Continental Resources Inc (CLR) 10-Q11 May 202020 Q1 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information Document - shares	3 Months Ended
Document and Entity Information Document - shares	Mar. 31, 2020	Apr. 30, 2020
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	001-32886
Entity Registrant Name	CONTINENTAL RESOURCES, INC
Entity Central Index Key	0000732834
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
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		365,152,819
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	Mar. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 517,571	$ 39,400
Receivables:
Crude oil and natural gas sales	389,203	726,876
Joint interest and other	305,519	317,018
Allowance for credit losses	(2,694)	(2,407)
Receivables, Net, Current	692,028	1,041,487
Inventories	62,600	109,536
Prepaid expenses and other	22,973	16,592
Total current assets	1,295,172	1,207,015
Net property and equipment, based on successful efforts method of accounting	14,436,112	14,497,726
Operating lease right-of-use assets	12,684	9,128
Other noncurrent assets	12,743	14,038
Total assets	15,756,711	15,727,907
Current liabilities:
Accounts payable trade	673,669	629,264
Revenues and royalties payable	239,245	470,264
Accrued liabilities and other	160,596	230,368
Current portion of operating leases	6,243	3,695
Current portion of long-term debt	2,455	2,435
Total current liabilities	1,082,208	1,336,026
Long-term debt, net of current portion	5,964,589	5,324,079
Other noncurrent liabilities:
Deferred income tax liabilities, net	1,737,112	1,787,125
Asset retirement obligations, net of current portion	156,126	151,774
Operating lease liabilities, net of current portion	6,340	5,433
Other noncurrent liabilities	13,078	15,119
Total other noncurrent liabilities	1,912,656	1,959,451
Commitments and contingencies (Note 10)
Equity:
Preferred stock, $0.01 par value; 25,000,000 shares authorized; no shares issued and outstanding	0	0
Common stock, $0.01 par value; 1,000,000,000 shares authorized; 365,117,003 shares issued and outstanding at March 31, 2020; 371,074,036 shares issued and outstanding at December 31, 2019	3,651	3,711
Additional paid-in capital	1,157,866	1,274,732
Retained earnings	5,258,845	5,463,224
Total shareholders’ equity attributable to Continental Resources	6,420,362	6,741,667
Noncontrolling interests	376,896	366,684
Total Equity	6,797,258	7,108,351
Total liabilities and equity	$ 15,756,711	$ 15,727,907

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	25,000,000	25,000,000
Preferred stock, shares issued
Preferred stock, shares outstanding
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	1,000,000,000	1,000,000,000
Common Stock, Shares, Issued	365,117,003	371,074,036
Common Stock, Shares, Outstanding	365,117,003	371,074,036

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Revenues:
Crude oil and natural gas sales	$ 862,743	$ 1,109,584
Loss on natural gas derivatives, net	0	(1,124)
Crude oil and natural gas service operations	18,058	15,774
Total revenues	880,801	1,124,234
Operating costs and expenses:
Production expenses	118,478	106,966
Production taxes	71,224	86,441
Transportation expenses	60,502	49,139
Exploration expenses	11,637	1,837
Crude oil and natural gas service operations	5,910	7,186
Depreciation, depletion, amortization and accretion	536,696	495,019
Property impairments	222,529	25,316
General and administrative expenses	42,911	47,617
Net (gain) loss on sale of assets and other	4,502	(252)
Total operating costs and expenses	1,074,389	819,269
Income (loss) from operations	(193,588)	304,965
Other income (expense):
Interest expense	(63,594)	(67,837)
Gain on extinguishment of debt	17,631	0
Other	532	1,355
Total other income (expense)	(45,431)	(66,482)
Income (loss) before income taxes	(239,019)	238,483
(Provision) benefit for income taxes	52,235	(51,990)
Net income (loss)	(186,784)	186,493
Net loss attributable to noncontrolling interests	(1,120)	(483)
Net income (loss) attributable to Continental Resources	$ (185,664)	$ 186,976
Basic net income (loss) per share (in dollars per share)	$ (0.51)	$ 0.50
Diluted net income (loss) per share (in dollars per share)	$ (0.51)	$ 0.50
Foreign currency translation adjustments	$ 0	$ 116
Total other comprehensive income, net of tax	0	116
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(186,784)	186,609
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(1,120)	(483)
Comprehensive income (loss)	$ (185,664)	$ 187,092

Condensed Consolidated Statemen

Condensed Consolidated Statements of Shareholders Equity - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-In Capital	Treasury Stock [Member]	Accumulated Other Comprehensive Income	Retained Earnings	Continental Resources Shareholders' Equity	Noncontrolling Interest
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								$ 276,728
Total Equity	$ 6,421,861
Balance at Dec. 31, 2018		$ 3,760	$ 1,434,823		$ 415	$ 4,706,135	$ 6,145,133
Balance, shares at Dec. 31, 2018		376,021,575
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	186,976					186,976	186,976
Net loss attributable to noncontrolling interests	(483)							(483)
Net income (loss)	186,493
Other comprehensive income, net of tax (unaudited)	116				116		116
Contributions from Noncontrolling Interests	42,204							42,204
Distributions to Noncontrolling Interests	(3,856)							(3,856)
Stock-based compensation (unaudited)	12,095		12,095				12,095
Restricted stock:
Granted (unaudited)	13	$ 13					13
Granted (unaudited), shares		1,333,602
Repurchased and canceled (unaudited)	(20,622)	$ (4)	(20,618)				(20,622)
Repurchased and canceled (unaudited), shares		(439,419)
Forfeited (unaudited), shares		(147,074)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Mar. 31, 2019		$ 3,768	1,426,300		531	4,893,111	6,323,710
Balance, shares at Mar. 31, 2019		376,768,684
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								314,593
Total Equity	6,638,303
Noncontrolling interests	366,684							366,684
Total Equity	7,108,351
Balance at Dec. 31, 2019	$ 6,741,667	$ 3,711	1,274,732		0	5,463,224	6,741,667
Balance, shares at Dec. 31, 2019	371,074,036	371,074,036
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Continental Resources	$ (185,664)					(185,664)	(185,664)
Net loss attributable to noncontrolling interests	(1,120)							(1,120)
Net income (loss)	(186,784)
Cumulative effect adjustment from adoption of ASU 2016-13	(137)					(137)	(137)
Dividends, Common Stock, Cash	(18,580)					(18,580)	(18,580)
Change in dividends payable	2					2	2
Treasury Stock, Value, Acquired, Cost Method	(126,906)			$ (126,906)			(126,906)
Treasury Stock, Shares, Retired		(8,122,104)
Treasury Stock, Retired, Cost Method, Amount	(126,900)	$ (81)	(126,825)	$ (126,906)
Other comprehensive income, net of tax (unaudited)	0
Contributions from Noncontrolling Interests	16,950							16,950
Distributions to Noncontrolling Interests	(5,618)							(5,618)
Stock-based compensation (unaudited)	16,411		16,411				16,411
Restricted stock:
Granted (unaudited)	$ 24	$ 24					24
Granted (unaudited), shares	2,454,235	2,454,235
Repurchased and canceled (unaudited)	$ (6,454)	$ (2)	(6,452)				(6,454)
Repurchased and canceled (unaudited), shares	(8,100,000)	(246,346)
Forfeited (unaudited), shares	(42,818)	(42,818)
Forfeitures (unaudited)	$ (1)	$ (1)					(1)
Balance at Mar. 31, 2020	$ 6,420,362	$ 3,651	$ 1,157,866		$ 0	$ 5,258,845	$ 6,420,362
Balance, shares at Mar. 31, 2020	365,117,003	365,117,003
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests	$ 376,896							$ 376,896
Total Equity	$ 6,797,258

Unaudited Condensed Consolida_2

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Statement of Cash Flows [Abstract]
Net income (loss)	$ (186,784)	$ 186,493
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, Depletion, Amortization and Accretion	536,786	496,561
Property impairments	222,529	25,316
Non-cash loss on derivatives	0	14,186
Stock-based compensation	16,441	12,107
Provision (benefit) for deferred income taxes	(50,012)	51,990
Dry hole costs	6,259	0
Net (gain) loss on sale of assets and other	4,502	(252)
Gain on extinguishment of debt	(17,631)	0
Other, net	2,911	3,683
Changes in assets and liabilities:
Accounts receivable	344,845	(78,027)
Inventories	22,417	(14,742)
Other current assets	(4,848)	(5,786)
Accounts payable trade	70,084	24,341
Revenues and royalties payable	(231,990)	6,282
Accrued liabilities and other	(70,274)	(563)
Other noncurrent assets and liabilities	(1,417)	(81)
Net cash provided by operating activities	663,818	721,508
Cash flows from investing activities
Exploration and development	(673,191)	(732,770)
Purchase of producing crude oil and natural gas properties	(19,258)	(15,849)
Purchase of other property and equipment	(14,923)	(4,951)
Proceeds from sale of assets	633	499
Net cash used in investing activities	(706,739)	(753,071)
Cash flows from financing activities
Credit facility borrowings	1,130,000	100,000
Repayment of credit facility	(450,000)	(100,000)
Redemption of Senior Notes	22,527	0
Repayment of other debt	(603)	(576)
Contributions from noncontrolling interests	21,254	38,242
Distributions to noncontrolling interests	(5,212)	(3,874)
Payments for Repurchase of Common Stock	(126,906)	0
Repurchase of restricted stock for tax withholdings	(6,454)	(20,622)
Payments of Dividends	(18,460)	0
Net cash provided by financing activities	521,092	13,170
Effect of exchange rate changes on cash	0	15
Net change in cash and cash equivalents	478,171	(18,378)
Cash and cash equivalents, at beginning of period	39,400	282,749
Cash and cash equivalents, at end of period	$ 517,571	$ 264,371

Organization and Nature of Busi

Organization and Nature of Business	3 Months Ended
Organization and Nature of Business	Mar. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Business	Organization and Nature of Business Continental Resources, Inc. (the “Company”) was formed in 1967 and is incorporated under the laws of the State of Oklahoma. The Company’s principal business is crude oil and natural gas exploration, development and production with properties primarily located in the North, South, and East regions of the United States. Additionally, the Company pursues the acquisition and management of perpetually owned minerals located in certain of its key operating areas. The North region consists of properties north of Kansas and west of the Mississippi River and includes North Dakota Bakken, Montana Bakken, and the Red River units. The South region includes all properties south of Nebraska and west of the Mississippi River including various plays in the SCOOP and STACK areas of Oklahoma. The East region is primarily comprised of undeveloped leasehold acreage east of the Mississippi River with no significant drilling or production operations. The Company's operations in the North region comprised 58% of its crude oil and natural gas production and 69% of its crude oil and natural gas revenues for the three months ended March 31, 2020 . The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. The Company's operations in the South region comprised 42% of its crude oil and natural gas production and 31% of its crude oil and natural gas revenues for the three months ended March 31, 2020 . The Company's principal producing properties in the South region are located in the SCOOP and STACK areas of Oklahoma. For the three months ended March 31, 2020 , crude oil accounted for 56% of the Company’s total production and 90%

Basis of Presentation and Signi

Basis of Presentation and Significant Accounting Policies	3 Months Ended
Basis of Presentation and Significant Accounting Policies	Mar. 31, 2020
Accounting Policies [Abstract]
Basis of Presentation and Significant Accounting Policies	Basis of Presentation and Significant Accounting Policies Basis of presentation The condensed consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries, and entities in which the Company has a controlling financial interest. Intercompany accounts and transactions have been eliminated upon consolidation. Noncontrolling interests reflected herein represent third party ownership in the net assets of consolidated subsidiaries. The portions of consolidated net income (loss) and equity attributable to the noncontrolling interests are presented separately in the Company’s financial statements. This report has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information. Because this is an interim period filing presented using a condensed format, it does not include all disclosures required by accounting principles generally accepted in the United States (“U.S. GAAP”), although the Company believes the disclosures are adequate to make the information not misleading. You should read this Quarterly Report on Form 10-Q (“Form 10-Q”) together with the Company’s Annual Report on Form 10-K for the year ended December 31, 2019 (“ 2019 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures. The condensed consolidated financial statements as of March 31, 2020 and for the three month periods ended March 31, 2020 and 2019 are unaudited. The condensed consolidated balance sheet as of December 31, 2019 was derived from the audited balance sheet included in the 2019 Form 10-K. The Company has evaluated events or transactions through the date this report on Form 10-Q was filed with the SEC in conjunction with its preparation of these condensed consolidated financial statements. The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure and estimation of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results may differ from those estimates. The most significant estimates and assumptions impacting reported results are estimates of the Company’s crude oil and natural gas reserves, which are used to compute depreciation, depletion, amortization and impairment of proved crude oil and natural gas properties. In the opinion of management, all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation in accordance with U.S. GAAP have been included in these unaudited condensed consolidated financial statements. The results of operations for any interim period are not necessarily indicative of the results of operations that may be expected for any other interim period or for an entire year. Earnings per share Basic net income (loss) per share is computed by dividing net income (loss) attributable to the Company by the weighted-average number of shares outstanding for the period. In periods where the Company has net income, diluted earnings per share reflects the potential dilution of non-vested restricted stock awards, which are calculated using the treasury stock method. The following table presents the calculation of basic and diluted weighted average shares outstanding and net income (loss) per share attributable to the Company for the three months ended March 31, 2020 and 2019 . Three months ended March 31, In thousands, except per share data 2020 2019 Net income (loss) attributable to Continental Resources (numerator) $ (185,664 ) $ 186,976 Weighted average shares (denominator): Weighted average shares - basic 365,403 372,563 Non-vested restricted stock (1) — 1,911 Weighted average shares - diluted 365,403 374,474 Net income (loss) per share attributable to Continental Resources: Basic $ (0.51 ) $ 0.50 Diluted $ (0.51 ) $ 0.50 (1) For the three months ended March 31, 2020 the Company had a net loss and therefore the potential dilutive effect of approximately 594,000 weighted average non-vested restricted shares were not included in the calculation of diluted net loss per share because to do so would have been anti-dilutive to the computation. Inventories Inventory is comprised of crude oil held in storage or as line fill in pipelines, pipeline imbalances, and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or net realizable value primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued primarily using a weighted average cost method applied to specific classes of inventory items. The components of inventory as of March 31, 2020 and December 31, 2019 consisted of the following: In thousands March 31, 2020 December 31, 2019 Tubular goods and equipment $ 15,853 $ 14,880 Crude oil 46,747 94,656 Total $ 62,600 $ 109,536 For the three months ended March 31, 2020 , the Company recognized a $24.5 million impairment to reduce its crude oil inventory to estimated net realizable value at March 31, 2020 . The impairment is included in the caption “Property impairments” in the unaudited condensed consolidated statements of comprehensive income (loss). Adoption of new accounting pronouncement On January 1, 2020 the Company adopted Accounting Standards Update ("ASU") 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . See Note 5. Allowance for Credit Losses for discussion of the adoption impact and the applicable disclosures required by the new standard. New accounting pronouncement not yet adopted In December 2019, the Financial Accounting Standards Board ("FASB") issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
Supplemental Cash Flow Information	Mar. 31, 2020
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information The following table discloses supplemental cash flow information about cash paid for interest and income tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments. Three months ended March 31, In thousands 2020 2019 Supplemental cash flow information: Cash paid for interest $ 51,111 $ 61,964 Cash paid for income taxes 8 9 Cash received for income tax refunds (1) 9,485 4 Non-cash investing activities: Asset retirement obligation additions and revisions, net 2,508 2,570 (1) Amount received in the 2020 period primarily represents alternative minimum tax refunds. As of March 31, 2020 and December 31, 2019 , the Company had $232.2 million and $262.7 million , respectively, of accrued capital expenditures included in “Net property and equipment” and “Accounts payable trade” in the condensed consolidated balance sheets. As of March 31, 2020 and December 31, 2019 , the Company had $1.3 million and $5.6 million , respectively, of accrued contributions from noncontrolling interests included in "Receivables – Joint interest and other" and "Equity – Noncontrolling interests" in the condensed consolidated balance sheets. As of March 31, 2020 and December 31, 2019 , the Company had $1.9 million and $1.5 million , respectively, of accrued distributions to noncontrolling interests included in "Revenues and royalties payable" and "Equity –

Revenues

Revenues	3 Months Ended
Revenues	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Text Block]	Revenues Below is a discussion of the nature, timing, and presentation of revenues arising from the Company's major revenue-generating arrangements. Operated crude oil revenues – The Company pays third parties to transport the majority of its operated crude oil production from lease locations to downstream market centers, at which time the Company's customers take title and custody of the product in exchange for prices based on the particular market where the product was delivered. Operated crude oil revenues are recognized during the month in which control transfers to the customer and it is probable the Company will collect the consideration it is entitled to receive. Crude oil sales proceeds from operated properties are generally received by the Company within one month after the month in which a sale has occurred. Operated crude oil revenues are presented separately from transportation expenses as the Company controls the operated production prior to its transfer to customers. Transportation expenses associated with the Company's operated crude oil production totaled $50.4 million and $41.6 million for the three months ended March 31, 2020 and 2019 , respectively. Operated natural gas revenues – The Company sells the majority of its operated natural gas production to midstream customers at its lease locations based on market prices in the field where the sales occur. Under these arrangements, the midstream customers obtain control of the unprocessed gas stream at the lease location and the Company's revenues from each sale are determined using contractually agreed pricing formulas which contain multiple components, including the volume and Btu content of the natural gas sold, the midstream customer's proceeds from the sale of residue gas and natural gas liquids ("NGLs") at secondary downstream markets, and contractual pricing adjustments reflecting the midstream customer's estimated recoupment of its investment over time. Such revenues are recognized net of pricing adjustments applied by the midstream customer during the month in which control transfers to the customer at the delivery point and it is probable the Company will collect the consideration it is entitled to receive. Natural gas sales proceeds from operated properties are generally received by the Company within one month after the month in which a sale has occurred. Under certain arrangements, 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 $10.1 million and $7.5 million for the three months ended March 31, 2020 and 2019 , respectively. Non-operated crude oil and natural gas revenues – The Company's proportionate share of production from non-operated properties is generally marketed at the discretion of the operators. For non-operated properties, the Company receives a net payment from the operator representing its proportionate share of sales proceeds which is net of costs incurred by the operator, if any. Such non-operated revenues are recognized at the net amount of proceeds to be received by the Company during the month in which production occurs and it is probable the Company will collect the consideration it is entitled to receive. Proceeds are generally received by the Company within two to three months after the month in which production occurs. Revenues from derivative instruments – See Note 6. Derivative Instruments for discussion of the Company's accounting for its derivative instruments. Revenues from service operations – Revenues from the Company's crude oil and natural gas service operations consist primarily of revenues associated with water gathering, recycling, and disposal activities and the treatment and sale of crude oil reclaimed from waste products. Revenues associated with such activities, which are derived using market-based rates or rates commensurate with industry guidelines, are recognized during the month in which services are performed, the Company has an unconditional right to receive payment, and collectability is probable. Payment is generally received by the Company within one month after the month in which services are provided. Disaggregation of crude oil and natural gas revenues The following tables present the disaggregation of the Company's crude oil and natural gas revenues for the three months ended March 31, 2020 and 2019 . Three months ended March 31, 2020 Three months ended March 31, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 448,930 $ 179,176 $ 628,106 $ 585,605 $ 136,547 $ 722,152 Non-operated properties 132,939 12,725 145,664 178,728 10,238 188,966 Total crude oil revenues 581,869 191,901 773,770 764,333 146,785 911,118 Natural gas revenues: Operated properties 11,588 72,306 83,894 51,461 124,698 176,159 Non-operated properties 1,720 3,359 5,079 10,866 11,441 22,307 Total natural gas revenues 13,308 75,665 88,973 62,327 136,139 198,466 Crude oil and natural gas sales $ 595,177 $ 267,566 $ 862,743 $ 826,660 $ 282,924 $ 1,109,584 Timing of revenue recognition Goods transferred at a point in time $ 595,177 $ 267,566 $ 862,743 $ 826,660 $ 282,924 $ 1,109,584 Goods transferred over time — — — — — — $ 595,177 $ 267,566 $ 862,743 $ 826,660 $ 282,924 $ 1,109,584 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 March 31, 2020 are short-term in nature with contract terms of less than one year. For such contracts, the Company has utilized the practical expedient in Accounting Standards Codification ("ASC") 606-10-50-14 exempting the Company from disclosure of the transaction price allocated to remaining performance obligations, if any, if the performance obligation is part of a contract that has an original expected duration of one year or less. The majority of the Company's operated natural gas production is sold at lease locations to midstream customers under multi-year term contracts. For such contracts having a term greater than one year, the Company has utilized the practical expedient in ASC 606-10-50-14A which indicates an entity is not required to disclose the transaction price allocated to remaining performance obligations, if any, if variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under the Company's sales contracts, whether for crude oil or natural gas, each unit of production delivered to a customer represents a separate performance obligation; therefore, future volumes to be delivered are wholly unsatisfied at period-end and disclosure of the transaction price allocated to remaining performance obligations is not applicable. Contract balances Under the Company’s crude oil and natural gas sales contracts or activities that give rise to service revenues, the Company recognizes revenue after its performance obligations have been satisfied, at which point the Company has an unconditional right to receive payment. Accordingly, the Company’s commodity sales contracts and service activities generally do not give rise to contract assets or contract liabilities under ASC Topic 606. Instead, the Company's unconditional rights to receive consideration are presented as a receivable within "Receivables – Crude oil and natural gas sales" or "Receivables – Joint interest and other", as applicable, in its condensed consolidated balance sheets. Revenues from previously satisfied performance obligations To record revenues for commodity sales, at the end of each month the Company estimates the amount of production delivered and sold to customers and the prices to be received for such sales. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month payment is received from the customer and are reflected in the financial statements within the caption "Crude oil and natural gas sales". Revenues recognized during the three months ended March 31, 2020 and 2019 related to performance obligations satisfied in prior reporting periods were not material.

Derivative Instruments

Derivative Instruments	3 Months Ended
Derivative Instruments	Mar. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments Natural gas derivatives As of and for the three months ended March 31, 2019 the Company had outstanding natural gas derivative contracts to economically hedge against the variability in cash flows associated with sales of natural gas production. Such contracts matured in 2019 and the Company had no commodity derivative contracts outstanding at December 31, 2019 and March 31, 2020 . The Company recognizes its derivative instruments, if any, on the balance sheet as either assets or liabilities measured at fair value. The estimated fair value of derivatives 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. Historically, the Company has not designated its derivatives as hedges for accounting purposes and, as a result, marked its derivative instruments to fair value and recognized the changes in fair value in the unaudited condensed consolidated statements of comprehensive income (loss) under the caption “ Loss on natural gas derivatives, net ”. Natural gas derivative gains and losses Cash receipts in the following table reflect the gain on derivative contracts which matured during the applicable period, calculated as the difference between the contract price and the market settlement price of matured contracts. The Company's 2019 natural gas derivatives were settled based upon reported NYMEX Henry Hub settlement prices. Non-cash losses below represent the change in fair value of derivative instruments which continued to be held at period end, if any, and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period. Three months ended March 31, In thousands 2020 2019 Cash received on derivatives: Natural gas fixed price swaps $ — $ 7,645 Natural gas collars — 5,417 Cash received on derivatives, net — 13,062 Non-cash loss on derivatives: Natural gas fixed price swaps — (8,704 ) Natural gas collars — (5,482 ) Non-cash loss on derivatives, net — (14,186 ) Loss on natural gas derivatives, net $ — $ (1,124 )

Allowance for Credit Losses (No

Allowance for Credit Losses (Notes)	3 Months Ended
Allowance for Credit Losses (Notes)	Mar. 31, 2020
Allowance for Credit Losses [Abstract]
Credit Loss, Financial Instrument [Text Block]	Allowance for Credit Losses In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . This standard changes how entities measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The standard replaced the previously required incurred loss approach with a forward-looking expected credit loss model for accounts receivable and other financial instruments measured at amortized cost. The standard became effective for reporting periods beginning after December 15, 2019. The Company adopted the new standard on January 1, 2020 using a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the effective date. The Company's cumulative effect adjustment resulted in a $0.1 million decrease in retained earnings and corresponding decrease in receivables via the recognition of an incremental allowance for credit losses at January 1, 2020. The Company's principal exposure to credit risk is through the sale of its crude oil and natural gas production and its receivables associated with billings to joint interest owners. Accordingly, the Company classifies its receivables into two portfolio segments as depicted on the condensed consolidated balance sheets as "Receivables — Crude oil and natural gas sales” and "Receivables — Joint interest and other.” Presented below are applicable disclosures required by ASU 2016-13 for each portfolio segment. Historically, the Company's credit losses on receivables have been immaterial. The Company’s aggregate allowance for credit losses totaled $2.7 million and $2.4 million at March 31, 2020 and December 31, 2019 , respectively, which is reported as "Allowance for credit losses" in the condensed consolidated balance sheets. Aggregate credit loss expenses totaled $0.7 million and $0.1 million for the three months ended March 31, 2020 and 2019 , respectively, which is included in “General and administrative expenses” in the unaudited condensed consolidated statements of comprehensive income (loss). Receivables—Crude oil and natural gas sales The Company's crude oil and natural gas production from operated properties is generally sold to energy marketing companies, crude oil refining companies, and natural gas gathering and processing companies. The Company monitors its credit loss exposure to these counterparties primarily by reviewing credit ratings, financial statements, and payment history. Credit terms are extended based on an evaluation of each counterparty’s credit worthiness. The Company has not generally required its counterparties to provide collateral to secure its crude oil and natural gas sales receivables. Receivables associated with crude oil and natural gas sales are short term in nature. Receivables from the sale of crude oil and natural gas from operated properties are generally collected within one month after the month in which a sale has occurred, while receivables associated with non-operated properties are generally collected within two to three months after the month in which production occurs. The Company’s allowance for credit losses on crude oil and natural gas sales was less than $0.1 million at both March 31, 2020 and December 31, 2019 . The allowance was determined by considering a number of factors, primarily including the Company’s history of credit losses with adjustment as needed to reflect current conditions, the length of time accounts are past due, whether amounts relate to operated properties or non-operated properties, and the counterparty's ability to pay. There were no significant write-offs, recoveries, or changes in the provision for credit losses on this portfolio segment during the three months ended March 31, 2020 . Receivables—Joint interest and other Joint interest and other receivables primarily arise from billing the individuals and entities who own a partial interest in the wells we operate. Joint interest receivables are due within 30 days and are considered delinquent after 60 days. In order to minimize our exposure to credit risk with these counterparties we generally request prepayment of drilling costs where it is allowed by contract or state law. Such prepayments are used to offset future capital costs when billed, thereby reducing the Company's credit risk. We may have the right to place a lien on a co-owner's interest in the well, to net production proceeds against amounts owed in order to secure payment or, if necessary, foreclose on the co-owner's interest. The Company’s allowance for credit losses on joint interest receivables totaled $2.7 million and $2.4 million at March 31, 2020 and December 31, 2019 , respectively. The allowance was determined by considering a number of factors, primarily including the Company’s history of credit losses with adjustment as needed to reflect current conditions, the length of time accounts are past due, the ability to recoup amounts owed through netting of production proceeds, the balance of co-owner prepayments if any, and the co-owner's ability to pay. There were no significant write-offs, recoveries, or changes in the provision for credit losses on this portfolio segment during the three months ended March 31, 2020

Fair Value Measurements

Fair Value Measurements	3 Months Ended
Fair Value Measurements	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The Company follows a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows: • Level 1: Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date. • Level 2: Observable market-based inputs or unobservable inputs corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. • Level 3: Unobservable inputs not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value. A financial instrument’s categorization within the hierarchy is based upon the lowest level of input that is significant to the fair value measurement. Level 1 inputs are given the highest priority in the fair value hierarchy while Level 3 inputs are given the lowest priority. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the hierarchy. As Level 1 inputs generally provide the most reliable evidence of fair value, the Company uses Level 1 inputs when available. Assets and Liabilities Measured at Fair Value on a Recurring Basis The Company's derivative instruments, if any, 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 Company had no outstanding commodity derivative instruments at March 31, 2020 and December 31, 2019 . 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 March 31, 2020, the Company's commodity price assumptions were based on forward NYMEX strip prices through year-end 2024 and were then escalated at 3% per year thereafter. 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 months ended March 31, 2020 , given the significant declines in commodity prices during the quarter the Company determined the carrying amounts of certain proved properties were not recoverable from future cash flows and therefore were impaired. Such impairments totaled $181.0 million which reflect fair value adjustments on legacy properties in the Red River Units ( $166.5 million ) and various non-core properties in the North and South regions ( $14.5 million ). The impaired properties were written down to their estimated fair value of $145.6 million . Impairments for 2020 also include a $24.5 million impairment to reduce the Company's crude oil inventory to estimated net realizable value at March 31, 2020 . For the three months ended March 31, 2019 , estimated future net cash flows were determined to be in excess of cost basis, therefore no impairment was recorded for the Company’s proved crude oil and natural gas properties for that period. Certain unproved crude oil and natural gas properties were impaired during the three months ended March 31, 2020 and 2019 , reflecting recurring amortization of undeveloped leasehold costs on properties the Company expects will not be transferred to proved properties over the lives of the leases based on drilling plans, experience of successful drilling, and the average holding period. The following table sets forth the non-cash impairments of both proved and unproved properties for the indicated periods. Proved and unproved property impairments are recorded under the caption “Property impairments” in the unaudited condensed consolidated statements of comprehensive income (loss). Three months ended March 31, In thousands 2020 2019 Proved property impairments $ 205,545 $ — Unproved property impairments 16,984 25,316 Total $ 222,529 $ 25,316 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. March 31, 2020 December 31, 2019 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 735,000 $ 735,000 $ 55,000 $ 55,000 Note payable 4,753 4,800 5,351 5,400 5% Senior Notes due 2022 1,099,234 692,400 1,099,165 1,108,700 4.5% Senior Notes due 2023 1,458,753 812,200 1,491,339 1,571,400 3.8% Senior Notes due 2024 987,644 507,700 994,310 1,034,200 4.375% Senior Notes due 2028 989,928 463,700 989,661 1,063,700 4.9% Senior Notes due 2044 691,732 298,600 691,688 742,000 Total debt $ 5,967,044 $ 3,514,400 $ 5,326,514 $ 5,580,400 The fair value of credit facility borrowings approximate carrying value based on borrowing rates available to the Company for bank loans with similar terms and maturities and are classified as Level 2 in the fair value hierarchy. The fair value of the note payable is determined using a discounted cash flow approach based on the interest rate and payment terms of the note payable and an assumed discount rate. The fair value of the note payable is significantly influenced by the discount rate assumption, which is derived by the Company and is unobservable. Accordingly, the fair value of the note 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”), 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	3 Months Ended
Long-Term Debt	Mar. 31, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $32.4 million and $33.9 million at March 31, 2020 and December 31, 2019 , respectively, consists of the following. In thousands March 31, 2020 December 31, 2019 Credit facility $ 735,000 $ 55,000 Note payable 4,753 5,351 5% Senior Notes due 2022 1,099,234 1,099,165 4.5% Senior Notes due 2023 1,458,753 1,491,339 3.8% Senior Notes due 2024 987,644 994,310 4.375% Senior Notes due 2028 989,928 989,661 4.9% Senior Notes due 2044 691,732 691,688 Total debt $ 5,967,044 $ 5,326,514 Less: Current portion of long-term debt 2,455 2,435 Long-term debt, net of current portion $ 5,964,589 $ 5,324,079 Credit Facility The Company has an unsecured credit facility, maturing on April 9, 2023 , with aggregate lender commitments totaling $1.5 billion . The Company had $735 million of outstanding borrowings on its credit facility at March 31, 2020 . In March 2020, the Company elected to draw $500 million on its credit facility to increase its cash on hand. At March 31, 2020 , the Company's cash on hand totaled $517.6 million . Credit facility borrowings bear interest at market-based interest rates plus a margin based on the terms of the borrowing and the credit ratings assigned to the Company's senior, unsecured, long-term indebtedness. The weighted-average interest rate on outstanding credit facility borrowings at March 31, 2020 was 2.6% . The Company had approximately $762 million of borrowing availability on its credit facility at March 31, 2020 after considering outstanding borrowings and letters of credit. The Company incurs commitment fees based on currently assigned credit ratings of 0.25% per annum on the daily average amount of unused borrowing availability. The credit facility contains certain restrictive covenants including a requirement that the Company maintain a consolidated net debt to total capitalization ratio of no greater than 0.65 to 1.00. This ratio represents the ratio of net debt (calculated as total face value of debt plus outstanding letters of credit less cash and cash equivalents) divided by the sum of net debt plus total shareholders' equity plus, to the extent resulting in a reduction of total shareholders’ equity, the amount of any non-cash impairment charges incurred, net of any tax effect, after June 30, 2014. The Company was in compliance with the credit facility covenants at March 31, 2020 . Senior Notes The following table summarizes the face values, maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at March 31, 2020 . In March 2020 the Company repurchased a portion of its 2023 Notes and 2024 Notes in open market transactions as further discussed below under the heading Repurchase of Senior Notes . 2022 Notes (1) 2023 Notes 2024 Notes 2028 Notes 2044 Notes Face value (in thousands) $1,100,000 $1,466,625 $993,000 $1,000,000 $700,000 Maturity date Sep 15, 2022 April 15, 2023 June 1, 2024 January 15, 2028 June 1, 2044 Interest payment dates March 15, Sep 15 April 15, Oct 15 June 1, Dec 1 Jan 15, July 15 June 1, Dec 1 Make-whole redemption period (2) — Jan 15, 2023 Mar 1, 2024 Oct 15, 2027 Dec 1, 2043 (1) The Company has the option to redeem all or a portion of its remaining 2022 Notes at the decreasing redemption prices specified in the indenture related to the 2022 Notes plus any accrued and unpaid interest to the date of redemption. (2) At any time prior to the indicated dates, the Company has the option to redeem all or a portion of its senior notes of the applicable series at the “make-whole” redemption amounts specified in the respective senior note indentures plus any accrued and unpaid interest to the date of redemption. On or after the indicated dates, the Company may redeem all or a portion of its senior notes at a redemption amount equal to 100% of the principal amount of the senior notes being redeemed plus any accrued and unpaid interest to the date of redemption. The Company’s senior notes are not subject to any mandatory redemption or sinking fund requirements. The indentures governing the Company’s senior notes contain covenants that, among other things, limit the Company’s ability to create liens securing certain indebtedness, enter into certain sale-leaseback transactions, or consolidate, merge or transfer certain assets. The senior note covenants are subject to a number of important exceptions and qualifications. The Company was in compliance with these covenants at March 31, 2020 . Three of the Company’s wholly-owned subsidiaries, Banner Pipeline Company, L.L.C., CLR Asset Holdings, LLC, and The Mineral Resources Company, the value of 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, the value of whose assets, equity, and results of operations attributable to the Company are not material, do not guarantee the senior notes. Repurchase of Senior Notes In March 2020, the Company repurchased a portion of its 2023 Notes and 2024 Notes in open market transactions at a substantial discount to the face value of the notes, including $33.4 million face value of its 2023 Notes at an aggregate cost of $19.5 million and $7.0 million face value of its 2024 Notes at an aggregate cost of $3.8 million , in each case, including accrued and unpaid interest to the repurchase dates. The repurchased notes were subsequently canceled by the Company. The Company recognized pre-tax gains on extinguishment of debt related to the March 2020 repurchases totaling $17.6 million , which included the pro-rata write-off of deferred financing costs and unamortized debt discount associated with the notes. The gains are reflected in the caption “Gain on extinguishment of debt” in the unaudited condensed consolidated statements of comprehensive income (loss). Subsequent to March 31, 2020 , the Company repurchased and canceled additional amounts of its 2023 Notes and 2024 Notes. See Note 14. Subsequent Events for further information. Note payable In February 2012, 20 Broadway Associates LLC, a wholly-owned subsidiary of the Company, borrowed $22 million under a 10 -year amortizing term loan secured by the Company’s corporate office building in Oklahoma City, Oklahoma. The loan bears interest at a fixed rate of 3.14% per annum. Principal and interest are payable monthly through the loan’s maturity date of February 26, 2022 . Accordingly, approximately $2.5 million is reflected as a current liability under the caption “Current portion of long-term debt” in the condensed consolidated balance sheets as of March 31, 2020 .

Leases

Leases	3 Months Ended
Leases	Mar. 31, 2020
Leases [Abstract]
Lessee, Operating Leases [Text Block]	Leases The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $12.6 million as of March 31, 2020 at discounted present value, which is comprised of the asset classes reflected in the table below. All leases recognized on the Company's balance sheet are classified as operating leases. The amounts disclosed herein primarily represent costs associated with properties operated by the Company that are presented on a gross basis and do not reflect the Company's net proportionate share of such amounts. A portion of these costs have been or will be billed to other working interest owners. Once paid, the Company's share of these costs are included in property and equipment, production expenses, or general and administrative expenses, as applicable. The Company's leasing activities as a lessor are negligible. In thousands Amount Drilling rig commitments $ 6,048 Surface use agreements 5,091 Field equipment 1,105 Other 339 Total $ 12,583 Drilling rig commitments reflected above represent minimum payment obligations expected to be incurred on enforceable commitments with durations in excess of one year at the inception of the lease. Minimum future commitments by year for the Company's operating leases as of March 31, 2020 are presented in the table below. Such commitments are reflected at undiscounted values and are reconciled to the discounted present value recognized on the balance sheet. In thousands Amount Remainder of 2020 $ 4,954 2021 2,574 2022 782 2023 729 2024 456 Thereafter 6,676 Total operating lease liabilities, at undiscounted value $ 16,171 Less: Imputed interest (3,588 ) Total operating lease liabilities, at discounted present value $ 12,583 Less: Current portion of operating lease liabilities (6,243 ) Operating lease liabilities, net of current portion $ 6,340 Additional information for the Company's operating leases is presented below. Lease costs are reflected at gross amounts and primarily represent costs incurred for drilling rigs, most of which are short term contracts that are not recognized as right-of-use assets and lease liabilities on the balance sheet. Variable lease costs primarily represent differences between minimum payment obligations and actual operating day-rate charges incurred by the Company for its long term drilling rig contracts. Short-term lease costs primarily represent operating day-rate charges for drilling rig contracts with durations of one year or less and month-to-month field equipment rentals. In thousands, except weighted average data Three months ended March 31, 2020 Lease costs: Operating lease costs $ 1,260 Variable lease costs 3,223 Short-term lease costs 51,348 Total lease costs $ 55,831 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 7,002 Operating cash flows from operating leases included in lease liabilities 228 Weighted average remaining lease term as of March 31, 2020 (in years) 9.8 Weighted average discount rate as of March 31, 2020 4.1 %

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Included below is a discussion of certain future commitments and contingencies of the Company as of March 31, 2020 . Drilling rig commitments – As of March 31, 2020 , the Company has drilling rig contracts with various terms extending to April 2021 . Future operating day-rate commitments as of March 31, 2020 total approximately $36 million , of which $33 million is expected to be incurred in the remainder of 2020 and $3 million will be incurred in 2021 . A portion of these future costs will be borne by other interest owners. Such future commitments include minimum payment obligations with a discounted present value totaling $6.0 million that are required to be recognized on the Company's balance sheet at March 31, 2020 in accordance with ASC Topic 842 as discussed in Note 9. Leases . Other lease commitments – The Company has various other lease commitments primarily associated with surface use agreements and field equipment. See Note 9. Leases for additional information. Transportation, gathering, and processing commitments – The Company has entered into transportation, gathering, and processing commitments to guarantee capacity on crude oil and natural gas pipelines and natural gas processing facilities. The commitments, which have varying terms extending as far as 2031, require the Company to pay per-unit transportation, gathering, or processing charges regardless of the amount of capacity used. Future commitments remaining as of March 31, 2020 under the arrangements amount to approximately $2.11 billion , of which $210 million is expected to be incurred in the remainder of 2020 , $326 million in 2021 , $329 million in 2022 , $331 million in 2023 , $298 million in 2024, and $615 million thereafter. A portion of these future costs will be borne by other interest owners. The Company is not committed under the above contracts to deliver fixed and determinable quantities of crude oil or natural gas in the future. These commitments do not qualify as leases under ASC Topic 842 and are not recognized on the Company's balance sheet. Litigation – 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. As of March 31, 2020 and December 31, 2019 , the Company had recognized a liability within “Other noncurrent liabilities” of $7.5 million and $8.7 million , respectively, for various matters, none of which are believed to be individually significant. See Note 14. Subsequent Events for discussion of a new legal matter involving the Company that was initiated subsequent to March 31, 2020 . 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	3 Months Ended
Stock-Based Compensation	Mar. 31, 2020
Share-based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation The Company has granted restricted stock to employees and directors pursuant to the Continental Resources, Inc. 2013 Long-Term Incentive Plan, as amended ("2013 Plan"). The Company’s associated compensation expense, which is included in the caption “General and administrative expenses” in the unaudited condensed consolidated statements of comprehensive income (loss), was $16.4 million and $12.1 million for the three months ended March 31, 2020 and 2019 , respectively. In March 2019, the Company amended and restated its 2013 Plan and reserved 12,983,543 shares of common stock that may be issued pursuant to the amended plan. The 2013 Plan allows previously issued shares to be reissued if such shares are subsequently forfeited after issuance. As of March 31, 2020 , the Company had 10,871,733 shares of common stock available for long-term incentive awards to employees and directors under the 2013 Plan. Restricted stock is awarded in the name of the recipient and constitutes issued and outstanding shares of the Company’s common stock for all corporate purposes during the period of restriction and, except as otherwise provided under the 2013 Plan or agreement relevant to a given award, includes the right to vote the restricted stock and to receive dividends if any, subject to forfeiture. Restricted stock grants generally vest over periods ranging from 1 to 3 years. A summary of changes in non-vested restricted shares outstanding for the three months ended March 31, 2020 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2019 3,461,908 $ 46.82 Granted 2,454,235 28.41 Vested (925,568 ) 46.19 Forfeited (42,818 ) 39.88 Non-vested restricted shares outstanding at March 31, 2020 4,947,757 $ 37.87 The grant date fair value of restricted stock represents the closing market price of the Company’s common stock on the date of grant. Compensation expense for a restricted stock grant is determined at the grant date fair value and is recognized over the vesting period as services are rendered by employees and directors. The Company estimates the number of forfeitures expected to occur in determining the amount of stock-based compensation expense to recognize. There are no post-vesting restrictions related to the Company’s restricted stock. The fair value at the vesting date of restricted stock that vested during the three months ended March 31, 2020 was approximately $24 million . As of March 31, 2020 , there was approximately $117 million of unrecognized compensation expense related to non-vested restricted stock. This expense is expected to be recognized over a weighted average period of 1.9

Shareholders' Equity

Shareholders' Equity	3 Months Ended
Shareholders' Equity	Mar. 31, 2020
Shareholders' Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Shareholders' Equity Share repurchases For the three months ended March 31, 2020 , the Company repurchased and retired approximately 8.1 million shares of its common stock at an aggregate cost of $126.9 million . Through March 31, 2020 , the Company had repurchased and retired a cumulative total of approximately 13.8 million shares at an aggregate cost of $317.1 million since the inception of its $1 billion share repurchase program in June 2019. The timing and amount of the Company's share repurchases are subject to market conditions and management discretion. The share repurchase program does not require the Company to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board of Directors at any time. Dividend payment On January 27, 2020 the Company declared a quarterly cash dividend of $0.05 per share on its outstanding common stock, which amounted to $18.4 million and was paid on February 21, 2020 to shareholders of record as of February 7, 2020.

Income Taxes

Income Taxes	3 Months Ended
Income Taxes	Mar. 31, 2020
Income Taxes [Abstract]
Income Tax Disclosure [Text Block]	Income Taxes Income taxes are accounted for using the liability method under which deferred income taxes are recognized for the future tax effects of temporary differences between financial statement carrying amounts and the tax basis of existing assets and liabilities using the enacted statutory tax rates in effect at period-end. The effect on deferred taxes for a change in tax rates is recognized in income in the period that includes the enactment date. The Company’s policy is to recognize penalties and interest related to unrecognized tax benefits, if any, in income tax expense. The Company's provision (benefit) for income taxes and resulting effective tax rates were as follows for the periods presented. Three months ended March 31, 2020 2019 Provision (benefit) for income taxes (in thousands) $ (52,235 ) $ 51,990 Effective tax rate 21.9 % 21.8 % The Company computes its quarterly income tax provision (benefit) under the effective tax rate method based on applying an anticipated annual effective tax rate to year-to-date pre-tax income (loss), except for discrete items. Income taxes for discrete items are computed and recorded in the period in which the specific transaction occurs. The Company's effective tax rate differs from the United States federal statutory tax rate due to the effect of state income taxes, equity compensation, valuation allowances, and other tax items as reflected in the table below. Three months ended March 31, In thousands, except tax rates 2020 2019 Income (loss) before income taxes $ (239,019 ) $ 238,483 U.S. federal statutory tax rate 21.0 % 21.0 % Expected income tax provision (benefit) based on U.S. federal statutory tax rate (50,194 ) 50,081 Items impacting the effective tax rate: State and local income taxes, net of federal benefit (7,603 ) 7,798 Equity compensation 3,886 (8,318 ) Other, net (3,189 ) 2,429 Valuation allowance 4,865 — Provision (benefit) for income taxes $ (52,235 ) $ 51,990 Effective tax rate 21.9 % 21.8 % The Company reduces its deferred tax assets by a valuation allowance if, based upon the weight of available evidence, it is more-likely-than-not that the Company will not realize some portion or all of the deferred tax assets. The Company considers relevant evidence, both positive and negative, to determine the need for a valuation allowance. Information evaluated includes the Company's financial position and results of operations for the current and preceding years, the availability of deferred tax liabilities and tax carrybacks, as well as an evaluation of currently available information about future years. The Company determined it was more-likely-than-not that a portion of its Oklahoma NOL carryforwards would not be able to be utilized before expiration, and a valuation allowance of approximately $4.9 million was established for the deferred tax assets associated with such NOL carryforwards. The Company will continue to evaluate both the positive and negative evidence on a quarterly basis in determining the need for a valuation allowance with respect to its deferred tax assets. Changes in positive and negative evidence, including differences between estimated and actual results, could result in changes in the valuation of our deferred tax assets that could have a material impact on our consolidated financial statements. Changes in existing tax laws could also affect actual tax results and the realization of deferred tax assets over time.

Subsequent Events (Notes)

Subsequent Events (Notes)	3 Months Ended
Subsequent Events (Notes)	Mar. 31, 2020
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events In March 2020, the World Health Organization declared a global pandemic related to the proliferation of COVID-19 (novel coronavirus). The adverse economic effects of the COVID-19 pandemic continue to evolve as of the filing of this report. The catastrophe caused by the COVID-19 pandemic has materially decreased global and domestic demand for crude oil based on changes in consumer behavior and restrictions implemented by governments to mitigate the pandemic. This destruction of demand has led to an unprecedented decline in crude o il prices. In response to these developments, the Company began shutting in production in April 2020 and currently has approximately 70% of its operated crude oil production and associated natural gas shut-in. The duration and extent of our production shut-ins are being evaluated on an ongoing basis and are subject to change as market conditions evolve. Given the uncertain duration of the catastrophe caused by the COVID-19 pandemic and the potential for a longer-term impact on consumer behaviors, the Company is not able to estima te the effects of the pandemic on its results of operations, financial condition, or cash flows for the remainder of 2020. Nevertheless, a near term material negative impact on the Company's production, revenues, cash flows, and earnings is certain to occur for the second quarter of 2020. On April 15, 2020, Casillas Petroleum Resource Partners II, LLC filed a petition against the Company in the District Court of Tulsa County, State of Oklahoma. In its petition Casillas alleges the Company breached a Purchase and Sale Agreement (“PSA”) to purchase oil and gas interests in Oklahoma for $200 million . Casillas seeks specific performance. The Company terminated the PSA due to Casillas’ breach of the agreement and denies the allegations and will vigorously defend the claims. The Company will also seek affirmative relief. The Company is not currently able to estimate what impact, if any, the ultimate resolution of the action will have on its financial condition, results of operations, or cash flows due to the preliminary status of the matter. In April 2020, the Company repurchased and canceled an additional $17.0 million face value of its 2023 Notes at an aggregate cost of $9.8 million and an additional $82.0 million face value of its 2024 Notes at an aggregate cost of $43.1 million , in each case, including accrued and unpaid interest to the repurchase dates. The Company estimates it will recognize pre-tax gains on extinguishment of debt related to the April 2020 repurchases totaling $47.0 million

Basis of Presentation and Sig_2

Basis of Presentation and Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2020
Accounting Policies [Abstract]
Description of the Company	Continental Resources, Inc. (the “Company”) was formed in 1967 and is incorporated under the laws of the State of Oklahoma. The Company’s principal business is crude oil and natural gas exploration, development and production with properties primarily located in the North, South, and East regions of the United States. Additionally, the Company pursues the acquisition and management of perpetually owned minerals located in certain of its key operating areas. The North region consists of properties north of Kansas and west of the Mississippi River and includes North Dakota Bakken, Montana Bakken, and the Red River units. The South region includes all properties south of Nebraska and west of the Mississippi River including various plays in the SCOOP and STACK areas of Oklahoma. The East region is primarily comprised of undeveloped leasehold acreage east of the Mississippi River with no significant drilling or production operations. The Company's operations in the North region comprised 58% of its crude oil and natural gas production and 69% of its crude oil and natural gas revenues for the three months ended March 31, 2020 . The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. The Company's operations in the South region comprised 42% of its crude oil and natural gas production and 31% of its crude oil and natural gas revenues for the three months ended March 31, 2020 . The Company's principal producing properties in the South region are located in the SCOOP and STACK areas of Oklahoma. For the three months ended March 31, 2020 , crude oil accounted for 56% of the Company’s total production and 90%
Basis of Presentation	Basis of presentation The condensed consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries, and entities in which the Company has a controlling financial interest. Intercompany accounts and transactions have been eliminated upon consolidation. Noncontrolling interests reflected herein represent third party ownership in the net assets of consolidated subsidiaries. The portions of consolidated net income (loss) and equity attributable to the noncontrolling interests are presented separately in the Company’s financial statements. This report has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information. Because this is an interim period filing presented using a condensed format, it does not include all disclosures required by accounting principles generally accepted in the United States (“U.S. GAAP”), although the Company believes the disclosures are adequate to make the information not misleading. You should read this Quarterly Report on Form 10-Q (“Form 10-Q”) together with the Company’s Annual Report on Form 10-K for the year ended December 31, 2019 (“ 2019 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures. The condensed consolidated financial statements as of March 31, 2020 and for the three month periods ended March 31, 2020 and 2019 are unaudited. The condensed consolidated balance sheet as of December 31, 2019 was derived from the audited balance sheet included in the 2019 Form 10-K. The Company has evaluated events or transactions through the date this report on Form 10-Q was filed with the SEC in conjunction with its preparation of these condensed consolidated financial statements. The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure and estimation of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results may differ from those estimates. The most significant estimates and assumptions impacting reported results are estimates of the Company’s crude oil and natural gas reserves, which are used to compute depreciation, depletion, amortization and impairment of proved crude oil and natural gas properties. In the opinion of management, all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation in accordance with U.S. GAAP have been included in these unaudited condensed consolidated financial statements. The results of operations for any interim period are not necessarily indicative of the results of operations that may be expected for any other interim period or for an entire year.
Earnings Per Share	Earnings per share
Inventories	Inventories Inventory is comprised of crude oil held in storage or as line fill in pipelines, pipeline imbalances, and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or net realizable value primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued primarily using a weighted average cost method applied to specific classes of inventory items.
New Accounting Pronouncements	Adoption of new accounting pronouncement On January 1, 2020 the Company adopted Accounting Standards Update ("ASU") 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . See Note 5. Allowance for Credit Losses for discussion of the adoption impact and the applicable disclosures required by the new standard. New accounting pronouncement not yet adopted In December 2019, the Financial Accounting Standards Board ("FASB") issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.

Basis of Presentation and Sig_3

Basis of Presentation and Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2020
Accounting Policies [Abstract]
Components of Inventories	The components of inventory as of March 31, 2020 and December 31, 2019 consisted of the following: In thousands March 31, 2020 December 31, 2019 Tubular goods and equipment $ 15,853 $ 14,880 Crude oil 46,747 94,656 Total $ 62,600 $ 109,536
Calculation of Basic and Diluted Weighted Average Shares and Net Income Per Share	The following table presents the calculation of basic and diluted weighted average shares outstanding and net income (loss) per share attributable to the Company for the three months ended March 31, 2020 and 2019 . Three months ended March 31, In thousands, except per share data 2020 2019 Net income (loss) attributable to Continental Resources (numerator) $ (185,664 ) $ 186,976 Weighted average shares (denominator): Weighted average shares - basic 365,403 372,563 Non-vested restricted stock (1) — 1,911 Weighted average shares - diluted 365,403 374,474 Net income (loss) per share attributable to Continental Resources: Basic $ (0.51 ) $ 0.50 Diluted $ (0.51 ) $ 0.50

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	3 Months Ended
Supplemental Cash Flow Information (Tables)	Mar. 31, 2020
Supplemental Cash Flow Elements [Abstract]
Summary of Supplemental Cash Flow Information	The following table discloses supplemental cash flow information about cash paid for interest and income tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments. Three months ended March 31, In thousands 2020 2019 Supplemental cash flow information: Cash paid for interest $ 51,111 $ 61,964 Cash paid for income taxes 8 9 Cash received for income tax refunds (1) 9,485 4 Non-cash investing activities: Asset retirement obligation additions and revisions, net 2,508 2,570

Revenues (Tables)

Revenues (Tables)	3 Months Ended
Revenues (Tables)	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	The following tables present the disaggregation of the Company's crude oil and natural gas revenues for the three months ended March 31, 2020 and 2019 . Three months ended March 31, 2020 Three months ended March 31, 2019 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 448,930 $ 179,176 $ 628,106 $ 585,605 $ 136,547 $ 722,152 Non-operated properties 132,939 12,725 145,664 178,728 10,238 188,966 Total crude oil revenues 581,869 191,901 773,770 764,333 146,785 911,118 Natural gas revenues: Operated properties 11,588 72,306 83,894 51,461 124,698 176,159 Non-operated properties 1,720 3,359 5,079 10,866 11,441 22,307 Total natural gas revenues 13,308 75,665 88,973 62,327 136,139 198,466 Crude oil and natural gas sales $ 595,177 $ 267,566 $ 862,743 $ 826,660 $ 282,924 $ 1,109,584 Timing of revenue recognition Goods transferred at a point in time $ 595,177 $ 267,566 $ 862,743 $ 826,660 $ 282,924 $ 1,109,584 Goods transferred over time — — — — — — $ 595,177 $ 267,566 $ 862,743 $ 826,660 $ 282,924 $ 1,109,584

Derivative Instruments (Tables)

Derivative Instruments (Tables)	3 Months Ended
Derivative Instruments (Tables)	Mar. 31, 2020
Realized and Unrealized Gains and Losses on Derivative Instruments	Cash receipts in the following table reflect the gain on derivative contracts which matured during the applicable period, calculated as the difference between the contract price and the market settlement price of matured contracts. The Company's 2019 natural gas derivatives were settled based upon reported NYMEX Henry Hub settlement prices. Non-cash losses below represent the change in fair value of derivative instruments which continued to be held at period end, if any, and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period. Three months ended March 31, In thousands 2020 2019 Cash received on derivatives: Natural gas fixed price swaps $ — $ 7,645 Natural gas collars — 5,417 Cash received on derivatives, net — 13,062 Non-cash loss on derivatives: Natural gas fixed price swaps — (8,704 ) Natural gas collars — (5,482 ) Non-cash loss on derivatives, net — (14,186 ) Loss on natural gas derivatives, net $ — $ (1,124 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
Fair Value Measurements (Tables)	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Property Impairments	The following table sets forth the non-cash impairments of both proved and unproved properties for the indicated periods. Proved and unproved property impairments are recorded under the caption “Property impairments” in the unaudited condensed consolidated statements of comprehensive income (loss). Three months ended March 31, In thousands 2020 2019 Proved property impairments $ 205,545 $ — Unproved property impairments 16,984 25,316 Total $ 222,529 $ 25,316
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. March 31, 2020 December 31, 2019 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 735,000 $ 735,000 $ 55,000 $ 55,000 Note payable 4,753 4,800 5,351 5,400 5% Senior Notes due 2022 1,099,234 692,400 1,099,165 1,108,700 4.5% Senior Notes due 2023 1,458,753 812,200 1,491,339 1,571,400 3.8% Senior Notes due 2024 987,644 507,700 994,310 1,034,200 4.375% Senior Notes due 2028 989,928 463,700 989,661 1,063,700 4.9% Senior Notes due 2044 691,732 298,600 691,688 742,000 Total debt $ 5,967,044 $ 3,514,400 $ 5,326,514 $ 5,580,400

Long-Term Debt (Tables)

Long-Term Debt (Tables)	3 Months Ended
Long-Term Debt (Tables)	Mar. 31, 2020
Debt Disclosure [Abstract]
Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations	Notes The following table summarizes the face values, maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at March 31, 2020 . In March 2020 the Company repurchased a portion of its 2023 Notes and 2024 Notes in open market transactions as further discussed below under the heading Repurchase of Senior Notes . 2022 Notes (1) 2023 Notes 2024 Notes 2028 Notes 2044 Notes Face value (in thousands) $1,100,000 $1,466,625 $993,000 $1,000,000 $700,000 Maturity date Sep 15, 2022 April 15, 2023 June 1, 2024 January 15, 2028 June 1, 2044 Interest payment dates March 15, Sep 15 April 15, Oct 15 June 1, Dec 1 Jan 15, July 15 June 1, Dec 1 Make-whole redemption period (2) — Jan 15, 2023 Mar 1, 2024 Oct 15, 2027 Dec 1, 2043 (1) The Company has the option to redeem all or a portion of its remaining 2022 Notes at the decreasing redemption prices specified in the indenture related to the 2022 Notes plus any accrued and unpaid interest to the date of redemption. (2)
Schedule of Long-term Debt Instruments [Table Text Block]	Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $32.4 million and $33.9 million at March 31, 2020 and December 31, 2019 , respectively, consists of the following. In thousands March 31, 2020 December 31, 2019 Credit facility $ 735,000 $ 55,000 Note payable 4,753 5,351 5% Senior Notes due 2022 1,099,234 1,099,165 4.5% Senior Notes due 2023 1,458,753 1,491,339 3.8% Senior Notes due 2024 987,644 994,310 4.375% Senior Notes due 2028 989,928 989,661 4.9% Senior Notes due 2044 691,732 691,688 Total debt $ 5,967,044 $ 5,326,514 Less: Current portion of long-term debt 2,455 2,435 Long-term debt, net of current portion $ 5,964,589 $ 5,324,079

Leases (Tables)

Leases (Tables)	3 Months Ended
Leases (Tables)	Mar. 31, 2020
Leases [Abstract]
Operating lease liabilities [Table Text Block]	The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $12.6 million as of March 31, 2020 at discounted present value, which is comprised of the asset classes reflected in the table below. All leases recognized on the Company's balance sheet are classified as operating leases. The amounts disclosed herein primarily represent costs associated with properties operated by the Company that are presented on a gross basis and do not reflect the Company's net proportionate share of such amounts. A portion of these costs have been or will be billed to other working interest owners. Once paid, the Company's share of these costs are included in property and equipment, production expenses, or general and administrative expenses, as applicable. The Company's leasing activities as a lessor are negligible. In thousands Amount Drilling rig commitments $ 6,048 Surface use agreements 5,091 Field equipment 1,105 Other 339 Total $ 12,583
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Minimum future commitments by year for the Company's operating leases as of March 31, 2020 are presented in the table below. Such commitments are reflected at undiscounted values and are reconciled to the discounted present value recognized on the balance sheet. In thousands Amount Remainder of 2020 $ 4,954 2021 2,574 2022 782 2023 729 2024 456 Thereafter 6,676 Total operating lease liabilities, at undiscounted value $ 16,171 Less: Imputed interest (3,588 ) Total operating lease liabilities, at discounted present value $ 12,583 Less: Current portion of operating lease liabilities (6,243 ) Operating lease liabilities, net of current portion $ 6,340
Lease, Cost [Table Text Block]	Additional information for the Company's operating leases is presented below. Lease costs are reflected at gross amounts and primarily represent costs incurred for drilling rigs, most of which are short term contracts that are not recognized as right-of-use assets and lease liabilities on the balance sheet. Variable lease costs primarily represent differences between minimum payment obligations and actual operating day-rate charges incurred by the Company for its long term drilling rig contracts. Short-term lease costs primarily represent operating day-rate charges for drilling rig contracts with durations of one year or less and month-to-month field equipment rentals. In thousands, except weighted average data Three months ended March 31, 2020 Lease costs: Operating lease costs $ 1,260 Variable lease costs 3,223 Short-term lease costs 51,348 Total lease costs $ 55,831 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 7,002 Operating cash flows from operating leases included in lease liabilities 228 Weighted average remaining lease term as of March 31, 2020 (in years) 9.8 Weighted average discount rate as of March 31, 2020 4.1 %

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	3 Months Ended
Stock-Based Compensation (Tables)	Mar. 31, 2020
Restricted stock [Member]
Summary of Changes in Non-vested Shares of Restricted Stock Outstanding	A summary of changes in non-vested restricted shares outstanding for the three months ended March 31, 2020 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2019 3,461,908 $ 46.82 Granted 2,454,235 28.41 Vested (925,568 ) 46.19 Forfeited (42,818 ) 39.88 Non-vested restricted shares outstanding at March 31, 2020 4,947,757 $ 37.87

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
Income Taxes (Tables)	Mar. 31, 2020
Effective Tax Rate Reconciliation Table [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	The Company's provision (benefit) for income taxes and resulting effective tax rates were as follows for the periods presented. Three months ended March 31, 2020 2019 Provision (benefit) for income taxes (in thousands) $ (52,235 ) $ 51,990 Effective tax rate 21.9 % 21.8 %
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The Company's effective tax rate differs from the United States federal statutory tax rate due to the effect of state income taxes, equity compensation, valuation allowances, and other tax items as reflected in the table below. Three months ended March 31, In thousands, except tax rates 2020 2019 Income (loss) before income taxes $ (239,019 ) $ 238,483 U.S. federal statutory tax rate 21.0 % 21.0 % Expected income tax provision (benefit) based on U.S. federal statutory tax rate (50,194 ) 50,081 Items impacting the effective tax rate: State and local income taxes, net of federal benefit (7,603 ) 7,798 Equity compensation 3,886 (8,318 ) Other, net (3,189 ) 2,429 Valuation allowance 4,865 — Provision (benefit) for income taxes $ (52,235 ) $ 51,990 Effective tax rate 21.9 % 21.8 % The Company reduces its deferred tax assets by a valuation allowance if, based upon the weight of available evidence, it is more-likely-than-not that the Company will not realize some portion or all of the deferred tax assets. The Company considers relevant evidence, both positive and negative, to determine the need for a valuation allowance. Information evaluated includes the Company's financial position and results of operations for the current and preceding years, the availability of deferred tax liabilities and tax carrybacks, as well as an evaluation of currently available information about future years. The Company determined it was more-likely-than-not that a portion of its Oklahoma NOL carryforwards would not be able to be utilized before expiration, and a valuation allowance of approximately $4.9 million was established for the deferred tax assets associated with such NOL carryforwards. The Company will continue to evaluate both the positive and negative evidence on a quarterly basis in determining the need for a valuation allowance with respect to its deferred tax assets. Changes in positive and negative evidence, including differences between estimated and actual results, could result in changes in the valuation of our deferred tax assets that could have a material impact on our consolidated financial statements. Changes in existing tax laws could also affect actual tax results and the realization of deferred tax assets over time.

Organization and Nature of Bu_2

Organization and Nature of Business - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2020
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of crude oil and natural gas production concentrated in crude oil	56.00%
Percentage of crude oil and natural gas revenue concentrated in crude oil	90.00%
North Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	58.00%
Percentage of revenues concentrated in geographic areas	69.00%
South Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	42.00%
Percentage of revenues concentrated in geographic areas	31.00%

Basis of Presentation and Sig_4

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Tubular goods and equipment	$ 15,853	$ 14,880
Crude oil	46,747	94,656
Total	$ 62,600	$ 109,536

Basis of Presentation and Sig_5

Basis of Presentation and Significant Accounting Policies - Earnings Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Accounting Policies [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment	594,000
Net income (loss) attributable to Continental Resources (numerator)
Net income (loss) attributable to Continental Resources (numerator)	$ (185,664)	$ 186,976
Weighted average shares - basic	365,403,000	372,563,000
Non-vested restricted stock (1)	0	1,911,000
Weighted average shares - diluted	365,403,000	374,474,000
Net income (loss) per share attributable to Continental Resources:
Basic (in dollars per share)	$ (0.51)	$ 0.50
Diluted (in dollars per share)	$ (0.51)	$ 0.50

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	$ 51,111	$ 61,964
Cash paid for income taxes	8	9
Cash received for income tax refunds (1)	9,485	4
Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	232,200	262,700
Increase (Decrease) in Asset Retirement Obligations	2,508	2,570
Accrued contributions from noncontrolling interests	1,300	5,600
Accrued distributions to noncontrolling interests	$ 1,900	$ 1,500

Revenues Disaggregation of Reve

Revenues Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 862,743	$ 1,109,584
Transportation expenses	60,502	49,139
Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	862,743	1,109,584
Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0
North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	595,177	826,660
North Region [Member] \| Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	595,177	826,660
North Region [Member] \| Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0
South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	267,566	282,924
South Region [Member] \| Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	267,566	282,924
South Region [Member] \| Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0
Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	773,770	911,118
Transportation expenses	50,400	41,600
Crude oil sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	581,869	764,333
Crude oil sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	191,901	146,785
Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	88,973	198,466
Transportation expenses	10,100	7,500
Natural gas sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	13,308	62,327
Natural gas sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	75,665	136,139
Operated properties \| Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	628,106	722,152
Operated properties \| Crude oil sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	448,930	585,605
Operated properties \| Crude oil sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	179,176	136,547
Operated properties \| Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	83,894	176,159
Operated properties \| Natural gas sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	11,588	51,461
Operated properties \| Natural gas sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	72,306	124,698
Non-operated properties \| Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	145,664	188,966
Non-operated properties \| Crude oil sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	132,939	178,728
Non-operated properties \| Crude oil sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	12,725	10,238
Non-operated properties \| Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	5,079	22,307
Non-operated properties \| Natural gas sales \| North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	1,720	10,866
Non-operated properties \| Natural gas sales \| South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 3,359	$ 11,441

Derivative Instruments - Realiz

Derivative Instruments - Realized and Unrealized Gains and Losses on Derivative Instruments (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	$ 0	$ (14,186)
Loss on natural gas derivatives, net	0	(1,124)
Swap [Member] \| Natural Gas [Member]
Cash received on derivatives:
Cash received (paid) on derivatives, net	0	7,645
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	(8,704)
Collars \| Natural Gas [Member]
Cash received on derivatives:
Cash received (paid) on derivatives, net	0	5,417
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	(5,482)
Crude Oil and Natural Gas [Member]
Cash received on derivatives:
Cash received (paid) on derivatives, net	0	13,062
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	(14,186)
Loss on natural gas derivatives, net	$ 0	$ (1,124)

Allowance for Credit Losses (De

Allowance for Credit Losses (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 2.7		$ 2.4
Cumulative Effect of New Accounting Principle in Period of Adoption	0.1
Accounts Receivable, Credit Loss Expense (Reversal)	0.7	$ 0.1
Allowance for credit losses on crude oil and natural gas sales [Member]
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	0.1
Allowance for credit losses on joint interest receivables [Member]
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 2.7		$ 2.4

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail)	3 Months Ended
Fair Value Measurements - Additional Information (Detail)	Mar. 31, 2020
Fair Value Measurements [Line Items]
Discount factor utilized as standardized measure for future net cash flows	10.00%
Forward Commodity Prices [Member]
Fair Value Measurements [Line Items]
Forward commodity price escalation assumption used in impairment assessment	3.00%

Fair Value Measurements - Prope

Fair Value Measurements - Property Impairments (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	$ 205,545	$ 0
Unproved property impairments	16,984	25,316
Property impairments	222,529	$ 25,316
Proved Oil And Gas Property Fair Value After Impairment	145,600
Red River Units [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	166,500
Non-core [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	14,500
Property, Plant and Equipment [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	181,000
Inventory Valuation and Obsolescence [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Inventory Write-down	$ 24,500

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values of Financial Instruments not Recorded at Fair Value (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	5.00%
Debt Instrument, Maturity Date, Description	2022
4.5% Senior Notes due 2023
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.50%
Debt Instrument, Maturity Date, Description	2023
3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	3.80%
Debt Instrument, Maturity Date, Description	2024
4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.375%
Debt Instrument, Maturity Date, Description	2028
4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.90%
Debt Instrument, Maturity Date, Description	2044
Carrying Amount
Fair Value Measurements [Line Items]
Credit facility	$ 735,000	$ 55,000
Note payable	4,753	5,351
Total debt	5,967,044	5,326,514
Carrying Amount \| 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,099,234	1,099,165
Carrying Amount \| 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,458,753	1,491,339
Carrying Amount \| 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	987,644	994,310
Carrying Amount \| 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	989,928	989,661
Carrying Amount \| 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	691,732	691,688
Estimated Fair Value
Fair Value Measurements [Line Items]
Credit facility	735,000	55,000
Note payable	4,800	5,400
Total debt	3,514,400	5,580,400
Estimated Fair Value \| 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	692,400	1,108,700
Estimated Fair Value \| 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	812,200	1,571,400
Estimated Fair Value \| 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	507,700	1,034,200
Estimated Fair Value \| 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	463,700	1,063,700
Estimated Fair Value \| 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	$ 298,600	$ 742,000

Long-Term Debt - Long-Term Debt

Long-Term Debt - Long-Term Debt (Detail) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Less: Current portion of long-term debt	$ (2,455)	$ (2,435)
Long-term debt, net of current portion	$ 5,964,589	5,324,079
5% Senior Notes due 2022
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.00%
Note payable
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.14%
Note payable	$ 22,000
3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.80%
4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.375%
4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%
Carrying Amount
Debt Instrument [Line Items]
Credit facility	$ 735,000	55,000
Note payable	4,753	5,351
Total debt	5,967,044	5,326,514
Carrying Amount \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,234	1,099,165
Carrying Amount \| 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,458,753	1,491,339
Carrying Amount \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	987,644	994,310
Carrying Amount \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	989,928	989,661
Carrying Amount \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	691,732	691,688
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	735,000	55,000
Note payable	4,800	5,400
Total debt	3,514,400	5,580,400
Estimated Fair Value \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	692,400	1,108,700
Estimated Fair Value \| 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	812,200	1,571,400
Estimated Fair Value \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	507,700	1,034,200
Estimated Fair Value \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	463,700	1,063,700
Estimated Fair Value \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 298,600	$ 742,000

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	$ 32,400		$ 33,900
Revolver draw	500,000
Cash and cash equivalents	$ 517,600
Line of credit facility, maturity date	Apr. 9, 2023
Aggregate amount of lender commitments on credit facility	$ 1,500,000
Line of credit facility, commitment fee percentage, per annum	0.25%
Current portion of long-term debt	$ 2,455		2,435
Line of Credit Facility, Covenant Terms	0.65
Gain on extinguishment of debt	$ (17,631)	$ 0
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	2.60%
Line of Credit Facility, Remaining Borrowing Capacity	$ 762,000
Senior Notes Due Two Thousand And Twenty Three [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	33,400
Debt Instrument, Repurchase Amount	$ 19,500
Debt Instrument, Maturity Date	Apr. 15, 2023
2022 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Sep. 15, 2022
4.5% Senior Notes due 2023
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.50%
Debt Instrument, Maturity Date, Description	2023
Note payable
Debt Instrument [Line Items]
Notes Payable	$ 22,000
Loan term	10 years
Debt Instrument, stated interest rate	3.14%
Debt Instrument, Maturity Date	Feb. 26, 2022
5% Senior Notes due 2022
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.00%
Debt Instrument, Maturity Date, Description	2022
3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	$ 7,000
Debt Instrument, Repurchase Amount	$ 3,800
Debt Instrument, stated interest rate	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%
Debt Instrument, Maturity Date, Description	2028
4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%
Debt Instrument, Maturity Date, Description	2044
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	$ 735,000		55,000
Notes Payable	4,800		5,400
Estimated Fair Value \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	692,400		1,108,700
Estimated Fair Value \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	507,700		1,034,200
Estimated Fair Value \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	463,700		1,063,700
Estimated Fair Value \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	298,600		742,000
Carrying Amount
Debt Instrument [Line Items]
Credit facility	735,000		55,000
Notes Payable	4,753		5,351
Carrying Amount \| 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,234		1,099,165
Carrying Amount \| 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	987,644		994,310
Carrying Amount \| 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	989,928		989,661
Carrying Amount \| 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 691,732		$ 691,688

Long-Term Debt Long-Term Debt -

Long-Term Debt Long-Term Debt - Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2020USD ($)
2022 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,100,000
Maturity date	Sep. 15, 2022
Interest payment dates	March 15, Sep 15
2023 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,466,625
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	$ 993,000
Maturity date	Jun. 1, 2024
Interest payment dates	June 1, Dec 1
Debt Instrument, Redemption Period, Start Date	Mar. 1, 2024
2028 Notes
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,000,000
Maturity date	Jan. 15, 2028
Interest payment dates	Jan 15, July 15
Debt Instrument, Redemption Period, Start Date	Oct. 15, 2027
2044 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 700,000
Maturity date	Jun. 1, 2044
Interest payment dates	June 1, Dec 1
Debt Instrument, Redemption Period, Start Date	Dec. 1, 2043

Leases (Details)

Leases (Details) $ in Thousands	3 Months Ended
Leases (Details) $ in Thousands	Mar. 31, 2020USD ($)
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 12,583
Operating lease costs	1,260
Variable Lease, Cost	3,223
Short-term Lease, Cost	51,348
Lease, Cost	55,831
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	7,002
Operating cash flows from operating leases	$ 228
Operating Lease, Weighted Average Remaining Lease Term	9 years 9 months 18 days
Weighted average discount rate	4.10%
Drilling rig commitments [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 6,048
Surface use agreements [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	5,091
Field equipment [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	1,105
Other [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 339

Leases Leases and lease commitm

Leases Leases and lease commitments, Maturities of operating leases (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease payments remainder of fiscal year	$ 4,954
Operating lease payments, due year two	2,574
Operating lease payments, due year three	782
Operating lease payments, due year four	729
Operating lease payments, due year five	456
Operating lease payments, remaining due thereafter	6,676
Operating lease payments due	16,171
Imputed interest	(3,588)
Operating Lease, Liability	12,583
Current portion of operating leases	(6,243)	$ (3,695)
Operating lease liabilities, net of current portion	$ 6,340	$ 5,433

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies - Additional Information (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2020USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation Agreement Expiration Date	2031
Future Drilling Commitments At Balance Sheet Date	$ 36,000
Drilling Commitments Year One	33,000
Drilling Commitments Year Two	3,000
Operating Lease, Liability	12,583
Purchase Obligation	2,110,000
Purchase Obligation, Future Minimum Payments, Remainder of Fiscal Year	210,000
Purchase Obligation, Due in Second Year	326,000
Purchase Obligation, Due in Third Year	329,000
Purchase Obligation, Due in Fourth Year	331,000
Purchase Obligation, Due in Fifth Year	298,000
Purchase Obligation, Due after Fifth Year	$ 615,000
Future Drilling Commitments End Date	2021-04
Drilling rig commitments [Member]
Long-term Purchase Commitment [Line Items]
Operating Lease, Liability	$ 6,048

Commitments and Contingencies L

Commitments and Contingencies Loss Contingencies (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
Legal proceedings recorded as a liability under other noncurrent liabilities	$ 7.5	$ 8.7

Stock Based Compensation - Stoc

Stock Based Compensation - Stock Based Compensation Expenses (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Share-based Payment Arrangement [Abstract]
Non-cash equity compensation	$ 16.4	$ 12.1

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2020USD ($)shares
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock available to grant \| shares	10,871,733
Fair value at vesting date \| $	$ 24
Unrecognized compensation expense related to non-vested \| $	$ 117
Unrecognized compensation expense related to non-vested, period for recognition, in years	1 year 10 months 24 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)	3 Months Ended
	Mar. 31, 2020$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested shares, beginning balance \| shares	3,461,908
Granted (unaudited), shares \| shares	2,454,235
Vested shares \| shares	(925,568)
Forfeited (unaudited), shares \| shares	(42,818)
Non-vested shares, ending balance \| shares	4,947,757
Non-vested, weighted average grant-date fair value, beginning of period \| $ / shares	$ 46.82
Granted, weighted average grant-date fair value \| $ / shares	28.41
Vested, weighted average grant-date fair value \| $ / shares	46.19
Forfeited, weighted average grant-date fair value \| $ / shares	39.88
Non-vested, weighted average grant-date fair value, end of period \| $ / shares	$ 37.87

Shareholders' Equity Share Repu

Shareholders' Equity Share Repurchase (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020	May 31, 2019
Shareholders' Equity [Abstract]
Stock Repurchase Program, Authorized Amount		$ 1,000
Stock Repurchased and Retired During Period, Shares	8.1
Stock Repurchased and Retired During Period, Value	$ 126.9
Cumulative shares repurchased under share repurchase program	13.8
Cumulative treasury stock, retired, cost method, amount	$ 317.1

Shareholders' Equity Dividend (

Shareholders' Equity Dividend (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2020	Feb. 21, 2020
Dividend [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.05
Dividends payable		$ 18.4

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended
Income Taxes (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Mar. 31, 2019
Income Taxes [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%	21.00%
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	$ (50,194)	$ 50,081
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	(7,603)	7,798
Income Tax Reconciliation Equity Compensation	3,886	(8,318)
Effective Income Tax Rate Reconciliation, Other Adjustments, Amount	(3,189)	2,429
Income Tax Expense	$ (52,235)	$ 51,990
Effective Income Tax Rate Reconciliation, Percent	21.90%	21.80%
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	$ 4,900

Income Taxes Provision for inco

Income Taxes Provision for income taxes (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Income Tax Expense	$ (52,235)	$ 51,990
Effective Income Tax Rate Reconciliation, Percent	21.90%	21.80%

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
Subsequent Events (Details) - USD ($) $ in Thousands	Apr. 30, 2020	Mar. 31, 2020	Mar. 31, 2019	May 01, 2020	Apr. 15, 2020
Subsequent Event [Line Items]
Gain on extinguishment of debt		$ 17,631	$ 0
Subsequent Event [Member]
Subsequent Event [Line Items]
Subsequent event pending litigation					$ 200,000
Gain on extinguishment of debt	$ 47,000
Senior Notes Due Two Thousand And Twenty Three [Member]
Subsequent Event [Line Items]
Debt Instrument, Repurchased Face Amount		33,400
Debt Instrument, Repurchase Amount		19,500
Senior Notes Due Two Thousand And Twenty Three [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Debt Instrument, Repurchased Face Amount				$ 17,000
Debt Instrument, Repurchase Amount				9,800
3.8% Senior Notes due 2024
Subsequent Event [Line Items]
Debt Instrument, Repurchased Face Amount		7,000
Debt Instrument, Repurchase Amount		$ 3,800
3.8% Senior Notes due 2024 \| Subsequent Event [Member]
Subsequent Event [Line Items]
Debt Instrument, Repurchased Face Amount				82,000
Debt Instrument, Repurchase Amount				$ 43,100