ (0.22)	$ 0.43	$ (1.39)	$ 1.56
Diluted (in dollars per share)	$ (0.22)	$ 0.43	$ (1.39)	$ 1.56

Revenues Disaggregation of Reve

Revenues Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 701,468	$ 1,081,400	$ 1,738,863	$ 3,328,409
Transportation expenses	55,272	62,038	148,079	164,569
Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	701,468	1,081,400	1,738,863	3,328,409
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	438,098	779,899	1,130,918	2,449,485
North Region [Member] | Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	438,098	779,899	1,130,918	2,449,485
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	263,370	301,501	607,945	878,924
South Region [Member] | Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	263,370	301,501	607,945	878,924
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	623,955	989,297	1,556,445	2,905,561
Transportation expenses	46,900	53,000	120,800	140,700
Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	437,647	766,112	1,144,294	2,346,669
Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	186,308	223,185	412,151	558,892
Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	77,513	92,103	182,418	422,848
Transportation expenses	8,400	9,000	27,300	23,900
Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	451	13,787	(13,376)	102,816
Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	77,062	78,316	195,794	320,032
Operated properties | Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	523,165	804,580	1,277,756	2,311,260
Operated properties | Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	346,580	593,729	891,920	1,787,776
Operated properties | Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	176,585	210,851	385,836	523,484
Operated properties | Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	70,936	82,089	172,022	374,611
negative gas revenues	2,500		25,200
Operated properties | Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	2,950	10,719	(7,974)	83,831
Operated properties | Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	67,986	71,370	179,996	290,780
Non-operated Properties | Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	100,790	184,717	278,689	594,301
Non-operated Properties | Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	91,067	172,383	252,374	558,893
Non-operated Properties | Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	9,723	12,334	26,315	35,408
Non-operated Properties | Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	6,577	10,014	10,396	48,237
negative gas revenues	4,700		12,500
Non-operated Properties | Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	(2,499)	3,068	(5,402)	18,985
Non-operated Properties | Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 9,076	$ 6,946	$ 15,798	$ 29,252

Derivative Instruments - Summar

Derivative Instruments - Summary of Outstanding Contracts with Respect to Natural Gas (Detail) - Natural Gas [Member] MMBTU in Thousands	9 Months Ended
	Sep. 30, 2020MMBTU$ / MMBTU
Jan 2021 to Dec 2021 Swaps
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	23,722
Swaps Weighted Average Price	2.72
October 2020 to Dec 2020 Swaps
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	17,480
Swaps Weighted Average Price	2.58
Oct 2020 to Dec 2020 Collars
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	8,280
Derivative, Average Floor Price	2.73
Derivative, Average Cap Price	3.10
Jan 2022 to Dec 2022 Swaps
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	5,475
Swaps Weighted Average Price	2.44
Jan 2021 to Dec 2021 Collars
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	33,480
Derivative, Average Floor Price	2.72
Derivative, Average Cap Price	3.48
Minimum [Member] | Collars
Derivative [Line Items]
Derivative, Floor Price	2.60
Derivative, Cap Price	3.05
Maximum [Member] | Collars
Derivative [Line Items]
Derivative, Floor Price	3
Derivative, Cap Price	4

Derivative Instruments - Realiz

Derivative Instruments - Realized and Unrealized Gains and Losses on Derivative Instruments (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net			$ (8,560)	$ 1,303
Gain (loss) on derivative instruments, net	$ (17,853)	$ 1,195	(25,635)	53,519
Swap [Member] | Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(14,205)	0	(21,328)	0
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	10,101	0	0	0
Swap [Member] | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	4,253	30,484	4,253	46,799
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(17,576)	(32,606)	(8,827)	3,468
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	(426)	3,317	267	(2,165)
Crude Oil and Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(9,952)	30,484	(17,075)	52,216
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(7,901)	(29,289)	(8,560)	1,303
Gain (loss) on derivative instruments, net	$ (17,853)	$ 1,195	$ (25,635)	$ 53,519

Derivative Instruments - Gross

Derivative Instruments - Gross Amounts of Recognized Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gross amounts of recognized assets	$ 2,682	$ 0
Gross amounts offset on balance sheet	(2,336)	0
Net amounts of assets on balance sheet	346	0
Gross amounts of recognized liabilities	(11,242)	0
Gross amounts offset on balance sheet	2,336	0
Net amounts of liabilities on balance sheet	$ (8,906)	$ 0

Derivative Instruments - Reconc

Derivative Instruments - Reconciles Net Amounts Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative assets	$ 346	$ 0
Noncurrent derivative assets	0	0
Net amounts of assets on balance sheet	346	0
Derivative liabilities	(7,086)	0
Derivative liabilities, noncurrent	(1,820)	0
Net amounts of liabilities on balance sheet	(8,906)	0
Total derivative assets (liabilities), net	$ (8,560)	$ 0

Allowance for Credit Losses (De

Allowance for Credit Losses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 2.2		$ 2.2		$ 2.4
Cumulative Effect of New Accounting Principle in Period of Adoption			0.1
Accounts Receivable, Credit Loss Expense (Reversal)	0.1	$ 1.4	1.4	$ 1.5
Allowance for credit losses on joint interest receivables [Member]
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 2.2		$ 2.2		$ 2.4

Fair Value Measurements - Valua

Fair Value Measurements - Valuation of Financial Instruments by Pricing Levels (Detail) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative assets (liabilities):
Derivative assets (liabilities)	$ (8,560)	$ 0
Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(8,827)
Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	267
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)	(8,560)
Fair Value, Inputs, Level 2 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(8,827)
Fair Value, Inputs, Level 2 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	267
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)	9 Months Ended
	Sep. 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		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	$ 1,574	$ 0	$ 207,119	$ 0
Unproved property impairments	16,944	20,199	57,857	66,854
Property impairments	18,518	$ 20,199	264,976	$ 66,854
Proved Oil And Gas Property Fair Value After Impairment	145,700		145,700
Red River Units [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments			168,100
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	$ 1,600		182,600
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	9 Months Ended
	Sep. 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	$ 475,000	$ 55,000
Notes payable	25,137	5,351
Total debt	5,631,358	5,326,514
Carrying Amount | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,099,378	1,099,165
Carrying Amount | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,443,031	1,491,339
Carrying Amount | 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	906,645	994,310
Carrying Amount | 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	990,345	989,661
Carrying Amount | 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	691,822	691,688
Estimated Fair Value
Fair Value Measurements [Line Items]
Credit facility	475,000	55,000
Notes payable	25,600	5,400
Total debt	5,212,300	5,580,400
Estimated Fair Value | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,090,600	1,108,700
Estimated Fair Value | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,379,900	1,571,400
Estimated Fair Value | 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	847,400	1,034,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	863,500	1,063,700
Estimated Fair Value | 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	$ 530,300	$ 742,000

Long-Term Debt - Long-Term Debt

Long-Term Debt - Long-Term Debt (Detail) - USD ($) $ in Thousands	Sep. 30, 2020	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Less: Current portion of long-term debt	$ (2,225)		$ (2,435)
Long-term debt, net of current portion	$ 5,629,133		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	$ 475,000		55,000
Notes payable	25,137		5,351
Total debt	5,631,358		5,326,514
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,378		1,099,165
Carrying Amount | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,443,031		1,491,339
Carrying Amount | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	906,645		994,310
Carrying Amount | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	990,345		989,661
Carrying Amount | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	691,822		691,688
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	475,000		55,000
Notes payable	25,600		5,400
Total debt	5,212,300		5,580,400
Estimated Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,090,600		1,108,700
Estimated Fair Value | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,379,900		1,571,400
Estimated Fair Value | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	847,400		1,034,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	863,500		1,063,700
Estimated Fair Value | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 530,300		$ 742,000

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Apr. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	$ 29,500				$ 29,500			$ 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	2,225				$ 2,225			2,435
Line of Credit Facility, Covenant Terms					0.65
Gain (Loss) on Extinguishment of Debt	$ 0		$ (17,600)	$ 4,584	$ (64,573)	$ 4,584
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	1.90%				1.90%
Line of Credit Facility, Remaining Borrowing Capacity	$ 1,020,000				$ 1,020,000
Senior Notes Due Two Thousand And Twenty Three [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount			33,400				$ 17,000
Debt Instrument, Repurchase Amount			19,500				9,800
Debt Instrument, Maturity Date					Apr. 15, 2023
Gain (Loss) on Extinguishment of Debt		$ (47,000)
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
Notes Payable		$ 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			7,000				82,000
Debt Instrument, Repurchase Amount			$ 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
2022 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchase Amount				500,000		$ 500,000
Debt Instrument, Maturity Date					Sep. 15, 2022
Debt Instrument, Redemption Price, Percentage						100.833%
Total redemption amount				$ 516,500		$ 516,500
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	$ 475,000				$ 475,000			55,000
Notes Payable	25,600				25,600			5,400
Estimated Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,090,600				1,090,600			1,108,700
Estimated Fair Value | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	847,400				847,400			1,034,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	863,500				863,500			1,063,700
Estimated Fair Value | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	530,300				530,300			742,000
Carrying Amount
Debt Instrument [Line Items]
Credit facility	475,000				475,000			55,000
Notes Payable	25,137				25,137			5,351
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,378				1,099,378			1,099,165
Carrying Amount | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	906,645				906,645			994,310
Carrying Amount | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	990,345				990,345			989,661
Carrying Amount | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 691,822				$ 691,822			$ 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	9 Months Ended
	Sep. 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		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 10,230		$ 10,230
Operating lease costs	1,636	$ 2,784	4,537	$ 9,330
Variable Lease, Cost	55	3,820	4,190	11,633
Short-term Lease, Cost	13,863	47,956	94,671	142,634
Lease, Cost	15,554	54,560	103,398	163,597
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	38	615	7,377	615
Operating cash flows from operating leases	$ 259	$ 202	$ 674	$ 600
Operating Lease, Weighted Average Remaining Lease Term	11 years 4 months 24 days	9 years 2 months 12 days	11 years 4 months 24 days	9 years 2 months 12 days
Weighted average discount rate	4.40%	4.80%	4.40%	4.80%
Drilling rig commitments [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 3,661		$ 3,661
Surface use agreements [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	4,998		4,998
Field equipment [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	1,026		1,026
Other [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 545		$ 545

Leases Leases and lease commitm

Leases Leases and lease commitments, Maturities of operating leases (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease payments remainder of fiscal year	$ 1,872
Operating lease payments, due year two	2,914
Operating lease payments, due year three	868
Operating lease payments, due year four	814
Operating lease payments, due year five	540
Operating lease payments, remaining due thereafter	6,707
Operating lease payments due	13,715
Imputed interest	(3,485)
Operating Lease, Liability	10,230
Current portion of operating leases	(4,225)	$ (3,695)
Operating lease liabilities, net of current portion	$ 6,005	$ 5,433

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies - Additional Information (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation Agreement Expiration Date	2031
Future Drilling Commitments At Balance Sheet Date	$ 18,000
Drilling Commitments Year One	12,000
Drilling Commitments Year Two	6,000
Operating Lease, Liability	10,230
Purchase Obligation	1,500,000
Purchase Obligation, to be Paid, Remainder of Fiscal Year	54,000
Purchase Obligation, to be Paid, Year Two	224,000
Purchase Obligation, to be Paid, Year Three	256,000
Purchase Obligation, to be Paid, Year Four	257,000
Purchase Obligation, to be Paid, Year Five	222,000
Purchase Obligation, to be Paid, after Year Five	$ 489,000
Future Drilling Commitments End Date	2021-04
Drilling rig commitments [Member]
Long-term Purchase Commitment [Line Items]
Operating Lease, Liability	$ 3,661

Commitments and Contingencies L

Commitments and Contingencies Loss Contingencies (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
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		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Share-based Payment Arrangement [Abstract]
Non-cash equity compensation	$ 16.4	$ 12.9	$ 48.1	$ 37.2

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2020USD ($)shares
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock available to grant | shares	10,876,574
Fair value at vesting date | $	$ 27
Unrecognized compensation expense related to non-vested | $	$ 82
Unrecognized compensation expense related to non-vested, period for recognition, in years	1 year 6 months
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)	9 Months Ended
	Sep. 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	2,582,990
Vested shares | shares	(1,077,656)
Forfeited (unaudited), shares | shares	(136,504)
Non-vested shares, ending balance | shares	4,830,738
Non-vested, weighted average grant-date fair value, beginning of period | $ / shares	$ 46.82
Granted, weighted average grant-date fair value | $ / shares	27.73
Vested, weighted average grant-date fair value | $ / shares	45.97
Forfeited, weighted average grant-date fair value | $ / shares	36.85
Non-vested, weighted average grant-date fair value, end of period | $ / shares	$ 37.08

Shareholders' Equity Share Repu

Shareholders' Equity Share Repurchase (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020	Sep. 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 Thousands	Feb. 21, 2020	Sep. 30, 2020	Sep. 30, 2019
Dividend [Abstract]
Common Stock, Dividends, Per Share, Declared		$ 0.05
Payments of Dividends	$ 18,400	$ 18,460	$ 0

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 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	$ (20,067)			$ 43,505	$ (136,258)	$ 159,128
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	(2,988)			7,312	(20,896)	26,648
Income Tax Reconciliation Equity Compensation	214			92	4,685	(8,124)
Effective Income Tax Rate Reconciliation, Other Adjustments, Amount	2,540			(1,162)	(90)	(266)
Income Tax Expense	$ (13,972)			$ 49,747	$ (138,350)	$ 177,386
Effective Income Tax Rate Reconciliation, Percent	14.60%			24.00%	21.30%	23.40%
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	$ 6,329	$ 3,000	$ 4,900	$ 0	$ 14,209	$ 0

Income Taxes Provision for inco

Income Taxes Provision for income taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Deferred Tax Assets, Valuation Allowance	$ 14,200		$ 14,200
Income Tax Expense	$ (13,972)	$ 49,747	$ (138,350)	$ 177,386
Effective Income Tax Rate Reconciliation, Percent	14.60%	24.00%	21.30%	23.40%