Continental Resources Inc (CLR) 10-Q3 Nov 212021 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information Document - shares	9 Months Ended
Document and Entity Information Document - shares	Sep. 30, 2021	Oct. 25, 2021
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
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	2021
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		365,580,875
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, 2021	Dec. 31, 2020
Commitments and contingencies (Note 8)
Current assets:
Cash and cash equivalents	693,649	47,470
Receivables:
Crude oil and natural gas sales	902,580	561,127
Joint interest and other	248,230	143,829
Allowance for credit losses	(2,977)	(2,462)
Receivables, Net, Current	1,147,833	702,494
Derivative assets	314	15,303
Inventories	119,285	72,157
Prepaid expenses and other	17,561	15,121
Total current assets	1,978,642	852,545
Net property and equipment, based on successful efforts method of accounting	13,475,204	13,737,292
Operating lease right-of-use assets	19,368	8,557
Derivative Asset, Noncurrent	1,773	0
Other noncurrent assets	31,176	34,704
Total assets	15,506,163	14,633,098
Current liabilities:
Accounts payable trade	527,268	361,704
Revenues and royalties payable	510,986	327,029
Accrued liabilities and other	230,488	167,013
Derivative liabilities	131,616	227
Current portion of operating leases	1,895	2,588
Current portion of long-term debt	2,306	2,245
Total current liabilities	1,404,559	860,806
Long-term debt, net of current portion	4,741,729	5,530,173
Other noncurrent liabilities:
Deferred income tax liabilities, net	1,911,270	1,620,154
Asset retirement obligations, net of current portion	192,788	177,194
Derivative liabilities, noncurrent	2,172	1,584
Operating lease liabilities, net of current portion	17,326	5,839
Other noncurrent liabilities	15,253	14,623
Total other noncurrent liabilities	2,138,809	1,819,394
Commitments and contingencies (Note 8)
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; 365,596,400 shares issued and outstanding at September 30, 2021; 365,220,435 shares issued and outstanding at December 31, 2020	3,656	3,652
Additional paid-in capital	1,174,755	1,205,148
Retained earnings	5,670,478	4,847,646
Total shareholders’ equity attributable to Continental Resources	6,848,889	6,056,446
Noncontrolling interests	372,177	366,279
Total Equity	7,221,066	6,422,725
Total liabilities and equity	$ 15,506,163	$ 14,633,098

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2021	Dec. 31, 2020
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	365,596,400	365,220,435
Common Stock, Shares, Outstanding	365,596,400	365,220,435

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income (loss) before income taxes	$ 486,162	$ (95,555)	$ 1,211,386	$ (648,848)
Revenues:
Crude oil and natural gas sales	1,456,181	701,468	3,986,628	1,738,863
Loss on derivative instruments, net	(127,110)	(17,853)	(232,795)	(25,635)
Crude oil and natural gas service operations	12,341	8,755	38,519	35,602
Total revenues	1,341,412	692,370	3,792,352	1,748,830
Operating costs and expenses:
Production expenses	103,222	88,701	292,791	271,852
Production taxes	102,398	50,153	280,667	132,444
Transportation expenses	53,969	55,272	156,670	148,079
Exploration expenses	2,534	1,041	9,470	14,638
Crude oil and natural gas service operations	4,884	3,316	15,037	15,288
Depreciation, depletion, amortization and accretion	465,357	461,191	1,446,823	1,288,185
Property impairments	7,945	18,518	30,991	264,976
General and administrative expenses	58,421	45,273	166,822	129,713
Net (gain) loss on sale of assets and other	(3,029)	800	(3,496)	5,914
Total operating costs and expenses	795,701	724,265	2,395,775	2,271,089
Income (loss) from operations	545,711	(31,895)	1,396,577	(522,259)
Other income (expense):
Interest expense	(59,894)	(63,884)	(185,796)	(192,547)
Gain (loss) on extinguishment of debt	0	0	(290)	64,573
Other	345	224	895	1,385
Total other income (expense)	(59,549)	(63,660)	(185,191)	(126,589)
Income (loss) before income taxes	486,162	(95,555)	1,211,386	(648,848)
(Provision) benefit for income taxes	(115,641)	13,972	(291,116)	138,350
Net income (loss)	370,521	(81,583)	920,270	(510,498)
Net loss attributable to noncontrolling interests	1,193	(2,161)	1,975	(6,126)
Net income (loss) attributable to Continental Resources	$ 369,328	$ (79,422)	$ 918,295	$ (504,372)
Basic net income (loss) per share (in dollars per share)	$ 1.02	$ (0.22)	$ 2.54	$ (1.39)
Diluted net income (loss) per share (in dollars per share)	$ 1.01	$ (0.22)	$ 2.52	$ (1.39)

Condensed Consolidated Statemen

Condensed Consolidated Statements of Shareholders Equity - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-In Capital	Treasury Stock [Member]	Retained Earnings	Continental Resources Shareholders' Equity	Noncontrolling Interest
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests							$ 366,684
Total Equity	$ 7,108,351
Balance at Dec. 31, 2019		$ 3,711	$ 1,274,732		$ 5,463,224	$ 6,741,667
Balance, shares at Dec. 31, 2019		371,074,036
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	(504,372)				(504,372)	(504,372)
Net loss attributable to noncontrolling interests	(6,126)						(6,126)
Net income (loss)	(510,498)
Cumulative Effect of New Accounting Principle in Period of Adoption	137				137	137
Dividends, Common Stock, Cash	(18,580)				(18,580)	(18,580)
Change in dividends payable	7				7	7
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	21,001						21,001
Distributions to Noncontrolling Interests	(10,129)						(10,129)
Stock-based compensation (unaudited)	48,054		48,054			48,054
Restricted stock:
Granted (unaudited)	26	$ 26				26
Granted (unaudited), shares		2,582,990
Repurchased and canceled (unaudited)	$ (7,072)	$ 2	(7,070)			(7,072)
Repurchased and canceled (unaudited), shares	(8,100,000)	(286,256)
Forfeited (unaudited), shares		(136,504)
Forfeitures (unaudited)	$ (3)	$ (3)				(3)
Balance at Sep. 30, 2020		$ 3,651	1,188,891		4,940,142	6,132,684
Balance, shares at Sep. 30, 2020		365,112,162
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests							375,108
Total Equity	6,571,252
Balance at Jun. 30, 2020		$ 3,651	1,172,932		5,019,561	6,196,144
Balance, shares at Jun. 30, 2020		365,144,243
Increase (Decrease) in Stockholders' Equity [Roll Forward]
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
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		$ 3,651	1,188,891		4,940,142	6,132,684
Balance, shares at Sep. 30, 2020		365,112,162
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests							371,430
Total Equity	6,504,114
Noncontrolling interests	366,279						366,279
Total Equity	6,422,725
Balance at Dec. 31, 2020	$ 6,056,446	$ 3,652	1,205,148		4,847,646	6,056,446
Balance, shares at Dec. 31, 2020	365,220,435	365,220,435
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	$ 918,295				918,295	918,295
Net loss attributable to noncontrolling interests	1,975						1,975
Net income (loss)	920,270
Dividends, Common Stock, Cash	(40,429)				(40,429)	(40,429)
Cash dividends declared ($0.15 per share)	55,132				55,132	55,132
Change in dividends payable	98				98	98
Treasury Stock, Value, Acquired, Cost Method	(65,256)			(65,256)		(65,256)
Treasury Stock, Shares, Retired		1,916,069
Treasury Stock, Retired, Cost Method, Amount		$ 19	65,237	(65,256)
Contributions from Noncontrolling Interests	21,263						21,263
Distributions to Noncontrolling Interests	(17,340)						(17,340)
Stock-based compensation (unaudited)	45,024		45,024			45,024
Restricted stock:
Granted (unaudited)	$ 29	$ 29				29
Granted (unaudited), shares	2,900,923	2,900,923
Repurchased and canceled (unaudited)	$ (10,184)	$ (4)	(10,180)			(10,184)
Repurchased and canceled (unaudited), shares		(426,255)
Forfeited (unaudited), shares	(182,634)	(182,634)
Forfeitures (unaudited)	$ (2)	$ (2)				(2)
Balance at Sep. 30, 2021	$ 6,848,889	$ 3,656	1,174,755		5,670,478	6,848,889
Balance, shares at Sep. 30, 2021	365,596,400	365,596,400
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests							369,586
Total Equity	$ 6,955,674
Balance at Jun. 30, 2021		$ 3,676	1,226,223		5,356,189	6,586,088
Balance, shares at Jun. 30, 2021		367,563,899
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	369,328				369,328	369,328
Net loss attributable to noncontrolling interests	1,193						1,193
Net income (loss)	370,521
Cash dividends declared ($0.15 per share)	55,132				55,132	55,132
Change in dividends payable	93				93	93
Treasury Stock, Value, Acquired, Cost Method	(65,256)			(65,256)		(65,256)
Treasury Stock, Shares, Retired		1,916,069
Treasury Stock, Retired, Cost Method, Amount	(65,300)	$ 19	65,237	$ (65,256)
Contributions from Noncontrolling Interests	6,788						6,788
Distributions to Noncontrolling Interests	(5,390)						(5,390)
Stock-based compensation (unaudited)	14,506		14,506			14,506
Restricted stock:
Granted (unaudited)	0	$ 0				0
Granted (unaudited), shares		47,701
Repurchased and canceled (unaudited)	$ (737)	$ 0	(737)			(737)
Repurchased and canceled (unaudited), shares	(1,900,000)	(19,003)
Forfeited (unaudited), shares		(80,128)
Forfeitures (unaudited)	$ (1)	$ (1)				(1)
Balance at Sep. 30, 2021	$ 6,848,889	$ 3,656	$ 1,174,755		$ 5,670,478	$ 6,848,889
Balance, shares at Sep. 30, 2021	365,596,400	365,596,400
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests	$ 372,177						$ 372,177
Total Equity	$ 7,221,066

Unaudited Condensed Consolida_2

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Statement of Cash Flows [Abstract]
Net income (loss)	$ 920,270	$ (510,498)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, Depletion, Amortization and Accretion	1,445,129	1,286,889
Property impairments	30,991	264,976
Non-cash loss on derivatives	145,194	8,560
Stock-based compensation	44,918	48,086
Provision (benefit) for deferred income taxes	291,116	(136,127)
Dry hole costs	0	6,456
Net (gain) loss on sale of assets and other	(3,496)	5,914
Gain (Loss) on Extinguishment of Debt	290	(64,573)
Other, net	7,465	7,811
Changes in assets and liabilities:
Accounts receivable	(444,748)	435,862
Inventories	(47,128)	21,846
Other current assets	(1,894)	1,196
Accounts payable trade	96,785	(150,645)
Revenues and royalties payable	183,050	(209,258)
Accrued liabilities and other	60,690	(80,227)
Other noncurrent assets and liabilities	21	(1,501)
Net cash provided by operating activities	2,728,653	934,767
Cash flows from investing activities
Exploration and development	(905,974)	(1,139,447)
Purchase of producing crude oil and natural gas properties	(175,441)	(23,318)
Purchase of other property and equipment	(46,948)	(21,306)
Proceeds from sale of assets	4,562	2,205
Net cash used in investing activities	(1,123,801)	(1,181,866)
Cash flows from financing activities
Credit facility borrowings	1,063,000	1,657,000
Repayment of credit facility	(1,223,000)	(1,237,000)
Redemption of Senior Notes	(630,782)	(74,032)
Proceeds from other debt	0	26,000
Repayment of other debt	(1,674)	(6,130)
Debt issuance costs	0	(237)
Contributions from noncontrolling interests	19,812	26,587
Distributions to noncontrolling interests	(16,535)	(10,814)
Repurchase of common stock	(65,256)	(126,906)
Repurchase of restricted stock for tax withholdings	(10,184)	(7,072)
Dividends paid on common stock	(94,054)	(18,460)
Net cash provided by (used in) financing activities	(958,673)	228,936
Net change in cash and cash equivalents	646,179	(18,163)
Cash and cash equivalents, at beginning of period	47,470	39,400
Cash and cash equivalents, at end of period	$ 693,649	$ 21,237

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
Supplemental Cash Flow Information	Sep. 30, 2021
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 2021 2020 Supplemental cash flow information: Cash paid for interest $ 164,874 $ 178,082 Cash paid for income taxes 3 8 Cash received for income tax refunds (1) 9 9,485 Non-cash investing activities: Asset retirement obligation additions and revisions, net 9,818 15,733 (1) Amount received in the 2020 period primarily represents alternative minimum tax refunds. As of September 30, 2021 and December 31, 2020, the Company ha d $194.9 million a nd $128.8 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, 2021 and December 31, 2020, the Company had $1.5 million and $0.1 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, 2021 and December 31, 2020, the Company had $1.8 million and $1.0 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
Supplemental Cash Flow Information	Sep. 30, 2021
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 2021 2020 Supplemental cash flow information: Cash paid for interest $ 164,874 $ 178,082 Cash paid for income taxes 3 8 Cash received for income tax refunds (1) 9 9,485 Non-cash investing activities: Asset retirement obligation additions and revisions, net 9,818 15,733

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Supplemental Cash Flow Elements [Abstract]
Cash paid for income taxes	$ 3	$ 8
Cash received for income tax refunds (1)	9	9,485
Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	194,900	128,800
Increase (Decrease) in Asset Retirement Obligations	9,818	15,733
Accrued contributions from noncontrolling interests	1,500	100
Accrued distributions to noncontrolling interests	1,800	1,000
Interest Paid, Excluding Capitalized Interest, Operating Activities	$ 164,874	$ 178,082

Organization and Nature of Busi

Organization and Nature of Business	9 Months Ended
Organization and Nature of Business	Sep. 30, 2021
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, Wyoming Powder River Basin, 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 62% of its crude oil and natural gas revenues for the nine months ended September 30, 2021. The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana and the Powder River Basin of Wyoming. The Company's operations in the South region comprised 45% of its crude oil and natural gas production and 38% of its crude oil and natural gas revenues for the nine months ended September 30, 2021. 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
Basis of Presentation and Significant Accounting Policies	Sep. 30, 2021
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, 2020 (“2020 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, 2021 and for the three and nine month periods ended September 30, 2021 and 2020 are unaudited. The condensed consolidated balance sheet as of December 31, 2020 was derived from the audited balance sheet included in the 2020 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, 2021 and 2020. Three months ended September 30, Nine months ended September 30, In thousands, except per share data 2021 2020 2021 2020 Net income (loss) attributable to Continental Resources (numerator) $ 369,328 $ (79,422) $ 918,295 $ (504,372) Weighted average shares (denominator): Weighted average shares - basic 360,563 360,257 360,899 361,948 Non-vested restricted stock (1) 3,685 — 3,580 — Weighted average shares - diluted 364,248 360,257 364,479 361,948 Net income (loss) per share attributable to Continental Resources: Basic $ 1.02 $ (0.22) $ 2.54 $ (1.39) Diluted $ 1.01 $ (0.22) $ 2.52 $ (1.39) (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. Credit risk The Company's principal exposure to credit risk is through receivables associated with the sale of its crude oil and natural gas production and 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.” The Company determines its credit loss allowance for each portfolio segment 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, the ability to recoup amounts owed through netting of production proceeds, the balance of co-owner prepayments if any, and a party's ability to pay. Historically, the Company's credit losses have been immaterial. There were no significant write-offs, recoveries, or changes in the Company's allowance for credit losses during the three and nine month periods ended September 30, 2021 and 2020. 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 and natural gas 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, 2021 and December 31, 2020 consisted of the following: In thousands September 30, 2021 December 31, 2020 Tubular goods and equipment $ 12,017 $ 13,671 Crude oil and natural gas 107,268 58,486 Total $ 119,285 $ 72,157 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 operations for the nine month period ended September 30, 2020. Adoption of new accounting pronouncement On January 1, 2021 the Company adopted Accounting Standards Update ("ASU") 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. This standard eliminates certain exceptions to the guidance in Topic 740 related

Revenues

Revenues	9 Months Ended
Revenues	Sep. 30, 2021
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 $45.2 million and $46.9 million for the three months ended September 30, 2021 and 2020, respectively, and $129.2 million and $120.8 million for the nine months ended September 30, 2021 and 2020, 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 operations. Such payments for operated properties, which are referred to herein as negative gas revenues, were immaterial for the three and nine months ended September 30, 2021 and totaled $2.5 million and $25.2 million 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 $8.7 million and $8.4 million for the three months ended September 30, 2021 and 2020, respectively, and $27.5 million and $27.3 million for the nine months ended September 30, 2021 and 2020, 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 operations. Such negative gas revenues associated with non-operated properties were immaterial for the three and nine months ended September 30, 2021 and 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 5. 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, 2021 and 2020. Three months ended September 30, 2021 Three months ended September 30, 2020 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 615,514 $ 214,348 $ 829,862 $ 346,580 $ 176,585 $ 523,165 Non-operated properties 159,981 12,980 172,961 91,067 9,723 100,790 Total crude oil revenues 775,495 227,328 1,002,823 437,647 186,308 623,955 Natural gas revenues: Operated properties (1) 123,907 277,124 401,031 2,950 67,986 70,936 Non-operated properties (2) 31,132 21,195 52,327 (2,499) 9,076 6,577 Total natural gas revenues 155,039 298,319 453,358 451 77,062 77,513 Crude oil and natural gas sales $ 930,534 $ 525,647 $ 1,456,181 $ 438,098 $ 263,370 $ 701,468 Timing of revenue recognition Goods transferred at a point in time $ 930,534 $ 525,647 $ 1,456,181 $ 438,098 $ 263,370 $ 701,468 Goods transferred over time — — — — — — $ 930,534 $ 525,647 $ 1,456,181 $ 438,098 $ 263,370 $ 701,468 Nine months ended September 30, 2021 Nine months ended September 30, 2020 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 1,647,079 $ 591,225 $ 2,238,304 $ 891,920 $ 385,836 $ 1,277,756 Non-operated properties 478,589 41,966 520,555 252,374 26,315 278,689 Total crude oil revenues 2,125,668 633,191 2,758,859 1,144,294 412,151 1,556,445 Natural gas revenues: Operated properties (1) 280,416 828,409 1,108,825 (7,974) 179,996 172,022 Non-operated properties (2) 64,876 54,068 118,944 (5,402) 15,798 10,396 Total natural gas revenues 345,292 882,477 1,227,769 (13,376) 195,794 182,418 Crude oil and natural gas sales $ 2,470,960 $ 1,515,668 $ 3,986,628 $ 1,130,918 $ 607,945 $ 1,738,863 Timing of revenue recognition Goods transferred at a point in time $ 2,470,960 $ 1,515,668 $ 3,986,628 $ 1,130,918 $ 607,945 $ 1,738,863 Goods transferred over time — — — — — — $ 2,470,960 $ 1,515,668 $ 3,986,628 $ 1,130,918 $ 607,945 $ 1,738,863 (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, 2021 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, 2021 and 2020 related to performance obligations satisfied in prior reporting periods were not material.

Derivative Instruments

Derivative Instruments	9 Months Ended
Derivative Instruments	Sep. 30, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments From time to time the Company enters 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 operations under the caption "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 6. Fair Value Measurements . At September 30, 2021 the Company had outstanding derivative contracts as set forth in the tables below. Natural gas derivatives Weighted Average Hedge Price Period and Type of Contract Volumes Hedged Swaps Sold Put Floor Ceiling October 2021 - December 2021 Swaps - Henry Hub 235,000 MMBtus/day $ 3.20 Collars - Henry Hub 90,000 MMBtus/day $ 3.00 $ 5.32 January 2022 - March 2022 Swaps - Henry Hub 45,000 MMBtus/day $ 3.96 Collars - Henry Hub 90,000 MMBtus/day $ 3.00 $ 6.33 Three-way collars - Henry Hub 280,000 MMBtus/day $ 2.33 $ 3.02 $ 4.46 April 2022 - June 2022 Swaps - Henry Hub 55,000 MMBtus/day $ 4.00 July 2022 - September 2022 Swaps - Henry Hub 55,000 MMBtus/day $ 4.00 Crude oil derivatives Period and Type of Contract Volumes Hedged Weighted Average Hedge Price October 2021 - December 2021 NYMEX Roll Swaps 50,000 Bbls/day $ 0.64 January 2022 - March 2022 NYMEX Roll Swaps 22,500 Bbls/day $ 0.65 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 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 2021 2020 2021 2020 Cash received (paid) on derivatives: Crude oil fixed price swaps $ — $ (14,205) $ (44,462) $ (21,328) Crude oil collars — — (9,365) — Crude oil NYMEX roll swaps (156) — 966 — Natural gas fixed price swaps (31,361) 4,253 (27,411) 4,253 Natural gas collars (10,563) — (7,329) — Cash received (paid) on derivatives, net (42,080) (9,952) (87,601) (17,075) Non-cash gain (loss) on derivatives: Crude oil fixed price swaps — 10,101 — — Crude oil collars — — 227 — Crude oil NYMEX roll swaps 3,506 — 180 — Natural gas fixed price swaps (33,947) (17,576) (68,503) (8,827) Natural gas collars (11,411) (426) (29,101) 267 Natural gas three-way collars (43,178) — (47,997) — Non-cash gain (loss) on derivatives, net (85,030) (7,901) (145,194) (8,560) Loss on derivative instruments, net $ (127,110) $ (17,853) $ (232,795) $ (25,635) 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, 2021 December 31, 2020 Commodity derivative assets: Gross amounts of recognized assets $ 19,465 $ 15,900 Gross amounts offset on balance sheet (17,378) (597) Net amounts of assets on balance sheet 2,087 15,303 Commodity derivative liabilities: Gross amounts of recognized liabilities (151,166) (2,408) Gross amounts offset on balance sheet 17,378 597 Net amounts of liabilities on balance sheet $ (133,788) $ (1,811) 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, 2021 December 31, 2020 Derivative assets $ 314 $ 15,303 Derivative assets, noncurrent 1,773 — Net amounts of assets on balance sheet 2,087 15,303 Derivative liabilities (131,616) (227) Derivative liabilities, noncurrent (2,172) (1,584) Net amounts of liabilities on balance sheet (133,788) (1,811) Total derivative assets (liabilities), net $ (131,701) $ 13,492

Fair Value Measurements

Fair Value Measurements	9 Months Ended
Fair Value Measurements	Sep. 30, 2021
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, 2021 and December 31, 2020. Fair value measurements at September 30, 2021 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets (liabilities): Swaps $ — $ (66,459) $ — $ (66,459) Collars — (17,425) — (17,425) Three-Way Collars — (47,997) — (47,997) NYMEX roll swaps — 180 — 180 Total $ — $ (131,701) $ — $ (131,701) Fair value measurements at December 31, 2020 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets (liabilities): Swaps $ — $ 2,043 $ — $ 2,043 Collars — 11,449 — $ 11,449 Total $ — $ 13,492 $ — $ 13,492 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, 2021, the Company's commodity price assumptions were based on forward NYMEX strip prices through year-end 2025 and were then escalated at 3% per year thereafter. Operating cost assumptions were based on current costs escalated at 3% per year beginning in 2022. 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, 2021, estimated future net cash flows were determined to be in excess of cost basis, and therefore no impairment was recorded for the Company's proved crude oil and natural gas properties for the 2021 periods. 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 included a $24.5 million impairment recognized in the 2020 first quarter to reduce the Company's crude oil inventory to estimated net realizable value at the time of impairment. Certain unproved crude oil and natural gas properties were impaired during the three and nine months ended September 30, 2021 and 2020, 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 operations. Three months ended September 30, Nine months ended September 30, In thousands 2021 2020 2021 2020 Proved property and inventory impairments $ — $ 1,574 $ — $ 207,119 Unproved property impairments 7,945 16,944 30,991 57,857 Total $ 7,945 $ 18,518 $ 30,991 $ 264,976 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, 2021 December 31, 2020 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ — $ — $ 160,000 $ 160,000 Notes payable 22,923 22,500 24,590 24,700 5% Senior Notes due 2022 — — 630,470 632,900 4.5% Senior Notes due 2023 647,789 673,600 646,943 669,900 3.8% Senior Notes due 2024 907,772 957,800 906,922 939,500 4.375% Senior Notes due 2028 991,592 1,106,500 990,746 1,024,400 5.75% Senior Notes due 2031 1,481,951 1,813,000 1,480,879 1,651,900 4.9% Senior Notes due 2044 692,008 786,800 691,868 689,600 Total debt $ 4,744,035 $ 5,360,200 $ 5,532,418 $ 5,792,900 The fair value of credit facility borrowings, if any, 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. 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”), the 5.75% Senior Notes due 2031 (“2031 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
Long-Term Debt	Sep. 30, 2021
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $39.6 million and $43.7 million at September 30, 2021 and December 31, 2020, respectively, consists of the following. In thousands September 30, 2021 December 31, 2020 Credit facility $ — $ 160,000 Notes payable 22,923 24,590 5% Senior Notes due 2022 — 630,470 4.5% Senior Notes due 2023 647,789 646,943 3.8% Senior Notes due 2024 907,772 906,922 4.375% Senior Notes due 2028 991,592 990,746 5.75% Senior Notes due 2031 1,481,951 1,480,879 4.9% Senior Notes due 2044 692,008 691,868 Total debt $ 4,744,035 $ 5,532,418 Less: Current portion of long-term debt 2,306 2,245 Long-term debt, net of current portion $ 4,741,729 $ 5,530,173 Credit Facility At September 30, 2021, the Company had an unsecured credit facility, maturing on April 9, 2023, with aggregate lender commitments totaling $1.5 billion. The Company had no outstanding borrowings on its credit facility at September 30, 2021. On October 29, 2021, the Company amended its credit facility. See Note 13. Subsequent Events for further discussion. Borrowings under the credit facility, if any, 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 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, 2021. 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, 2021. 2023 Notes 2024 Notes 2028 Notes 2031 Notes 2044 Notes Face value (in thousands) $649,625 $911,000 $1,000,000 $1,500,000 $700,000 Maturity date April 15, 2023 June 1, 2024 January 15, 2028 January 15, 2031 June 1, 2044 Interest payment dates April 15, Oct 15 June 1, Dec 1 Jan 15, July 15 Jan 15, Jul 15 June 1, Dec 1 Make-whole redemption period (1) Jan 15, 2023 Mar 1, 2024 Oct 15, 2027 Jul 15, 2030 Dec 1, 2043 (1) 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, 2021. The senior notes are obligations of Continental Resources, Inc. Additionally, 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 2021 In January 2021, the Company redeemed $400.0 million principal amount of its outstanding 2022 Notes and subsequently redeemed the remaining $230.8 million principal amount of its 2022 Notes in April 2021. The Company recognized pre-tax losses on extinguishment of debt totaling $0.3 million related to the redemptions, which included the pro-rata write-off of deferred financing costs and unamortized debt premium associated with the redeemed notes. The losses are reflected in the caption “Gain (loss) on extinguishment of debt” in the unaudited condensed consolidated statements of operations. 2020 In March and April 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 $50.4 million face value of its 2023 Notes at an aggregate cost of $29.3 million and $89.0 million face value of its 2024 Notes at an aggregate cost of $46.9 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 totaling $64.6 million related to the repurchases, which included the pro-rata write-off of deferred financing costs and unamortized debt discount associated with the repurchased notes. Notes payable

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies 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. Certain of 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, 2021 under the arrangements amount to approximately $1.38 billion, of which $73 million is expected to be incurred in the remainder of 2021, $272 million in 2022, $272 million in 2023, $252 million in 2024, $164 million in 2025, and $353 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. Pending property acquisitions – The Company is in the process of executing various property acquisitions to increase its position in multiple strategic plays, which we expect will result in cash outlays of up to approximately $375 million in the fourth quarter of 2021 if completed. The acquisitions remain subject to the completion of customary due diligence procedures and satisfaction of closing conditions. Additionally, see Note 13. Subsequent Events for discussion of a definitive acquisition agreement executed by the Company subsequent to September 30, 2021. Litigation – The Company is involved in various 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, 2021 and December 31, 2020, the Company had recognized a liability within “Other noncurrent liabilities” of $7.7 million and $7.7 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
Stock-Based Compensation	Sep. 30, 2021
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 operations, was $14.3 million and $16.4 million for the three months ended September 30, 2021 and 2020, respectively, and $44.9 million and $48.1 million for the nine months ended September 30, 2021 and 2020, 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, 2021, the Company had 8,476,267 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, 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, 2021 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2020 4,890,638 $ 36.26 Granted 2,900,923 23.51 Vested (1,615,209) 45.49 Forfeited (182,634) 27.14 Non-vested restricted shares outstanding at September 30, 2021 5,993,718 $ 27.88

Shareholders' Equity

Shareholders' Equity	9 Months Ended
Shareholders' Equity	Sep. 30, 2021
Shareholders' Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Shareholders' Equity 2021 Share Repurchases During the three months ended September 30, 2021, the Company repurchased and retired approximately 1.9 million shares of its common stock at an aggregate cost of $65.3 million. The Company has repurchased and retired a cumulative total of approximately 15.7 million shares at an aggregate cost of $382.4 million since the inception of its $1 billion share repurchase program in June 2019. 2020 Share Repurchases During the nine months ended September 31, 2020, the Company repurchased and retired approximately 8.1 million shares of its common stock at an aggregate cost of $126.9 million. 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 Payments On July 30, 2021, the Company declared a quarterly cash dividend of $0.15 per share on its outstanding common stock, which amounted to $54.1 million and was paid on August 20, 2021 to shareholders of record as of August 10, 2021. On April 27, 2021, the Company declared a quarterly cash dividend of $0.11 per share on its outstanding common stock, which amounted to $40 million and was paid on May 24, 2021 to shareholders of record as of May 10, 2021.

Income Taxes

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2021
Income Taxes [Abstract]
Income Tax Disclosure [Text Block]	Income Taxes Income taxes are accounted for using the asset and 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, 2021 2020 2021 2020 Provision (benefit) for income taxes (in thousands) $ 115,641 $ (13,972) $ 291,116 $ (138,350) Effective tax rate 23.8 % 14.6 % 24.0 % 21.3 % 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, changes in 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 2021 2020 2021 2020 Income (loss) before income taxes $ 486,162 $ (95,555) $ 1,211,386 $ (648,848) 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 102,094 (20,067) 254,391 (136,258) Items impacting the effective tax rate: State and local income taxes, net of federal benefit 17,109 (2,988) 43,559 (20,896) Equity compensation (11) 214 6,126 4,685 Other, net (2,086) 2,540 (7,006) (90) Change in valuation allowance (1,465) 6,329 (5,954) 14,209 Provision (benefit) for income taxes $ 115,641 $ (13,972) $ 291,116 $ (138,350) Effective tax rate 23.8 % 14.6 % 24.0 % 21.3 % In assessing the realizability of deferred tax assets the Company must consider whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The Company applies judgment to determine the weight of both positive and negative evidence in order to conclude whether a valuation allowance is necessary for its deferred tax assets. In determining whether a valuation allowance is required, the Company considers, among other factors, the Company's financial position, results of operations, projected future taxable income, reversal of existing deferred tax liabilities against deferred tax assets, and tax planning strategies. During 2020, a valuation allowance had been established for the deferred tax asset associated with a portion of the Company's Oklahoma state net operating loss carryforwards. In 2021, the Company reassessed the realizability of the deferred tax asset related to Oklahoma state net operating loss carryforwards, and based on current year activity, determined it was more likely than not that such assets would be realized. Therefore, it was determined that the previously recorded valuation allowance in 2020 should be released throughout 2021, with $1.5 million and $5.9 million of release being recognized during the three and nine months ended September 30, 2021, respectively.

Property Acquisition

Property Acquisition	9 Months Ended
Property Acquisition	Sep. 30, 2021
Property Acquisition [Abstract]
Property Acquisition	Property AcquisitionOn March 4, 2021, the Company acquired undeveloped leasehold and producing properties in the Powder River Basin of Wyoming for $206.6 million, consisting of a $21.5 million escrow deposit paid in December 2020 upon execution of a definitive purchase agreement and a $185.1 million payment made at closing in March 2021. The acquisition included approximately 130,000 net acres and producing properties with production totaling approximately 7,200 net barrels of oil equivalent per day at the time of closing. The $21.5 million escrow deposit paid in December 2020 is included in the caption "Other noncurrent assets" on the Company's balance sheet at December 31, 2020, which was subsequently reclassified to "Net property and equipment" on the closing date. The Company recognized approximately $4.9 million of asset retirement obligations and $12.4 million of right-of-use assets and corresponding lease liabilities associated with the acquired properties.

Subsequent Events

Subsequent Events	9 Months Ended
Subsequent Events	Sep. 30, 2021
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Credit Facility Amendment On October 29, 2021, the Company amended its credit facility to increase the aggregate commitments from $1.5 billion to $1.7 billion and extend the maturity date from April 2023 to October 2026. The amended credit facility provides for benchmark replacement mechanics to address the transition from LIBOR, while all other terms, conditions, and covenants remain substantially unchanged. Acquisition Agreement On November 1, 2021, the Company executed a definitive agreement to acquire oil and gas properties and related assets in the Permian Basin of Texas from certain subsidiaries of Pioneer Natural Resources Company (“Pioneer”) for $3.25 billion of cash, subject to customary closing price adjustments. The properties include approximately 92,000 net leasehold acres, approximately 50,000 net royalty acres in the same area normalized to a 1/8th royalty, production totaling approximately 55,000 net barrels of oil equivalent per day (~70% oil) based on historical 3-stream reporting and including anticipated volumes from in-progress wells expected to be completed in first quarter 2022, and extensive water infrastructure. On the execution date the Company paid Pioneer a deposit of $325 million. Closing of the acquisition is expected to occur in December 2021 and remains subject to the completion of customary due diligence procedures and closing conditions, including the satisfaction of certain regulatory approvals. The Company expects to fund the acquisition through a combination of funding sources, including the use of cash on hand, utilization of credit facility borrowing capacity, and the issuance of debt securities and/or bank term loan facilities. Dividend Declaration On November 1, 2021, the Company declared a quarterly cash dividend of $0.20 per share on its outstanding common stock, which will be paid on November 26, 2021 to shareholders of record as of November 15, 2021.

Basis of Presentation and Sig_2

Basis of Presentation and Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2021
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, Wyoming Powder River Basin, 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 62% of its crude oil and natural gas revenues for the nine months ended September 30, 2021. The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana and the Powder River Basin of Wyoming. The Company's operations in the South region comprised 45% of its crude oil and natural gas production and 38% of its crude oil and natural gas revenues for the nine months ended September 30, 2021. 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, 2020 (“2020 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, 2021 and for the three and nine month periods ended September 30, 2021 and 2020 are unaudited. The condensed consolidated balance sheet as of December 31, 2020 was derived from the audited balance sheet included in the 2020 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.
Concentration Risk, Credit Risk, Policy	Credit risk The Company's principal exposure to credit risk is through receivables associated with the sale of its crude oil and natural gas production and 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 —
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 and natural gas 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, 2021 the Company adopted Accounting Standards Update ("ASU") 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. This standard eliminates certain exceptions to the guidance in Topic 740 related

Basis of Presentation and Sig_3

Basis of Presentation and Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2021
Accounting Policies [Abstract]
Components of Inventories	The components of inventory as of September 30, 2021 and December 31, 2020 consisted of the following: In thousands September 30, 2021 December 31, 2020 Tubular goods and equipment $ 12,017 $ 13,671 Crude oil and natural gas 107,268 58,486 Total $ 119,285 $ 72,157
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, 2021 and 2020. Three months ended September 30, Nine months ended September 30, In thousands, except per share data 2021 2020 2021 2020 Net income (loss) attributable to Continental Resources (numerator) $ 369,328 $ (79,422) $ 918,295 $ (504,372) Weighted average shares (denominator): Weighted average shares - basic 360,563 360,257 360,899 361,948 Non-vested restricted stock (1) 3,685 — 3,580 — Weighted average shares - diluted 364,248 360,257 364,479 361,948 Net income (loss) per share attributable to Continental Resources: Basic $ 1.02 $ (0.22) $ 2.54 $ (1.39) Diluted $ 1.01 $ (0.22) $ 2.52 $ (1.39) (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.

Revenues (Tables)

Revenues (Tables)	9 Months Ended
Revenues (Tables)	Sep. 30, 2021
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, 2021 and 2020. Three months ended September 30, 2021 Three months ended September 30, 2020 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 615,514 $ 214,348 $ 829,862 $ 346,580 $ 176,585 $ 523,165 Non-operated properties 159,981 12,980 172,961 91,067 9,723 100,790 Total crude oil revenues 775,495 227,328 1,002,823 437,647 186,308 623,955 Natural gas revenues: Operated properties (1) 123,907 277,124 401,031 2,950 67,986 70,936 Non-operated properties (2) 31,132 21,195 52,327 (2,499) 9,076 6,577 Total natural gas revenues 155,039 298,319 453,358 451 77,062 77,513 Crude oil and natural gas sales $ 930,534 $ 525,647 $ 1,456,181 $ 438,098 $ 263,370 $ 701,468 Timing of revenue recognition Goods transferred at a point in time $ 930,534 $ 525,647 $ 1,456,181 $ 438,098 $ 263,370 $ 701,468 Goods transferred over time — — — — — — $ 930,534 $ 525,647 $ 1,456,181 $ 438,098 $ 263,370 $ 701,468 Nine months ended September 30, 2021 Nine months ended September 30, 2020 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 1,647,079 $ 591,225 $ 2,238,304 $ 891,920 $ 385,836 $ 1,277,756 Non-operated properties 478,589 41,966 520,555 252,374 26,315 278,689 Total crude oil revenues 2,125,668 633,191 2,758,859 1,144,294 412,151 1,556,445 Natural gas revenues: Operated properties (1) 280,416 828,409 1,108,825 (7,974) 179,996 172,022 Non-operated properties (2) 64,876 54,068 118,944 (5,402) 15,798 10,396 Total natural gas revenues 345,292 882,477 1,227,769 (13,376) 195,794 182,418 Crude oil and natural gas sales $ 2,470,960 $ 1,515,668 $ 3,986,628 $ 1,130,918 $ 607,945 $ 1,738,863 Timing of revenue recognition Goods transferred at a point in time $ 2,470,960 $ 1,515,668 $ 3,986,628 $ 1,130,918 $ 607,945 $ 1,738,863 Goods transferred over time — — — — — — $ 2,470,960 $ 1,515,668 $ 3,986,628 $ 1,130,918 $ 607,945 $ 1,738,863 (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
Derivative Instruments (Tables)	Sep. 30, 2021
Summary of Outstanding Contracts with Respect to Natural Gas	At September 30, 2021 the Company had outstanding derivative contracts as set forth in the tables below. Natural gas derivatives Weighted Average Hedge Price Period and Type of Contract Volumes Hedged Swaps Sold Put Floor Ceiling October 2021 - December 2021 Swaps - Henry Hub 235,000 MMBtus/day $ 3.20 Collars - Henry Hub 90,000 MMBtus/day $ 3.00 $ 5.32 January 2022 - March 2022 Swaps - Henry Hub 45,000 MMBtus/day $ 3.96 Collars - Henry Hub 90,000 MMBtus/day $ 3.00 $ 6.33 Three-way collars - Henry Hub 280,000 MMBtus/day $ 2.33 $ 3.02 $ 4.46 April 2022 - June 2022 Swaps - Henry Hub 55,000 MMBtus/day $ 4.00 July 2022 - September 2022 Swaps - Henry Hub 55,000 MMBtus/day $ 4.00 Crude oil derivatives Period and Type of Contract Volumes Hedged Weighted Average Hedge Price October 2021 - December 2021 NYMEX Roll Swaps 50,000 Bbls/day $ 0.64 January 2022 - March 2022 NYMEX Roll Swaps 22,500 Bbls/day $ 0.65
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 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 2021 2020 2021 2020 Cash received (paid) on derivatives: Crude oil fixed price swaps $ — $ (14,205) $ (44,462) $ (21,328) Crude oil collars — — (9,365) — Crude oil NYMEX roll swaps (156) — 966 — Natural gas fixed price swaps (31,361) 4,253 (27,411) 4,253 Natural gas collars (10,563) — (7,329) — Cash received (paid) on derivatives, net (42,080) (9,952) (87,601) (17,075) Non-cash gain (loss) on derivatives: Crude oil fixed price swaps — 10,101 — — Crude oil collars — — 227 — Crude oil NYMEX roll swaps 3,506 — 180 — Natural gas fixed price swaps (33,947) (17,576) (68,503) (8,827) Natural gas collars (11,411) (426) (29,101) 267 Natural gas three-way collars (43,178) — (47,997) — Non-cash gain (loss) on derivatives, net (85,030) (7,901) (145,194) (8,560) Loss on derivative instruments, net $ (127,110) $ (17,853) $ (232,795) $ (25,635)
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, 2021 December 31, 2020 Commodity derivative assets: Gross amounts of recognized assets $ 19,465 $ 15,900 Gross amounts offset on balance sheet (17,378) (597) Net amounts of assets on balance sheet 2,087 15,303 Commodity derivative liabilities: Gross amounts of recognized liabilities (151,166) (2,408) Gross amounts offset on balance sheet 17,378 597 Net amounts of liabilities on balance sheet $ (133,788) $ (1,811)
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, 2021 December 31, 2020 Derivative assets $ 314 $ 15,303 Derivative assets, noncurrent 1,773 — Net amounts of assets on balance sheet 2,087 15,303 Derivative liabilities (131,616) (227) Derivative liabilities, noncurrent (2,172) (1,584) Net amounts of liabilities on balance sheet (133,788) (1,811) Total derivative assets (liabilities), net $ (131,701) $ 13,492

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2021
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 operations. Three months ended September 30, Nine months ended September 30, In thousands 2021 2020 2021 2020 Proved property and inventory impairments $ — $ 1,574 $ — $ 207,119 Unproved property impairments 7,945 16,944 30,991 57,857 Total $ 7,945 $ 18,518 $ 30,991 $ 264,976
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, 2021 December 31, 2020 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ — $ — $ 160,000 $ 160,000 Notes payable 22,923 22,500 24,590 24,700 5% Senior Notes due 2022 — — 630,470 632,900 4.5% Senior Notes due 2023 647,789 673,600 646,943 669,900 3.8% Senior Notes due 2024 907,772 957,800 906,922 939,500 4.375% Senior Notes due 2028 991,592 1,106,500 990,746 1,024,400 5.75% Senior Notes due 2031 1,481,951 1,813,000 1,480,879 1,651,900 4.9% Senior Notes due 2044 692,008 786,800 691,868 689,600 Total debt $ 4,744,035 $ 5,360,200 $ 5,532,418 $ 5,792,900

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
Long-Term Debt (Tables)	Sep. 30, 2021
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, 2021. 2023 Notes 2024 Notes 2028 Notes 2031 Notes 2044 Notes Face value (in thousands) $649,625 $911,000 $1,000,000 $1,500,000 $700,000 Maturity date April 15, 2023 June 1, 2024 January 15, 2028 January 15, 2031 June 1, 2044 Interest payment dates April 15, Oct 15 June 1, Dec 1 Jan 15, July 15 Jan 15, Jul 15 June 1, Dec 1 Make-whole redemption period (1) Jan 15, 2023 Mar 1, 2024 Oct 15, 2027 Jul 15, 2030 Dec 1, 2043 (1) 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 $39.6 million and $43.7 million at September 30, 2021 and December 31, 2020, respectively, consists of the following. In thousands September 30, 2021 December 31, 2020 Credit facility $ — $ 160,000 Notes payable 22,923 24,590 5% Senior Notes due 2022 — 630,470 4.5% Senior Notes due 2023 647,789 646,943 3.8% Senior Notes due 2024 907,772 906,922 4.375% Senior Notes due 2028 991,592 990,746 5.75% Senior Notes due 2031 1,481,951 1,480,879 4.9% Senior Notes due 2044 692,008 691,868 Total debt $ 4,744,035 $ 5,532,418 Less: Current portion of long-term debt 2,306 2,245 Long-term debt, net of current portion $ 4,741,729 $ 5,530,173

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
Stock-Based Compensation (Tables)	Sep. 30, 2021
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, 2021 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2020 4,890,638 $ 36.26 Granted 2,900,923 23.51 Vested (1,615,209) 45.49 Forfeited (182,634) 27.14 Non-vested restricted shares outstanding at September 30, 2021 5,993,718 $ 27.88

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
Income Taxes (Tables)	Sep. 30, 2021
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, 2021 2020 2021 2020 Provision (benefit) for income taxes (in thousands) $ 115,641 $ (13,972) $ 291,116 $ (138,350) Effective tax rate 23.8 % 14.6 % 24.0 % 21.3 %
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, changes in 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 2021 2020 2021 2020 Income (loss) before income taxes $ 486,162 $ (95,555) $ 1,211,386 $ (648,848) 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 102,094 (20,067) 254,391 (136,258) Items impacting the effective tax rate: State and local income taxes, net of federal benefit 17,109 (2,988) 43,559 (20,896) Equity compensation (11) 214 6,126 4,685 Other, net (2,086) 2,540 (7,006) (90) Change in valuation allowance (1,465) 6,329 (5,954) 14,209 Provision (benefit) for income taxes $ 115,641 $ (13,972) $ 291,116 $ (138,350) Effective tax rate 23.8 % 14.6 % 24.0 % 21.3 % In assessing the realizability of deferred tax assets the Company must consider whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The Company applies judgment to determine the weight of both positive and negative evidence in order to conclude whether a valuation allowance is necessary for its deferred tax assets. In determining whether a valuation allowance is required, the Company considers, among other factors, the Company's financial position, results of operations, projected future taxable income, reversal of existing deferred tax liabilities against deferred tax assets, and tax planning strategies. During 2020, a valuation allowance had been established for the deferred tax asset associated with a portion of the Company's Oklahoma state net operating loss carryforwards. In 2021, the Company reassessed the realizability of the deferred tax asset related to Oklahoma state net operating loss carryforwards, and based on current year activity, determined it was more likely than not that such assets would be realized. Therefore, it was determined that the previously recorded valuation allowance in 2020 should be released throughout 2021, with $1.5 million and $5.9 million of release being recognized during the three and nine months ended September 30, 2021, respectively.

Organization and Nature of Bu_2

Organization and Nature of Business - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2021
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	49.00%
Percentage of crude oil and natural gas revenue concentrated in crude oil	69.00%
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	62.00%
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	38.00%

Basis of Presentation and Sig_4

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Tubular goods and equipment	$ 12,017	$ 13,671
Crude oil	107,268	58,486
Total	$ 119,285	$ 72,157

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, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
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)	$ 369,328	$ (79,422)	$ 918,295	$ (504,372)
Weighted average shares - basic	360,563,000	360,257,000	360,899,000	361,948,000
Non-vested restricted stock (1)	3,685,000	0	3,580,000	0
Weighted average shares - diluted	364,248,000	360,257,000	364,479,000	361,948,000
Net income (loss) per share attributable to Continental Resources:
Basic (in dollars per share)	$ 1.02	$ (0.22)	$ 2.54	$ (1.39)
Diluted (in dollars per share)	$ 1.01	$ (0.22)	$ 2.52	$ (1.39)

Revenues Disaggregation of Reve

Revenues Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 1,456,181	$ 701,468	$ 3,986,628	$ 1,738,863
Transportation expenses	53,969	55,272	156,670	148,079
Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	1,456,181	701,468	3,986,628	1,738,863
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	930,534	438,098	2,470,960	1,130,918
North Region [Member] \| Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	930,534	438,098	2,470,960	1,130,918
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	525,647	263,370	1,515,668	607,945
South Region [Member] \| Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	525,647	263,370	1,515,668	607,945
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	1,002,823	623,955	2,758,859	1,556,445
Transportation expenses	45,200	46,900	129,200	120,800
Crude oil sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	775,495	437,647	2,125,668	1,144,294
Crude oil sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	227,328	186,308	633,191	412,151
Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	453,358	77,513	1,227,769	182,418
Transportation expenses	8,700	8,400	27,500	27,300
Natural gas sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	155,039	451	345,292	(13,376)
Natural gas sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	298,319	77,062	882,477	195,794
Operated properties \| Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	829,862	523,165	2,238,304	1,277,756
Operated properties \| Crude oil sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	615,514	346,580	1,647,079	891,920
Operated properties \| Crude oil sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	214,348	176,585	591,225	385,836
Operated properties \| Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	401,031	70,936	1,108,825	172,022
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	123,907	2,950	280,416	(7,974)
Operated properties \| Natural gas sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	277,124	67,986	828,409	179,996
Non-operated Properties \| Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	172,961	100,790	520,555	278,689
Non-operated Properties \| Crude oil sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	159,981	91,067	478,589	252,374
Non-operated Properties \| Crude oil sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	12,980	9,723	41,966	26,315
Non-operated Properties \| Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	52,327	6,577	118,944	10,396
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	31,132	(2,499)	64,876	(5,402)
Non-operated Properties \| Natural gas sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 21,195	$ 9,076	$ 54,068	$ 15,798

Derivative Instruments - Summar

Derivative Instruments - Summary of Outstanding Contracts with Respect to Natural Gas and Crude Oil (Detail)	9 Months Ended
	Sep. 30, 2021MMBTU$ / MMBTUbbl
July 2021 to Sept 2021 Swaps \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	45,000
Swaps Weighted Average Price	3.96
July 2021 to Dec 2021 NYMEX Roll Swap \| Crude Oil [Member]
Derivative [Line Items]
Swaps Weighted Average Price	0.64
Crude oil production volume hedged \| bbl	50,000
Jan 2022 to March 2022 NYMEX Roll Swap \| Crude Oil [Member]
Derivative [Line Items]
Swaps Weighted Average Price	0.65
Crude oil production volume hedged \| bbl	22,500
Oct 2021 to Dec 2021 Collars \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	90,000
Derivative, Average Floor Price	3
Derivative, Average Cap Price	5.32
October 2021 to Dec 2021 Swaps \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	235,000
Swaps Weighted Average Price	3.20
Jan 2022 to March 2022 3 Way Collars \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	280,000
Derivative, Average Floor Price	3.02
Derivative, Average Cap Price	4.46
Derivative, Average Price Risk Option Strike Price	2.33
Jan 2022 to Mar 2022 Collars \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	90,000
Derivative, Average Floor Price	3
Derivative, Average Cap Price	6.33
April 2022 to June 2022 Swaps \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	55,000
Swaps Weighted Average Price	4
July 2022 to September 2022 Swaps \| Natural Gas [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus \| MMBTU	55,000
Swaps Weighted Average 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, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net			$ (145,194)	$ (8,560)
Loss on derivative instruments, net	$ (127,110)	$ (17,853)	(232,795)	(25,635)
Swap [Member] \| Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	(14,205)	(44,462)	(21,328)
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	10,101	0	0
Swap [Member] \| Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(31,361)	4,253	(27,411)	4,253
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(33,947)	(17,576)	(68,503)	(8,827)
Collars \| Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	0	(9,365)	0
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	0	227	0
Collars \| Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(10,563)	0	(7,329)	0
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(11,411)	(426)	(29,101)	267
NYMEX roll swaps \| Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(156)	0	966	0
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	3,506	0	180	0
Jan 2022 to March 2022 3 Way Collars \| Natural Gas [Member]
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net		0	(47,997)	0
3 Way Collars \| Natural Gas [Member]
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(43,178)
Crude Oil and Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	(42,080)	(9,952)	(87,601)	(17,075)
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(85,030)	(7,901)	(145,194)	(8,560)
Loss on derivative instruments, net	$ (127,110)	$ (17,853)	$ (232,795)	$ (25,635)

Derivative Instruments - Gross

Derivative Instruments - Gross Amounts of Recognized Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gross amounts of recognized assets	$ 19,465	$ 15,900
Gross amounts offset on balance sheet	(17,378)	(597)
Net amounts of assets on balance sheet	2,087	15,303
Gross amounts of recognized liabilities	(151,166)	(2,408)
Gross amounts offset on balance sheet	17,378	597
Net amounts of liabilities on balance sheet	$ (133,788)	$ (1,811)

Derivative Instruments - Reconc

Derivative Instruments - Reconciles Net Amounts Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative assets	$ 314	$ 15,303
Noncurrent derivative assets	1,773	0
Net amounts of assets on balance sheet	2,087	15,303
Derivative liabilities	(131,616)	(227)
Derivative liabilities, noncurrent	(2,172)	(1,584)
Net amounts of liabilities on balance sheet	(133,788)	(1,811)
Total derivative assets (liabilities), net	$ (131,701)	$ 13,492

Fair Value Measurements - Valua

Fair Value Measurements - Valuation of Financial Instruments by Pricing Levels (Detail) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Derivative assets (liabilities):
Derivative assets (liabilities)	$ (131,701)	$ 13,492
Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(66,459)	2,043
Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	(17,425)	11,449
NYMEX roll swaps
Derivative assets (liabilities):
Derivative assets (liabilities)	180
3 Way Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	(47,997)
Fair Value, Inputs, Level 1 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0	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	0
Fair Value, Inputs, Level 1 [Member] \| Price Swap
Derivative assets (liabilities):
Derivative assets (liabilities)		0
Fair Value, Inputs, Level 1 [Member] \| NYMEX roll swaps
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 1 [Member] \| 3 Way Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 2 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(131,701)	13,492
Fair Value, Inputs, Level 2 [Member] \| Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	(66,459)
Fair Value, Inputs, Level 2 [Member] \| Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	(17,425)	11,449
Fair Value, Inputs, Level 2 [Member] \| Price Swap
Derivative assets (liabilities):
Derivative assets (liabilities)		2,043
Fair Value, Inputs, Level 2 [Member] \| NYMEX roll swaps
Derivative assets (liabilities):
Derivative assets (liabilities)	180
Fair Value, Inputs, Level 2 [Member] \| 3 Way Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	(47,997)
Fair Value, Inputs, Level 3 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0	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	0
Fair Value, Inputs, Level 3 [Member] \| Price Swap
Derivative assets (liabilities):
Derivative assets (liabilities)		$ 0
Fair Value, Inputs, Level 3 [Member] \| NYMEX roll swaps
Derivative assets (liabilities):
Derivative assets (liabilities)	0
Fair Value, Inputs, Level 3 [Member] \| 3 Way Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	$ 0

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail)	9 Months Ended
Fair Value Measurements - Additional Information (Detail)	Sep. 30, 2021
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, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property and inventory impairments	$ 0	$ 1,574	$ 0	$ 207,119
Unproved property impairments	7,945	16,944	30,991	57,857
Property impairments	$ 7,945	18,518	$ 30,991	264,976
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 and inventory impairments				168,100
Non-core [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property and inventory impairments				14,500
Inventory Valuation and Obsolescence [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Inventory Write-down				24,500
Property, Plant and Equipment [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property and inventory impairments		$ 1,600		$ 182,600

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, 2021	Dec. 31, 2020
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
Senior Notes due 2031
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	5.75%
Debt Instrument, Maturity Date, Description	2031
Five Point Seven Five Percent Senior Notes due 2031
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	5.75%
Debt Instrument, Maturity Date, Description	2031
Carrying Amount
Fair Value Measurements [Line Items]
Credit facility	$ 0	$ 160,000
Notes payable	22,923	24,590
Total debt	4,744,035	5,532,418
Carrying Amount \| 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	0	630,470
Carrying Amount \| 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	647,789	646,943
Carrying Amount \| 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	907,772	906,922
Carrying Amount \| 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	991,592	990,746
Carrying Amount \| 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	692,008	691,868
Carrying Amount \| Senior Notes due 2031
Fair Value Measurements [Line Items]
Senior notes	1,481,951	1,480,879
Estimated Fair Value
Fair Value Measurements [Line Items]
Credit facility	0	160,000
Notes payable	22,500	24,700
Total debt	5,360,200	5,792,900
Estimated Fair Value \| 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	0	632,900
Estimated Fair Value \| 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	673,600	669,900
Estimated Fair Value \| 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	957,800	939,500
Estimated Fair Value \| 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	1,106,500	1,024,400
Estimated Fair Value \| 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	786,800	689,600
Estimated Fair Value \| Senior Notes due 2031
Fair Value Measurements [Line Items]
Senior notes	$ 1,813,000	$ 1,651,900

Long-Term Debt - Long-Term Debt

Long-Term Debt - Long-Term Debt (Detail) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Less: Current portion of long-term debt	$ (2,306)	$ (2,245)
Long-term debt, net of current portion	$ 4,741,729	5,530,173
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%
Senior Notes due 2031
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.75%
Carrying Amount
Debt Instrument [Line Items]
Credit facility	$ 0	160,000
Notes payable	22,923	24,590
Total debt	4,744,035	5,532,418
Carrying Amount \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	0	630,470
Carrying Amount \| 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	647,789	646,943
Carrying Amount \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	907,772	906,922
Carrying Amount \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	991,592	990,746
Carrying Amount \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	692,008	691,868
Carrying Amount \| Senior Notes due 2031
Debt Instrument [Line Items]
Senior notes	1,481,951	1,480,879
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	0	160,000
Notes payable	22,500	24,700
Total debt	5,360,200	5,792,900
Estimated Fair Value \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	0	632,900
Estimated Fair Value \| 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	673,600	669,900
Estimated Fair Value \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	957,800	939,500
Estimated Fair Value \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	1,106,500	1,024,400
Estimated Fair Value \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	786,800	689,600
Estimated Fair Value \| Senior Notes due 2031
Debt Instrument [Line Items]
Senior notes	$ 1,813,000	$ 1,651,900

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended	9 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020	Jun. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Apr. 22, 2021	Jan. 05, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	$ 39,600					$ 39,600				$ 43,700
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	2,306					$ 2,306				2,245
Line of Credit Facility, Covenant Terms						0.65
Gain (Loss) on Extinguishment of Debt	$ 0		$ 0	$ (64,600)		$ 290	$ (64,573)
Senior Notes Due Two Thousand And Twenty Three [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount			50,400				50,400
Debt Instrument, Repurchase Amount			29,300				29,300
Debt Instrument, Maturity Date						Apr. 15, 2023
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]
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			89,000				89,000
Debt Instrument, Repurchase Amount			$ 46,900				$ 46,900
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, Repurchased Face Amount								$ 230,800	$ 400,000
Gain (Loss) on Extinguishment of Debt		$ (300)
Senior Notes due 2031
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.75%					5.75%
Debt Instrument, Maturity Date						Jan. 15, 2031
Debt Instrument, Maturity Date, Description						2031
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	$ 0					$ 0				160,000
Notes Payable	22,500					22,500				24,700
Estimated Fair Value \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	0					0				632,900
Estimated Fair Value \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	957,800					957,800				939,500
Estimated Fair Value \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	1,106,500					1,106,500				1,024,400
Estimated Fair Value \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	786,800					786,800				689,600
Estimated Fair Value \| Senior Notes due 2031
Debt Instrument [Line Items]
Senior notes	1,813,000					1,813,000				1,651,900
Carrying Amount
Debt Instrument [Line Items]
Credit facility	0					0				160,000
Notes Payable	22,923					22,923				24,590
Carrying Amount \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	0					0				630,470
Carrying Amount \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	907,772					907,772				906,922
Carrying Amount \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	991,592					991,592				990,746
Carrying Amount \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	692,008					692,008				691,868
Carrying Amount \| Senior Notes due 2031
Debt Instrument [Line Items]
Senior notes	$ 1,481,951					$ 1,481,951				$ 1,480,879

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, 2021USD ($)
2023 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 649,625
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
Senior Notes due 2031
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,500,000
Maturity date	Jan. 15, 2031
Interest payment dates	Jan 15, Jul 15
Debt Instrument, Redemption Period, Start Date	Jul. 15, 2030

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies - Additional Information (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation Agreement Expiration Date	2031
Purchase Obligation	$ 1,380
Purchase Obligation, to be Paid, Year Two	272
Purchase Obligation, to be Paid, Year Three	272
Purchase Obligation, to be Paid, Year Four	252
Purchase Obligation, to be Paid, Year Five	164
Purchase Obligation, to be Paid, after Year Five	353
Purchase Obligation, to be Paid, Year One	$ 73

Commitments and Contingencies L

Commitments and Contingencies Loss Contingencies (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Loss Contingencies [Line Items]
Legal proceedings recorded as a liability under other noncurrent liabilities	$ 7.7	$ 7.7

Stock Based Compensation - Stoc

Stock Based Compensation - Stock Based Compensation Expenses (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Non-cash equity compensation	$ 14.3	$ 16.4	$ 44.9	$ 48.1

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2021USD ($)shares
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock available to grant \| shares	8,476,267
Fair value at vesting date \| $	$ 40
Unrecognized compensation expense related to non-vested \| $	$ 81
Unrecognized compensation expense related to non-vested, period for recognition, in years	1 year 7 months 6 days
Restricted stock [Member] \| Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants vest over periods, in years	1 year
Restricted stock [Member] \| Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants vest over periods, in years	3 years
2013 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock available for issue \| shares	12,983,543

Stock Based Compensation - Summ

Stock Based Compensation - Summary of Changes in Non Vested Shares of Restricted Stock Outstanding (Detail)	9 Months Ended
	Sep. 30, 2021$ / 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	4,890,638
Granted (unaudited), shares \| shares	2,900,923
Vested shares \| shares	(1,615,209)
Forfeited (unaudited), shares \| shares	(182,634)
Non-vested shares, ending balance \| shares	5,993,718
Non-vested, weighted average grant-date fair value, beginning of period \| $ / shares	$ 36.26
Granted, weighted average grant-date fair value \| $ / shares	23.51
Vested, weighted average grant-date fair value \| $ / shares	45.49
Forfeited, weighted average grant-date fair value \| $ / shares	27.14
Non-vested, weighted average grant-date fair value, end of period \| $ / shares	$ 27.88

Shareholders' Equity Share Repu

Shareholders' Equity Share Repurchase (Details) - USD ($) shares in Thousands, $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Shareholders' Equity [Abstract]
Stock Repurchased and Retired During Period, Shares	1,900	8,100
Stock Repurchased and Retired During Period, Value	$ 65.3	$ 126.9
Cumulative shares repurchased under share repurchase program	15,700
Cumulative treasury stock, retired, cost method, amount	$ 382.4

Shareholders' Equity Dividend (

Shareholders' Equity Dividend (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 20, 2021	May 24, 2021	Feb. 21, 2020	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2020	Sep. 30, 2021	Sep. 30, 2020
Dividend [Abstract]
Common Stock, Dividends, Per Share, Declared				$ 0.15	$ 0.11	$ 0.05
Payments of Dividends	$ 54,100	$ 40,000	$ 18,400				$ 94,054	$ 18,460

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Income Taxes (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Taxes [Abstract]
Income (loss) before income taxes	$ 486,162	$ (95,555)	$ 1,211,386	$ (648,848)
U.S. federal statutory tax rate	21.00%	21.00%	21.00%	21.00%
Expected income tax provision (benefit) based on U.S. federal statutory tax rate	$ 102,094	$ (20,067)	$ 254,391	$ (136,258)
State and local income taxes, net of federal benefit	17,109	(2,988)	43,559	(20,896)
Equity compensation	(11)	214	6,126	4,685
Other, net	(2,086)	2,540	(7,006)	(90)
Change in valuation allowance	(1,465)	6,329	(5,954)	14,209
Provision (benefit) for income taxes	$ 115,641	$ (13,972)	$ 291,116	$ (138,350)
Effective Income Tax Rate Reconciliation, Percent	23.80%	14.60%	24.00%	21.30%
Release of valuation allowance	$ 1,500		$ 5,900

Income Taxes Provision for inco

Income Taxes Provision for income taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Provision (benefit) for income taxes	$ 115,641	$ (13,972)	$ 291,116	$ (138,350)
Effective Income Tax Rate Reconciliation, Percent	23.80%	14.60%	24.00%	21.30%
Income (loss) before income taxes	$ 486,162	$ (95,555)	$ 1,211,386	$ (648,848)

Property Acquisitions (Details)

Property Acquisitions (Details) $ in Millions	9 Months Ended
Property Acquisitions (Details) $ in Millions	Sep. 30, 2021USD ($)aBoe	Dec. 31, 2020USD ($)
Property Acquisition [Abstract]
Costs Incurred, Acquisition of Oil and Gas Properties	$ 206.6
Escrow deposit per PSA		$ 21.5
Additional funds at closing per PSA	$ 185.1
Oil and Gas, Undeveloped Acreage, Net \| a	130,000
Daily production of acquired producing properties \| Boe	7,200
Amount of Asset Retirement Obligations associated with acquired properties	$ 4.9
Amount of right of use assets acquired in property acquisition	$ 12.4

Subsequent Events (Details)

Subsequent Events (Details) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended			9 Months Ended
	Nov. 03, 2021USD ($)aBoe$ / shares	Sep. 30, 2021Boe$ / shares	Jun. 30, 2021$ / shares	Mar. 31, 2020$ / shares	Sep. 30, 2021USD ($)Boe
Subsequent Event [Line Items]
Costs Incurred, Acquisition of Oil and Gas Properties					$ 206.6
Daily production of acquired producing properties \| Boe		7,200			7,200
Common Stock, Dividends, Per Share, Declared \| $ / shares		$ 0.15	$ 0.11	$ 0.05
Subsequent Event
Subsequent Event [Line Items]
Costs Incurred, Acquisition of Oil and Gas Properties	$ 3,250
Net leasehold acres \| a	92,000
Daily production of acquired producing properties \| Boe	55,000
Net mineral acres \| a	50,000
PSA deposit	$ 325
Common Stock, Dividends, Per Share, Declared \| $ / shares	$ 0.20