Continental Resources Inc (CLR) 10-Q 30 Oct 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information Document - shares	9 Months Ended
	Sep. 30, 2019	Oct. 18, 2019
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
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	2019
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-0767549
Entity Address, Address Line One	20 N. Broadway,
Entity Address, City or Town	Oklahoma City,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73102
City Area Code	405
Local Phone Number	234-9000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		371,420,567
NEW YORK STOCK EXCHANGE, INC. [Member]
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $0.01 par value
Trading Symbol	CLR
Security Exchange Name	NYSE

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 35,260	$ 282,749
Receivables:
Crude oil and natural gas sales	706,946	644,107
Affiliated parties	88	73
Joint interest and other, net	338,879	368,235
Derivative assets	16,930	15,612
Inventories	110,323	88,544
Prepaid expenses and other	17,258	13,041
Total current assets	1,225,684	1,412,361
Net property and equipment, based on successful efforts method of accounting	14,520,573	13,869,800
Operating lease right-of-use assets	10,219	0
Other noncurrent assets	14,879	15,786
Total assets	15,771,355	15,297,947
Current liabilities:
Accounts payable trade	694,966	717,560
Revenues and royalties payable	400,230	400,567
Payables to affiliated parties	121	203
Accrued liabilities and other	250,192	266,819
Dividends payable	18,587	0
Derivative liabilities	15	0
Current portion of operating leases	5,242	0
Current portion of long-term debt	2,416	2,360
Total current liabilities	1,371,769	1,387,509
Long-term debt, net of current portion	5,568,413	5,765,989
Other noncurrent liabilities:
Deferred income tax liabilities, net	1,751,822	1,574,436
Asset retirement obligations, net of current portion	148,626	136,986
Operating lease liabilities, net of current portion	4,977	0
Other noncurrent liabilities	11,568	11,166
Total other noncurrent liabilities	1,916,993	1,722,588
Commitments and contingencies (Note 9)
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; 371,730,488 shares issued and outstanding at September 30, 2019; 376,021,575 shares issued and outstanding at December 31, 2018	3,717	3,760
Additional paid-in capital	1,278,482	1,434,823
Accumulated other comprehensive income	543	415
Retained earnings	5,269,243	4,706,135
Total shareholders’ equity attributable to Continental Resources	6,551,985	6,145,133
Noncontrolling interests	362,195	276,728
Total Equity	6,914,180	6,421,861
Total liabilities and equity	$ 15,771,355	$ 15,297,947

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2019	Dec. 31, 2018
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	371,730,488	376,021,575
Common Stock, Shares, Outstanding	371,730,488	376,021,575

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues:
Crude oil and natural gas sales	$ 1,081,400	$ 1,273,238	$ 3,328,409	$ 3,524,618
Gain (loss) on natural gas derivatives, net	1,195	(2,025)	53,519	(4,536)
Crude oil and natural gas service operations	21,602	10,938	54,886	40,210
Total revenues	1,104,197	1,282,151	3,436,814	3,560,292
Operating costs and expenses:
Production expenses	114,050	103,032	333,446	286,165
Production taxes	86,931	98,572	267,237	262,747
Transportation expenses	62,038	46,008	164,569	142,559
Exploration expenses	2,472	2,324	7,399	4,347
Crude oil and natural gas service operations	8,224	5,163	26,616	17,434
Depreciation, depletion, amortization and accretion	484,031	469,333	1,464,672	1,370,912
Property impairments	20,199	23,770	66,854	86,715
General and administrative expenses	46,993	44,151	141,837	134,368
Net (gain) loss on sale of assets and other	535	(1,510)	647	(8,261)
Total operating costs and expenses	825,473	790,843	2,473,277	2,296,986
Income from operations	278,724	491,308	963,537	1,263,306
Other income (expense):
Interest expense	(68,090)	(73,409)	(204,398)	(223,590)
Loss on extinguishment of debt	(4,584)	(7,133)	(4,584)	(7,133)
Other	1,119	869	3,196	2,231
Total other income (expense)	(71,555)	(79,673)	(205,786)	(228,492)
Income before income taxes	207,169	411,635	757,751	1,034,814
Provision for income taxes	(49,747)	(97,466)	(177,386)	(244,234)
Net income	157,422	314,169	580,365	790,580
Net loss attributable to noncontrolling interests	(740)	0	(1,330)	0
Net income attributable to Continental Resources	$ 158,162	$ 314,169	$ 581,695	$ 790,580
Basic net income per share (in dollars per share)	$ 0.43	$ 0.84	$ 1.56	$ 2.13
Diluted net income per share (in dollars per share)	$ 0.43	$ 0.84	$ 1.56	$ 2.11
Foreign currency translation adjustments	$ (18)	$ 105	$ 128	$ 123
Total other comprehensive income, net of tax	(18)	105	128	123
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	157,404	314,274	580,493	790,703
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(740)	0	(1,330)	0
Comprehensive income	$ 158,144	$ 314,274	$ 581,823	$ 790,703

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								$ 0
Total Equity	$ 5,131,203
Balance at Dec. 31, 2017		$ 3,752	$ 1,409,326		$ 307	$ 3,717,818	$ 5,131,203
Balance, shares at Dec. 31, 2017		375,219,769
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Continental Resources						233,946	233,946
Net income	233,946
Other comprehensive income, net of tax (unaudited)	2				2		2
Stock-based compensation (unaudited)	10,905		10,905				10,905
Restricted stock:
Granted (unaudited)	12	$ 12					12
Granted (unaudited), shares		1,180,032
Repurchased and canceled (unaudited)	(14,846)	$ (3)	(14,843)				(14,846)
Repurchased and canceled (unaudited), shares		(276,108)
Forfeited (unaudited), shares		(66,489)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Mar. 31, 2018		$ 3,760	1,405,388		309	3,951,764	5,361,221
Balance, shares at Mar. 31, 2018		376,057,204
Balance at Dec. 31, 2017		$ 3,752	1,409,326		307	3,717,818	5,131,203
Balance, shares at Dec. 31, 2017		375,219,769
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Continental Resources	790,580
Net loss attributable to noncontrolling interests	0
Net income	790,580
Other comprehensive income, net of tax (unaudited)	123
Balance at Sep. 30, 2018		$ 3,760	1,426,222		430	4,508,398	5,938,810
Balance, shares at Sep. 30, 2018		375,995,294
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								0
Total Equity	5,361,221
Balance at Mar. 31, 2018		$ 3,760	1,405,388		309	3,951,764	5,361,221
Balance, shares at Mar. 31, 2018		376,057,204
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Continental Resources						242,465	242,465
Net income	242,465
Other comprehensive income, net of tax (unaudited)	16				16		16
Stock-based compensation (unaudited)	10,560		10,560				10,560
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		97,459
Repurchased and canceled (unaudited)	(773)	$ 0	(773)				(773)
Repurchased and canceled (unaudited), shares		(11,398)
Forfeited (unaudited), shares		(112,468)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Jun. 30, 2018		$ 3,760	1,415,175		325	4,194,229	5,613,489
Balance, shares at Jun. 30, 2018		376,030,797
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								0
Total Equity	5,613,489
Net income attributable to Continental Resources	314,169					314,169	314,169
Net loss attributable to noncontrolling interests	0
Net income	314,169
Other comprehensive income, net of tax (unaudited)	105				105		105
Stock-based compensation (unaudited)	11,731		11,731				11,731
Restricted stock:
Granted (unaudited)	0	$ 0					0
Granted (unaudited), shares		55,214
Repurchased and canceled (unaudited)	(684)	$ 0	(684)				(684)
Repurchased and canceled (unaudited), shares		(11,142)
Forfeited (unaudited), shares		(79,575)
Forfeitures (unaudited)	0	$ 0					0
Balance at Sep. 30, 2018		$ 3,760	1,426,222		430	4,508,398	5,938,810
Balance, shares at Sep. 30, 2018		375,995,294
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								0
Total Equity	5,938,810
Noncontrolling interests	276,728							276,728
Total Equity	6,421,861
Balance at Dec. 31, 2018	$ 6,145,133	$ 3,760	1,434,823		415	4,706,135	6,145,133
Balance, shares at Dec. 31, 2018	376,021,575	376,021,575
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Continental Resources						186,976	186,976
Net loss attributable to noncontrolling interests								(483)
Net income	$ 186,493
Other comprehensive income, net of tax (unaudited)	116				116		116
Contributions from Noncontrolling Interests	42,204							42,204
Distributions to Noncontrolling Interests	(3,856)							(3,856)
Stock-based compensation (unaudited)	12,095		12,095				12,095
Restricted stock:
Granted (unaudited)	13	$ 13					13
Granted (unaudited), shares		1,333,602
Repurchased and canceled (unaudited)	(20,622)	$ (4)	(20,618)				(20,622)
Repurchased and canceled (unaudited), shares		(439,419)
Forfeited (unaudited), shares		(147,074)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Mar. 31, 2019		$ 3,768	1,426,300		531	4,893,111	6,323,710
Balance, shares at Mar. 31, 2019		376,768,684
Balance at Dec. 31, 2018	$ 6,145,133	$ 3,760	1,434,823		415	4,706,135	6,145,133
Balance, shares at Dec. 31, 2018	376,021,575	376,021,575
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Continental Resources	$ 581,695
Net loss attributable to noncontrolling interests	(1,330)
Net income	580,365
Other comprehensive income, net of tax (unaudited)	$ 128
Restricted stock:
Granted (unaudited), shares	1,496,186
Repurchased and canceled (unaudited)	$ (172,000)
Repurchased and canceled (unaudited), shares	(5,006,553)
Forfeited (unaudited), shares	(314,613)
Balance at Sep. 30, 2019	$ 6,551,985	$ 3,717	1,278,482		543	5,269,243	6,551,985
Balance, shares at Sep. 30, 2019	371,730,488	371,730,488
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								314,593
Total Equity	$ 6,638,303
Balance at Mar. 31, 2019		$ 3,768	1,426,300		531	4,893,111	6,323,710
Balance, shares at Mar. 31, 2019		376,768,684
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Continental Resources						236,557	236,557
Net loss attributable to noncontrolling interests								(107)
Net income	236,450
Dividends, Common Stock, Cash	(18,747)					(18,747)	(18,747)
Treasury Stock, Value, Acquired, Cost Method	(69,661)			$ (69,661)			(69,661)
Treasury Stock, Shares, Retired		(1,800,000)
Treasury Stock, Retired, Cost Method, Amount		$ (18)	(69,643)	(69,661)
Other comprehensive income, net of tax (unaudited)	30				30		30
Contributions from Noncontrolling Interests	35,118							35,118
Distributions to Noncontrolling Interests	(3,272)							(3,272)
Stock-based compensation (unaudited)	12,176		12,176				12,176
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		59,639
Repurchased and canceled (unaudited)	(562)	$ (1)	(561)				(562)
Repurchased and canceled (unaudited), shares		(13,335)
Forfeited (unaudited), shares		(71,440)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Jun. 30, 2019		$ 3,749	1,368,272		561	5,110,921	6,483,503
Balance, shares at Jun. 30, 2019		374,943,548
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests								346,332
Total Equity	6,829,835
Net income attributable to Continental Resources	158,162					158,162	158,162
Net loss attributable to noncontrolling interests	(740)							(740)
Net income	157,422
Change in dividends payable	160					160	160
Treasury Stock, Value, Acquired, Cost Method	(102,304)			(102,304)			(102,304)
Treasury Stock, Shares, Retired		(3,206,553)
Treasury Stock, Retired, Cost Method, Amount		$ (32)	(102,272)	$ (102,304)
Other comprehensive income, net of tax (unaudited)	(18)				(18)		(18)
Contributions from Noncontrolling Interests	19,713							19,713
Distributions to Noncontrolling Interests	(3,110)							(3,110)
Stock-based compensation (unaudited)	12,871		12,871				12,871
Restricted stock:
Granted (unaudited)	1	$ 1					1
Granted (unaudited), shares		102,945
Repurchased and canceled (unaudited)	(389)	$ 0	(389)				(389)
Repurchased and canceled (unaudited), shares		(13,353)
Forfeited (unaudited), shares		(96,099)
Forfeitures (unaudited)	(1)	$ (1)					(1)
Balance at Sep. 30, 2019	$ 6,551,985	$ 3,717	$ 1,278,482		$ 543	$ 5,269,243	$ 6,551,985
Balance, shares at Sep. 30, 2019	371,730,488	371,730,488
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interests	$ 362,195							$ 362,195
Total Equity	$ 6,914,180

Unaudited Condensed Consolida_2

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Statement of Cash Flows [Abstract]
Net income	$ 580,365	$ 790,580
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, Depletion, Amortization and Accretion	1,465,856	1,370,676
Property impairments	66,854	86,715
Non-cash (gain) loss on derivatives, net	(1,303)	12,013
Stock-based compensation	37,153	33,209
Provision for deferred income taxes	177,386	252,012
(Gain) loss on sale of assets, net	647	(8,261)
Loss on extinguishment of debt	4,584	7,133
Other, net	8,036	11,069
Changes in assets and liabilities:
Accounts receivable	(42,269)	(139,219)
Inventories	(21,867)	(7,852)
Other current assets	(3,808)	(4,766)
Accounts payable trade	56,624	32,708
Revenues and royalties payable	(309)	86,814
Accrued liabilities and other	(15,707)	(19,677)
Other noncurrent assets and liabilities	(366)	(2,413)
Net cash provided by operating activities	2,311,876	2,500,741
Cash flows from investing activities
Exploration and development	(2,268,594)	(2,093,010)
Purchase of producing crude oil and natural gas properties	(49,324)	(25,476)
Purchase of other property and equipment	(22,875)	(15,724)
Proceeds from sale of assets	86,866	30,727
Net cash used in investing activities	(2,253,927)	(2,103,483)
Cash flows from financing activities
Credit facility borrowings	776,000	1,706,000
Repayment of credit facility	(476,000)	(1,704,000)
Redemption of Senior Notes	500,000	400,000
Premium and costs on redemption of Senior Notes	(4,167)	(6,700)
Repayment of other debt	(1,754)	(1,707)
Debt issuance costs	0	(5,543)
Contributions from noncontrolling interests	104,494	0
Distributions to noncontrolling interests	(10,493)	0
Payments for Repurchase of Common Stock	(171,965)	0
Repurchase of restricted stock for tax withholdings	(21,573)	(16,303)
Net cash used in financing activities	(305,458)	(428,253)
Effect of Exchange Rate on Cash and Cash Equivalents	20	(11)
Net change in cash and cash equivalents	(247,489)	(31,006)
Cash and cash equivalents at beginning of period	282,749	43,902
Cash and cash equivalents at end of period	$ 35,260	$ 12,896

Organization and Nature of Busi

Organization and Nature of Business	9 Months Ended
	Sep. 30, 2019
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. A majority of the Company’s operations are located in the North region, with that region comprising 61% of the Company’s crude oil and natural gas production and 74% of its crude oil and natural gas revenues for the nine months ended September 30, 2019 . 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 continue to expand with its increased activity in the SCOOP and STACK plays and that region comprised 39% of the Company's crude oil and natural gas production and 26% of its crude oil and natural gas revenues for the nine months ended September 30, 2019 . For the nine months ended September 30, 2019 , crude oil accounted for 59% of the Company’s total production and 87%

Basis of Presentation and Signi

Basis of Presentation and Significant Accounting Policies	9 Months Ended
	Sep. 30, 2019
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 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, 2018 (“ 2018 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures. The condensed consolidated financial statements as of September 30, 2019 and for the three and nine month periods ended September 30, 2019 and 2018 are unaudited. The condensed consolidated balance sheet as of December 31, 2018 was derived from the audited balance sheet included in the 2018 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 per share is computed by dividing net income 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 per share attributable to the Company for the three and nine months ended September 30, 2019 and 2018 . Three months ended September 30, Nine months ended September 30, In thousands, except per share data 2019 2018 2019 2018 Net income attributable to Continental Resources (numerator) $ 158,162 $ 314,169 $ 581,695 $ 790,580 Weighted average shares (denominator): Weighted average shares - basic 369,739 371,960 371,702 371,810 Non-vested restricted stock 937 2,663 1,804 2,952 Weighted average shares - diluted 370,676 374,623 373,506 374,762 Net income per share attributable to Continental Resources: Basic $ 0.43 $ 0.84 $ 1.56 $ 2.13 Diluted $ 0.43 $ 0.84 $ 1.56 $ 2.11 Inventories Inventory is comprised of crude oil held in storage or as line fill in pipelines, pipeline imbalances, and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or net realizable value primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued primarily using a weighted average cost method applied to specific classes of inventory items. The components of inventory as of September 30, 2019 and December 31, 2018 consisted of the following: In thousands September 30, 2019 December 31, 2018 Tubular goods and equipment $ 15,360 $ 14,623 Crude oil 94,963 73,921 Total $ 110,323 $ 88,544 Adoption of new accounting pronouncement On January 1, 2019 the Company adopted Accounting Standards Update ("ASU") 2016-02, Leases (Topic 842) . See Note 8. Leases for discussion of the adoption impact and the applicable disclosures required by the new guidance. New accounting pronouncement not yet adopted In June 2016 the Financial Accounting Standards Board ("FASB") issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . This standard changes how entities will measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The standard will replace the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost. The standard is effective for interim and annual periods beginning after December 15, 2019 and shall be applied using a modified retrospective approach resulting in a cumulative effect adjustment to retained earnings upon adoption. The Company continues to evaluate the new standard and is unable to estimate its financial statement impact at this time; however, the impact is not expected to be material. Historically, the Company's credit losses on crude oil and natural gas sales receivables and joint interest receivables have been immaterial.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information The following table discloses supplemental cash flow information about cash paid for interest and income tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments. Nine months ended September 30, In thousands 2019 2018 Supplemental cash flow information: Cash paid for interest $ 194,087 $ 199,960 Cash paid for income taxes 9 — Cash received for income tax refunds 7 7,786 Non-cash investing activities: Asset retirement obligation additions and revisions, net 4,313 6,591 As of September 30, 2019 and December 31, 2018 , the Company had $236.2 million and $317.5 million , respectively, of accrued capital expenditures included in “Net property and equipment” and “Accounts payable trade” in the condensed consolidated balance sheets. As of September 30, 2019 and December 31, 2018 , the Company had $1.8 million and $9.3 million , respectively, of accrued contributions from noncontrolling interests included in "Receivables – Joint interest and other, net" and "Equity – Noncontrolling interests" in the condensed consolidated balance sheets. As of September 30, 2019 and December 31, 2018 , the Company had $1.0 million and $1.3 million , respectively, of accrued distributions to noncontrolling interests included in "Revenues and royalties payable" and "Equity – Noncontrolling interests" in the condensed consolidated balance sheets. On January 1, 2019 the Company adopted ASU 2016-02 which resulted in the non-cash recognition of offsetting right-of-use assets and lease liabilities totaling approximately $19 million . See Note 8. Leases for additional information.

Revenues

Revenues	9 Months Ended
	Sep. 30, 2019
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 $53.0 million and $39.3 million for the three months ended September 30, 2019 and 2018 , respectively, and $140.7 million and $119.9 million for the nine months ended September 30, 2019 and 2018 , 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 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 $9.0 million and $6.7 million for the three months ended September 30, 2019 and 2018 , respectively, and $23.9 million and $22.6 million for the nine months ended September 30, 2019 and 2018 , 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 5. Derivative Instruments for discussion of the Company's accounting for its derivative instruments. Revenues from service operations – Revenues from the Company's crude oil and natural gas service operations consist primarily of revenues associated with water gathering, recycling, and disposal activities and the treatment and sale of crude oil reclaimed from waste products. Revenues associated with such activities, which are derived using market-based rates or rates commensurate with industry guidelines, are recognized during the month in which services are performed, the Company has an unconditional right to receive payment, and collectability is probable. Payment is generally received by the Company within one month after the month in which services are provided. Disaggregation of crude oil and natural gas revenues The following tables present the disaggregation of the Company's crude oil and natural gas revenues for the three and nine months ended September 30, 2019 and 2018 . Three months ended September 30, 2019 Three months ended September 30, 2018 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 593,729 $ 210,851 $ 804,580 $ 634,251 $ 159,506 $ 793,757 Non-operated properties 172,383 12,334 184,717 225,513 19,288 244,801 Total crude oil revenues 766,112 223,185 989,297 859,764 178,794 1,038,558 Natural gas revenues: Operated properties 10,719 71,370 82,089 60,381 140,168 200,549 Non-operated properties 3,068 6,946 10,014 16,397 17,734 34,131 Total natural gas revenues 13,787 78,316 92,103 76,778 157,902 234,680 Crude oil and natural gas sales $ 779,899 $ 301,501 $ 1,081,400 $ 936,542 $ 336,696 $ 1,273,238 Timing of revenue recognition Goods transferred at a point in time $ 779,899 $ 301,501 $ 1,081,400 $ 936,542 $ 336,696 $ 1,273,238 Goods transferred over time — — — — — — $ 779,899 $ 301,501 $ 1,081,400 $ 936,542 $ 336,696 $ 1,273,238 Nine months ended September 30, 2019 Nine months ended September 30, 2018 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 1,787,776 $ 523,484 $ 2,311,260 $ 1,791,045 $ 443,562 $ 2,234,607 Non-operated properties 558,893 35,408 594,301 604,700 52,415 657,115 Total crude oil revenues 2,346,669 558,892 2,905,561 2,395,745 495,977 2,891,722 Natural gas revenues: Operated properties 83,831 290,780 374,611 153,627 388,610 542,237 Non-operated properties 18,985 29,252 48,237 44,058 46,601 90,659 Total natural gas revenues 102,816 320,032 422,848 197,685 435,211 632,896 Crude oil and natural gas sales $ 2,449,485 $ 878,924 $ 3,328,409 $ 2,593,430 $ 931,188 $ 3,524,618 Timing of revenue recognition Goods transferred at a point in time $ 2,449,485 $ 878,924 $ 3,328,409 $ 2,593,430 $ 931,188 $ 3,524,618 Goods transferred over time — — — — — — $ 2,449,485 $ 878,924 $ 3,328,409 $ 2,593,430 $ 931,188 $ 3,524,618 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. Upon delivery of production, the Company has a right to receive consideration from its customers in amounts determined by the sales contracts. All of the Company's outstanding crude oil sales contracts at September 30, 2019 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, net", as applicable, in its condensed consolidated balance sheets. Revenues from previously satisfied performance obligations To record revenues for commodity sales, at the end of each month the Company estimates the amount of production delivered and sold to customers and the prices to be received for such sales. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month payment is received from the customer and are reflected in the financial statements within the caption "Crude oil and natural gas sales". Revenues recognized during the three and nine months ended September 30, 2019 and 2018 related to performance obligations satisfied in prior reporting periods were not material.

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments Natural gas derivatives From time to time the Company has entered into natural gas swap and collar derivative contracts to economically hedge against the variability in cash flows associated with future sales of natural gas production. The Company recognizes its derivative instruments on the balance sheet as either assets or liabilities measured at fair value. The Company has not designated its derivatives as hedges for accounting purposes and, as a result, marks such derivative instruments to fair value and recognizes the changes in fair value in the unaudited condensed consolidated statements of comprehensive income under the caption “ Gain (loss) on natural gas derivatives, net ”. The Company's natural gas derivative contracts are settled based upon reported NYMEX Henry Hub settlement prices. 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. The calculation of the fair value of collars requires the use of an option-pricing model. See Note 6. Fair Value Measurements . At September 30, 2019 the Company had outstanding natural gas derivative contracts as set forth in the table below. Collars Floors Ceilings Swaps Weighted Average Price Range Weighted Average Price Range Weighted Average Price Period and Type of Contract MMBtus October 2019 - December 2019 Swaps - Henry Hub 31,734,000 $ 2.85 November 2019 - December 2019 Collars - Henry Hub 18,300,000 $2.50 - $2.55 $ 2.52 $3.00 - $3.01 $ 3.00 Natural gas derivative gains and losses Cash receipts and payments in the following table reflect the gain or loss on derivative contracts which matured during the period, calculated as the difference between the contract price and the market settlement price of matured contracts. Non-cash gains and losses below represent the change in fair value of derivative instruments which continue to be held at period end and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period. Three months ended September 30, Nine months ended September 30, In thousands 2019 2018 2019 2018 Cash received (paid) on derivatives: Natural gas fixed price swaps $ 30,484 $ (1,477 ) $ 46,799 $ 7,477 Natural gas collars — — 5,417 — Cash received (paid) on derivatives, net 30,484 (1,477 ) 52,216 7,477 Non-cash gain (loss) on derivatives: Natural gas fixed price swaps (32,606 ) (548 ) 3,468 (12,013 ) Natural gas collars 3,317 — (2,165 ) — Non-cash gain (loss) on derivatives, net (29,289 ) (548 ) 1,303 (12,013 ) Gain (loss) on natural gas derivatives, net $ 1,195 $ (2,025 ) $ 53,519 $ (4,536 ) Balance sheet offsetting of derivative assets and liabilities The Company’s derivative contracts are recorded at fair value in the condensed consolidated balance sheets under the captions “Derivative assets”, “Noncurrent derivative assets”, “Derivative liabilities”, and “Noncurrent derivative liabilities”, as applicable. Derivative assets and liabilities with the same counterparty that are subject to contractual terms which provide for net settlement are reported on a net basis in the condensed consolidated balance sheets. The following table presents the gross amounts of recognized natural gas derivative assets and liabilities, as applicable, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value. In thousands September 30, 2019 December 31, 2018 Commodity derivative assets: Gross amounts of recognized assets $ 23,456 $ 16,789 Gross amounts offset on balance sheet (6,526 ) (1,177 ) Net amounts of assets on balance sheet 16,930 15,612 Commodity derivative liabilities: Gross amounts of recognized liabilities (6,541 ) (1,177 ) Gross amounts offset on balance sheet 6,526 1,177 Net amounts of liabilities on balance sheet $ (15 ) $ — The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets. In thousands September 30, 2019 December 31, 2018 Derivative assets $ 16,930 $ 15,612 Noncurrent derivative assets — — Net amounts of assets on balance sheet 16,930 15,612 Derivative liabilities (15 ) — Noncurrent derivative liabilities — — Net amounts of liabilities on balance sheet (15 ) — Total derivative assets, net $ 16,915 $ 15,612

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2019
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. The Company’s policy is to recognize transfers between the hierarchy levels as of the beginning of the reporting period in which the event or change in circumstances caused the transfer. Assets and Liabilities Measured at Fair Value on a Recurring Basis The Company's derivative instruments are reported at fair value on a recurring basis. In determining the fair values of swap contracts, a discounted cash flow method is used due to the unavailability of relevant comparable market data for the Company’s exact contracts. The discounted cash flow method estimates future cash flows based on quoted market prices for forward commodity prices and a risk-adjusted discount rate. The fair values of swap contracts are calculated mainly using significant observable inputs (Level 2). Calculation of the fair values of collars requires the use of an industry-standard option pricing model that considers various inputs including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. These assumptions are observable in the marketplace or can be corroborated by active markets or broker quotes and are therefore designated as Level 2 within the valuation hierarchy. The Company’s calculation of fair value for each of its derivative positions is compared to the counterparty valuation for reasonableness. The following tables summarize the valuation of financial instruments by pricing levels that were accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018 . Fair value measurements at September 30, 2019 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets: Swaps $ — $ 13,598 $ — $ 13,598 Collars — 3,317 — 3,317 Total $ — $ 16,915 $ — $ 16,915 Fair value measurements at December 31, 2018 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets: Swaps $ — $ 10,130 $ — $ 10,130 Collars — 5,482 — 5,482 Total $ — $ 15,612 $ — $ 15,612 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. The discounted cash flow method estimates future cash flows based on the Company’s estimates of future crude oil and natural gas production, commodity prices based on commodity futures price strips adjusted for differentials, operating costs, and a risk-adjusted discount rate. The fair value of proved crude oil and natural gas properties is calculated using significant unobservable inputs (Level 3). The following table sets forth quantitative information about the significant unobservable inputs used by the Company at September 30, 2019 to calculate the fair value of proved crude oil and natural gas properties using a discounted cash flow method. Unobservable Input Assumption Future production Future production estimates for each property Forward commodity prices Forward NYMEX strip prices through 2023 (adjusted for differentials), escalating 3% per year thereafter Operating costs Estimated costs for the current year, escalating 3% per year thereafter Productive life of properties Up to 50 years Discount rate 10% Unobservable inputs to the fair value assessment are reviewed quarterly and are revised as warranted based on a number of factors, including reservoir performance, new drilling, crude oil and natural gas prices, changes in costs, technological advances, new geological or geophysical data, or other economic factors. Fair value measurements of proved properties are reviewed and approved by certain members of the Company’s management. For the three and nine months ended September 30, 2019 and 2018 , 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 those periods. Certain unproved crude oil and natural gas properties were impaired during the three and nine months ended September 30, 2019 and 2018 , 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. Three months ended September 30, Nine months ended September 30, In thousands 2019 2018 2019 2018 Proved property impairments $ — $ — $ — $ — Unproved property impairments 20,199 23,770 66,854 86,715 Total $ 20,199 $ 23,770 $ 66,854 $ 86,715 Financial Instruments Not Recorded at Fair Value The following table sets forth the estimated fair values of financial instruments that are not recorded at fair value in the condensed consolidated financial statements. September 30, 2019 December 31, 2018 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 300,000 $ 300,000 $ — $ — Note payable 5,946 5,900 7,700 7,700 5% Senior Notes due 2022 1,099,097 1,109,400 1,598,404 1,590,900 4.5% Senior Notes due 2023 1,490,728 1,557,400 1,488,960 1,476,300 3.8% Senior Notes due 2024 994,016 1,019,800 993,151 947,200 4.375% Senior Notes due 2028 989,398 1,033,200 988,617 942,800 4.9% Senior Notes due 2044 691,644 709,600 691,517 618,800 Total debt $ 5,570,829 $ 5,735,300 $ 5,768,349 $ 5,583,700 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	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt, net of unamortized discounts, premiums, and debt issuance costs totaling $35.1 million and $39.4 million at September 30, 2019 and December 31, 2018 , respectively, consists of the following. In thousands September 30, 2019 December 31, 2018 Credit facility $ 300,000 $ — Note payable 5,946 7,700 5% Senior Notes due 2022 1,099,097 1,598,404 4.5% Senior Notes due 2023 1,490,728 1,488,960 3.8% Senior Notes due 2024 994,016 993,151 4.375% Senior Notes due 2028 989,398 988,617 4.9% Senior Notes due 2044 691,644 691,517 Total debt $ 5,570,829 $ 5,768,349 Less: Current portion of long-term debt 2,416 2,360 Long-term debt, net of current portion $ 5,568,413 $ 5,765,989 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 $300 million of outstanding borrowings on its credit facility at September 30, 2019 , which were incurred to fund a portion of the Company's $500 million redemption of its 2022 Notes in September 2019 as discussed below. Credit facility borrowings bear interest at market-based interest rates plus a margin based on the terms of the borrowing and the credit ratings assigned to the Company's senior, unsecured, long-term indebtedness. The weighted-average interest rate on outstanding credit facility borrowings at September 30, 2019 was 3.6% . The Company had approximately $1.2 billion of borrowing availability on its credit facility at September 30, 2019 and incurs commitment fees based on currently assigned credit ratings of 0.20% per annum on the daily average amount of unused borrowing availability. The credit facility contains certain restrictive covenants including a requirement that the Company maintain a consolidated net debt to total capitalization ratio of no greater than 0.65 to 1.00. This ratio represents the ratio of net debt (calculated as total face value of debt plus outstanding letters of credit less cash and cash equivalents) divided by the sum of net debt plus total shareholders' equity plus, to the extent resulting in a reduction of total shareholders’ equity, the amount of any non-cash impairment charges incurred, net of any tax effect, after June 30, 2014. The Company was in compliance with the credit facility covenants at September 30, 2019 . Senior Notes The following table summarizes the face values, maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at September 30, 2019 . 2022 Notes (1) 2023 Notes 2024 Notes 2028 Notes 2044 Notes Face value (in thousands) $1,100,000 $1,500,000 $1,000,000 $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 September 30, 2019 . 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 minor, 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 minor, do not guarantee the senior notes. Partial redemptions of senior notes 2019 On September 12, 2019, the Company redeemed $500 million of its previously outstanding $1.6 billion of 5% Senior Notes due 2022. The redemption price was equal to 100.833% of the principal amount called for redemption plus accrued and unpaid interest to the redemption date. The Company funded the redemption using available cash and lower-rate borrowings under its credit facility. The aggregate of the principal amount, redemption premium, and accrued interest paid upon redemption was $516.5 million . The Company recorded a pre-tax loss on extinguishment of debt related to the redemption of $4.6 million , which included the redemption premium and pro-rata write-off of deferred financing costs and unamortized debt premium associated with the notes. The loss is reflected under the caption “Loss on extinguishment of debt” in the unaudited condensed consolidated statements of comprehensive income. 2018 On August 16, 2018, the Company redeemed $400 million of its original outstanding $2.0 billion of 5% Senior Notes due 2022. The redemption price was equal to 101.667% of the principal amount called for redemption plus accrued and unpaid interest to the redemption date. The aggregate of the principal amount, redemption premium, and accrued interest paid upon redemption was $415.1 million . The Company recorded a pre-tax loss on extinguishment of debt related to the redemption of $7.1 million , which included the redemption premium and pro-rata write-off of deferred financing costs and unamortized debt premium associated with the notes. 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 $2.4 million is reflected as a current liability under the caption “Current portion of long-term debt” in the condensed consolidated balance sheets as of September 30, 2019 .

Leases

Leases	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Lessee, Operating Leases [Text Block]	Leases In February 2016 the FASB issued ASU 2016-02, Leases (Topic 842) , which requires companies to recognize a right-of-use asset and related liability on the balance sheet for the rights and obligations arising from leases with durations greater than twelve months. The standard became effective for interim and annual reporting periods beginning after December 15, 2018. The Company adopted the new standard on January 1, 2019 on a prospective basis using the simplified transition method prescribed by ASU 2018-11, Leases (Topic 842): Targeted Improvements . Offsetting right-of-use assets and lease liabilities recognized by the Company on the January 1, 2019 adoption date totaled approximately $19 million , representing minimum payment obligations associated with drilling rig commitments, surface use agreements, equipment, and other leases with contractual durations in excess of one year. No cumulative-effect adjustment to retained earnings was recognized upon adoption of the new standard. The Company has elected to account for lease and non-lease components in its contracts as a single lease component for all asset classes. Additionally, the Company has elected not to apply the recognition requirements of ASC Topic 842 to leases with durations of twelve months or less and has elected to use hindsight in determining the lease term for all leases. The Company's leasing activities as a lessor are negligible. Presented below are disclosures required by the new lease standard. 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 lease liabilities recognized on the balance sheet as a lessee totaled $10.2 million as of September 30, 2019 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. In thousands Amount Drilling rig commitments $ 4,706 Surface use agreements 3,932 Field equipment 1,238 Other 343 Total $ 10,219 Drilling rig commitments reflected above represent minimum payment obligations expected to be incurred on enforceable commitments with durations in excess of one year at the inception of the lease. Minimum future commitments by year for the Company's operating leases as of September 30, 2019 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 2019 $ 1,797 2020 3,959 2021 710 2022 696 2023 629 Thereafter 5,322 Total operating lease liabilities, at undiscounted value $ 13,113 Less: Imputed interest (2,894 ) Total operating lease liabilities, at discounted present value $ 10,219 Less: Current portion of operating lease liabilities (5,242 ) Operating lease liabilities, net of current portion $ 4,977 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. In thousands, except weighted average data Three months ended September 30, 2019 Nine months ended September 30, 2019 Lease costs: Operating lease costs $ 2,784 $ 9,330 Variable lease costs 3,820 11,633 Short-term lease costs 47,956 142,634 Total lease costs $ 54,560 $ 163,597 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 615 $ 615 Operating cash flows from operating leases included in lease liabilities 202 600 Weighted average remaining lease term as of September 30, 2019 (in years) 9.2 Weighted average discount rate as of September 30, 2019 4.8 %

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Included below is a discussion of certain future commitments and contingencies of the Company as of September 30, 2019 . Drilling rig commitments – As of September 30, 2019 , the Company has drilling rig contracts with various terms extending to September 2020 to ensure rig availability in its key operating areas. Future operating day-rate commitments as of September 30, 2019 total approximately $57 million , of which $29 million is expected to be incurred in the remainder of 2019 and $28 million in 2020 . A portion of these future costs will be borne by other interest owners. Such future commitments include minimum payment obligations with a discounted present value totaling $4.7 million that are required to be recognized on the Company's balance sheet at September 30, 2019 in accordance with ASC Topic 842 as discussed in Note 8. Leases . Other lease commitments – The Company has various other lease commitments primarily associated with surface use agreements and field equipment. See Note 8. Leases for additional information. Transportation, gathering, and processing commitments – The Company has entered into transportation, gathering, and processing commitments to guarantee capacity on crude oil and natural gas pipelines and natural gas processing facilities. The commitments, which have varying terms extending as far as 2031, require the Company to pay per-unit transportation, gathering, or processing charges regardless of the amount of capacity used. Future commitments remaining as of September 30, 2019 under the arrangements amount to approximately $2.26 billion , of which $68 million is expected to be incurred in the remainder of 2019 , $285 million in 2020 , $332 million in 2021 , $330 million in 2022 , $331 million in 2023, and $913 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. Dividend declaration – See Note 11. Shareholders' Equity for discussion of the Company's dividend payment obligation as of September 30, 2019 . Litigation – In November 2010, a putative class action was filed in the District Court of Blaine County, Oklahoma by Billy J. Strack and Daniela A. Renner as trustees of certain named trusts and on behalf of other similarly situated parties against the Company. The Petition, as amended, alleged the Company improperly deducted post-production costs from royalties paid to plaintiffs and other royalty interest owners from crude oil and natural gas wells located in Oklahoma. The plaintiffs alleged a number of claims, including breach of contract, fraud, breach of fiduciary duty, unjust enrichment, and other claims and sought recovery of compensatory damages, interest, punitive damages and attorney fees on behalf of the proposed class. The Company denied all allegations and denied that the case was properly brought as a class action. Due to the uncertainty of and burdens of litigation, in February 2018 the Company reached a settlement in connection with this matter, which was subsequently approved by the District Court of Garfield County, Oklahoma in June 2018. Under the settlement, the Company initially expected to make payments and incur costs associated with the settlement of approximately $59.6 million and accrued a loss for such amount at December 31, 2017. The Company has now satisfied substantially all of its monetary obligations under the settlement. The Company is involved in various other legal proceedings including, but not limited to, commercial disputes, claims from royalty and surface owners, property damage claims, personal injury claims, regulatory compliance matters, disputes with tax authorities and other matters. While the outcome of these legal matters cannot be predicted with certainty, the Company does not expect them to have a material effect on its financial condition, results of operations or cash flows. As of September 30, 2019 , the Company had recognized a $3.1 million liability within "Accrued liabilities and other" and a liability of $5.4 million and $4.7 million within “Other noncurrent liabilities” as of September 30, 2019 and December 31, 2018 , respectively, for various matters, none of which are believed to be individually significant. Environmental risk – Due to the nature of the crude oil and natural gas business, the Company is exposed to possible environmental risks. The Company is not aware of any material environmental issues or claims.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2019
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 ("2013 Plan") as discussed below. 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, was $12.9 million and $11.7 million for the three months ended September 30, 2019 and 2018 , respectively, and $37.2 million and $33.2 million for the nine months ended September 30, 2019 and 2018 , respectively. In May 2013, the Company adopted the 2013 Plan and reserved 19,680,072 shares of common stock that may be issued pursuant to the plan. As of September 30, 2019 , the Company had 13,021,268 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 under the Company's dividend payment program discussed in Note 11. Shareholders' Equity , subject to forfeiture. Restricted stock grants generally vest over periods ranging from 1 to 3 years. A summary of changes in non-vested restricted shares outstanding for the nine months ended September 30, 2019 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2018 4,022,409 $ 38.44 Granted 1,496,186 43.99 Vested (1,691,097 ) 23.48 Forfeited (314,613 ) 47.36 Non-vested restricted shares outstanding at September 30, 2019 3,512,885 $ 47.21 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 nine months ended September 30, 2019 was approximately $78 million . As of September 30, 2019 , there was approximately $82 million of unrecognized compensation expense related to non-vested restricted stock. This expense is expected to be recognized over a weighted average period of 1.5

Shareholders' Equity

Shareholders' Equity	9 Months Ended
	Sep. 30, 2019
Shareholders' Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Shareholders' Equity Share repurchase program In May 2019 the Company's Board of Directors approved the initiation of a share repurchase program to acquire up to $1 billion of the Company's common stock beginning in June 2019 and expected to continue through 2020. As of September 30, 2019 , the Company had repurchased and retired 5,006,553 shares under the program at an aggregate cost of $172.0 million . Under the program, the Company may repurchase shares from time to time at management's discretion in accordance with applicable securities laws, including through open market transactions, privately negotiated transactions or any combination thereof. In addition, shares may also be repurchased pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Securities Exchange Act of 1934. The timing and amount of repurchases are subject to market conditions. 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 declaration In May 2019 the Company's Board of Directors approved the initiation of a dividend payment program and on June 3, 2019 the Company announced a quarterly cash dividend of $0.05 per share on the Company's outstanding common stock, payable on November 21, 2019 to shareholders of record on November 7, 2019. At September 30, 2019 the Company had an $18.6 million

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2019
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. A valuation allowance for deferred tax assets is recorded when it is more likely than not that the benefit from the deferred tax asset will not be realized. The Company's provision for income taxes and resulting effective tax rates were as follows for the periods presented. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Provision for income taxes (in thousands) $ 49,747 $ 97,466 $ 177,386 $ 244,234 Effective tax rate 24.0 % 23.7 % 23.4 % 23.6 % The Company computes its quarterly income tax provision under the effective tax rate method based on applying an anticipated annual effective tax rate to year-to-date pre-tax income, 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, and other tax items as reflected in the table below. Three months ended September 30, Nine months ended September 30, In thousands, except tax rates 2019 2018 2019 2018 Income before income taxes $ 207,169 $ 411,635 $ 757,751 $ 1,034,814 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % 21.0 % Expected income tax provision based on U.S. federal statutory tax rate 43,505 86,443 159,128 217,311 Items impacting the effective tax rate: State and local income taxes, net of federal benefit 7,312 12,349 26,648 31,044 Equity compensation 92 (235 ) (8,124 ) (2,103 ) Other, net (1,162 ) (1,091 ) (266 ) (2,018 ) Provision for income taxes $ 49,747 $ 97,466 $ 177,386 $ 244,234 Effective tax rate 24.0 % 23.7 % 23.4 % 23.6 %

Asset Disposition (Notes)

Asset Disposition (Notes)	9 Months Ended
	Sep. 30, 2019
Asset Disposition [Abstract]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	Asset Disposition In July 2019 the Company sold certain water gathering, recycling, and disposal assets in the STACK play for proceeds of $85.3 million

Basis of Presentation and Sig_2

Basis of Presentation and Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2019
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. A majority of the Company’s operations are located in the North region, with that region comprising 61% of the Company’s crude oil and natural gas production and 74% of its crude oil and natural gas revenues for the nine months ended September 30, 2019 . 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 continue to expand with its increased activity in the SCOOP and STACK plays and that region comprised 39% of the Company's crude oil and natural gas production and 26% of its crude oil and natural gas revenues for the nine months ended September 30, 2019 . For the nine months ended September 30, 2019 , crude oil accounted for 59% of the Company’s total production and 87%
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 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, 2018 (“ 2018 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures. The condensed consolidated financial statements as of September 30, 2019 and for the three and nine month periods ended September 30, 2019 and 2018 are unaudited. The condensed consolidated balance sheet as of December 31, 2018 was derived from the audited balance sheet included in the 2018 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 Basic net income per share is computed by dividing net income 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
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, 2019 the Company adopted Accounting Standards Update ("ASU") 2016-02, Leases (Topic 842) . See Note 8. Leases for discussion of the adoption impact and the applicable disclosures required by the new guidance. New accounting pronouncement not yet adopted In June 2016 the Financial Accounting Standards Board ("FASB") issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments . This standard changes how entities will measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The standard will replace the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost. The standard is effective for interim and annual periods beginning after December 15, 2019 and shall be applied using a modified retrospective approach resulting in a cumulative effect adjustment to retained earnings upon adoption. The Company continues to evaluate the new standard and is unable to estimate its financial statement impact at this time; however, the impact is not expected to be material. Historically, the Company's credit losses on crude oil and natural gas sales receivables and joint interest receivables have been immaterial.

Basis of Presentation and Sig_3

Basis of Presentation and Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Components of Inventories	The components of inventory as of September 30, 2019 and December 31, 2018 consisted of the following: In thousands September 30, 2019 December 31, 2018 Tubular goods and equipment $ 15,360 $ 14,623 Crude oil 94,963 73,921 Total $ 110,323 $ 88,544
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 per share attributable to the Company for the three and nine months ended September 30, 2019 and 2018 . Three months ended September 30, Nine months ended September 30, In thousands, except per share data 2019 2018 2019 2018 Net income attributable to Continental Resources (numerator) $ 158,162 $ 314,169 $ 581,695 $ 790,580 Weighted average shares (denominator): Weighted average shares - basic 369,739 371,960 371,702 371,810 Non-vested restricted stock 937 2,663 1,804 2,952 Weighted average shares - diluted 370,676 374,623 373,506 374,762 Net income per share attributable to Continental Resources: Basic $ 0.43 $ 0.84 $ 1.56 $ 2.13 Diluted $ 0.43 $ 0.84 $ 1.56 $ 2.11

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Summary of Supplemental Cash Flow Information	The following table discloses supplemental cash flow information about cash paid for interest and income tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments. Nine months ended September 30, In thousands 2019 2018 Supplemental cash flow information: Cash paid for interest $ 194,087 $ 199,960 Cash paid for income taxes 9 — Cash received for income tax refunds 7 7,786 Non-cash investing activities: Asset retirement obligation additions and revisions, net 4,313 6,591

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	The following tables present the disaggregation of the Company's crude oil and natural gas revenues for the three and nine months ended September 30, 2019 and 2018 . Three months ended September 30, 2019 Three months ended September 30, 2018 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 593,729 $ 210,851 $ 804,580 $ 634,251 $ 159,506 $ 793,757 Non-operated properties 172,383 12,334 184,717 225,513 19,288 244,801 Total crude oil revenues 766,112 223,185 989,297 859,764 178,794 1,038,558 Natural gas revenues: Operated properties 10,719 71,370 82,089 60,381 140,168 200,549 Non-operated properties 3,068 6,946 10,014 16,397 17,734 34,131 Total natural gas revenues 13,787 78,316 92,103 76,778 157,902 234,680 Crude oil and natural gas sales $ 779,899 $ 301,501 $ 1,081,400 $ 936,542 $ 336,696 $ 1,273,238 Timing of revenue recognition Goods transferred at a point in time $ 779,899 $ 301,501 $ 1,081,400 $ 936,542 $ 336,696 $ 1,273,238 Goods transferred over time — — — — — — $ 779,899 $ 301,501 $ 1,081,400 $ 936,542 $ 336,696 $ 1,273,238 Nine months ended September 30, 2019 Nine months ended September 30, 2018 In thousands North Region South Region Total North Region South Region Total Crude oil revenues: Operated properties $ 1,787,776 $ 523,484 $ 2,311,260 $ 1,791,045 $ 443,562 $ 2,234,607 Non-operated properties 558,893 35,408 594,301 604,700 52,415 657,115 Total crude oil revenues 2,346,669 558,892 2,905,561 2,395,745 495,977 2,891,722 Natural gas revenues: Operated properties 83,831 290,780 374,611 153,627 388,610 542,237 Non-operated properties 18,985 29,252 48,237 44,058 46,601 90,659 Total natural gas revenues 102,816 320,032 422,848 197,685 435,211 632,896 Crude oil and natural gas sales $ 2,449,485 $ 878,924 $ 3,328,409 $ 2,593,430 $ 931,188 $ 3,524,618 Timing of revenue recognition Goods transferred at a point in time $ 2,449,485 $ 878,924 $ 3,328,409 $ 2,593,430 $ 931,188 $ 3,524,618 Goods transferred over time — — — — — — $ 2,449,485 $ 878,924 $ 3,328,409 $ 2,593,430 $ 931,188 $ 3,524,618

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2019
Summary of Outstanding Contracts with Respect to Natural Gas	At September 30, 2019 the Company had outstanding natural gas derivative contracts as set forth in the table below. Collars Floors Ceilings Swaps Weighted Average Price Range Weighted Average Price Range Weighted Average Price Period and Type of Contract MMBtus October 2019 - December 2019 Swaps - Henry Hub 31,734,000 $ 2.85 November 2019 - December 2019 Collars - Henry Hub 18,300,000 $2.50 - $2.55 $ 2.52 $3.00 - $3.01 $ 3.00
Realized and Unrealized Gains and Losses on Derivative Instruments	Cash receipts and payments in the following table reflect the gain or loss on derivative contracts which matured during the period, calculated as the difference between the contract price and the market settlement price of matured contracts. Non-cash gains and losses below represent the change in fair value of derivative instruments which continue to be held at period end and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period. Three months ended September 30, Nine months ended September 30, In thousands 2019 2018 2019 2018 Cash received (paid) on derivatives: Natural gas fixed price swaps $ 30,484 $ (1,477 ) $ 46,799 $ 7,477 Natural gas collars — — 5,417 — Cash received (paid) on derivatives, net 30,484 (1,477 ) 52,216 7,477 Non-cash gain (loss) on derivatives: Natural gas fixed price swaps (32,606 ) (548 ) 3,468 (12,013 ) Natural gas collars 3,317 — (2,165 ) — Non-cash gain (loss) on derivatives, net (29,289 ) (548 ) 1,303 (12,013 ) Gain (loss) on natural gas derivatives, net $ 1,195 $ (2,025 ) $ 53,519 $ (4,536 )
Gross Amounts of Recognized Derivative Assets and Liabilities	The following table presents the gross amounts of recognized natural gas derivative assets and liabilities, as applicable, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value. In thousands September 30, 2019 December 31, 2018 Commodity derivative assets: Gross amounts of recognized assets $ 23,456 $ 16,789 Gross amounts offset on balance sheet (6,526 ) (1,177 ) Net amounts of assets on balance sheet 16,930 15,612 Commodity derivative liabilities: Gross amounts of recognized liabilities (6,541 ) (1,177 ) Gross amounts offset on balance sheet 6,526 1,177 Net amounts of liabilities on balance sheet $ (15 ) $ —
Reconciles Net Amounts Derivative Assets and Liabilities	The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets. In thousands September 30, 2019 December 31, 2018 Derivative assets $ 16,930 $ 15,612 Noncurrent derivative assets — — Net amounts of assets on balance sheet 16,930 15,612 Derivative liabilities (15 ) — Noncurrent derivative liabilities — — Net amounts of liabilities on balance sheet (15 ) — Total derivative assets, net $ 16,915 $ 15,612

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Valuation of Financial Instruments by Pricing Levels	The following tables summarize the valuation of financial instruments by pricing levels that were accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018 . Fair value measurements at September 30, 2019 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets: Swaps $ — $ 13,598 $ — $ 13,598 Collars — 3,317 — 3,317 Total $ — $ 16,915 $ — $ 16,915 Fair value measurements at December 31, 2018 using: In thousands Level 1 Level 2 Level 3 Total Derivative assets: Swaps $ — $ 10,130 $ — $ 10,130 Collars — 5,482 — 5,482 Total $ — $ 15,612 $ — $ 15,612
Quantitative Information about Significant Unobservable Inputs	The following table sets forth quantitative information about the significant unobservable inputs used by the Company at September 30, 2019 to calculate the fair value of proved crude oil and natural gas properties using a discounted cash flow method. Unobservable Input Assumption Future production Future production estimates for each property Forward commodity prices Forward NYMEX strip prices through 2023 (adjusted for differentials), escalating 3% per year thereafter Operating costs Estimated costs for the current year, escalating 3% per year thereafter Productive life of properties Up to 50 years Discount rate 10%
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. Three months ended September 30, Nine months ended September 30, In thousands 2019 2018 2019 2018 Proved property impairments $ — $ — $ — $ — Unproved property impairments 20,199 23,770 66,854 86,715 Total $ 20,199 $ 23,770 $ 66,854 $ 86,715
Fair Values of Financial Instruments not Recorded at Fair Value	The following table sets forth the estimated fair values of financial instruments that are not recorded at fair value in the condensed consolidated financial statements. September 30, 2019 December 31, 2018 In thousands Carrying Estimated Fair Value Carrying Estimated Fair Value Debt: Credit facility $ 300,000 $ 300,000 $ — $ — Note payable 5,946 5,900 7,700 7,700 5% Senior Notes due 2022 1,099,097 1,109,400 1,598,404 1,590,900 4.5% Senior Notes due 2023 1,490,728 1,557,400 1,488,960 1,476,300 3.8% Senior Notes due 2024 994,016 1,019,800 993,151 947,200 4.375% Senior Notes due 2028 989,398 1,033,200 988,617 942,800 4.9% Senior Notes due 2044 691,644 709,600 691,517 618,800 Total debt $ 5,570,829 $ 5,735,300 $ 5,768,349 $ 5,583,700

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 . 2022 Notes (1) 2023 Notes 2024 Notes 2028 Notes 2044 Notes Face value (in thousands) $1,100,000 $1,500,000 $1,000,000 $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 $35.1 million and $39.4 million at September 30, 2019 and December 31, 2018 , respectively, consists of the following. In thousands September 30, 2019 December 31, 2018 Credit facility $ 300,000 $ — Note payable 5,946 7,700 5% Senior Notes due 2022 1,099,097 1,598,404 4.5% Senior Notes due 2023 1,490,728 1,488,960 3.8% Senior Notes due 2024 994,016 993,151 4.375% Senior Notes due 2028 989,398 988,617 4.9% Senior Notes due 2044 691,644 691,517 Total debt $ 5,570,829 $ 5,768,349 Less: Current portion of long-term debt 2,416 2,360 Long-term debt, net of current portion $ 5,568,413 $ 5,765,989

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Operating lease liabilities [Table Text Block]	The Company’s lease liabilities recognized on the balance sheet as a lessee totaled $10.2 million as of September 30, 2019 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. In thousands Amount Drilling rig commitments $ 4,706 Surface use agreements 3,932 Field equipment 1,238 Other 343 Total $ 10,219
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Minimum future commitments by year for the Company's operating leases as of September 30, 2019 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 2019 $ 1,797 2020 3,959 2021 710 2022 696 2023 629 Thereafter 5,322 Total operating lease liabilities, at undiscounted value $ 13,113 Less: Imputed interest (2,894 ) Total operating lease liabilities, at discounted present value $ 10,219 Less: Current portion of operating lease liabilities (5,242 ) Operating lease liabilities, net of current portion $ 4,977
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. In thousands, except weighted average data Three months ended September 30, 2019 Nine months ended September 30, 2019 Lease costs: Operating lease costs $ 2,784 $ 9,330 Variable lease costs 3,820 11,633 Short-term lease costs 47,956 142,634 Total lease costs $ 54,560 $ 163,597 Other information: Right-of-use assets obtained in exchange for new operating lease liabilities $ 615 $ 615 Operating cash flows from operating leases included in lease liabilities 202 600 Weighted average remaining lease term as of September 30, 2019 (in years) 9.2 Weighted average discount rate as of September 30, 2019 4.8 %

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2019
Restricted stock [Member]
Summary of Changes in Non-vested Shares of Restricted Stock Outstanding	A summary of changes in non-vested restricted shares outstanding for the nine months ended September 30, 2019 is presented below. Number of Weighted average Non-vested restricted shares outstanding at December 31, 2018 4,022,409 $ 38.44 Granted 1,496,186 43.99 Vested (1,691,097 ) 23.48 Forfeited (314,613 ) 47.36 Non-vested restricted shares outstanding at September 30, 2019 3,512,885 $ 47.21

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2019
Effective Tax Rate Reconciliation Table [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	The Company's provision for income taxes and resulting effective tax rates were as follows for the periods presented. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Provision for income taxes (in thousands) $ 49,747 $ 97,466 $ 177,386 $ 244,234 Effective tax rate 24.0 % 23.7 % 23.4 % 23.6 %
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, and other tax items as reflected in the table below. Three months ended September 30, Nine months ended September 30, In thousands, except tax rates 2019 2018 2019 2018 Income before income taxes $ 207,169 $ 411,635 $ 757,751 $ 1,034,814 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % 21.0 % Expected income tax provision based on U.S. federal statutory tax rate 43,505 86,443 159,128 217,311 Items impacting the effective tax rate: State and local income taxes, net of federal benefit 7,312 12,349 26,648 31,044 Equity compensation 92 (235 ) (8,124 ) (2,103 ) Other, net (1,162 ) (1,091 ) (266 ) (2,018 ) Provision for income taxes $ 49,747 $ 97,466 $ 177,386 $ 244,234 Effective tax rate 24.0 % 23.7 % 23.4 % 23.6 %

Organization and Nature of Bu_2

Organization and Nature of Business - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2019
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	59.00%
Percentage of crude oil and natural gas revenue concentrated in crude oil	87.00%
North Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	61.00%
Percentage of revenues concentrated in geographic areas	74.00%
South Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	39.00%
Percentage of revenues concentrated in geographic areas	26.00%

Basis of Presentation and Sig_4

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Accounting Policies [Abstract]
Tubular goods and equipment	$ 15,360	$ 14,623
Crude oil	94,963	73,921
Total	$ 110,323	$ 88,544

Basis of Presentation and Sig_5

Basis of Presentation and Significant Accounting Policies - Earnings Per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net income attributable to Continental Resources (numerator)
Net income attributable to Continental Resources (numerator)	$ 158,162	$ 314,169	$ 581,695	$ 790,580
Weighted average shares - basic	369,739	371,960	371,702	371,810
Non-vested restricted stock	937	2,663	1,804	2,952
Weighted average shares - diluted	370,676	374,623	373,506	374,762
Net income per share attributable to Continental Resources:
Basic (in dollars per share)	$ 0.43	$ 0.84	$ 1.56	$ 2.13
Diluted (in dollars per share)	$ 0.43	$ 0.84	$ 1.56	$ 2.11

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	$ 194,087	$ 199,960
Cash paid for income taxes	9	0
Cash received for income tax refunds	7	7,786
Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	236,200		$ 317,500
Increase (Decrease) in Asset Retirement Obligations	4,313	$ 6,591
Accrued contributions from noncontrolling interests	1,800		9,300
Accrued distributions to noncontrolling interests	1,000		$ 1,300
ASU 2016-02 Lease assets and liabilities recognition	$ 19,000

Revenues Disaggregation of Reve

Revenues Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 1,081,400	$ 1,273,238	$ 3,328,409	$ 3,524,618
Transportation expenses	62,038	46,008	164,569	142,559
Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	1,081,400	1,273,238	3,328,409	3,524,618
Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0	0	0
North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	779,899	936,542	2,449,485	2,593,430
North Region [Member] | Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	779,899	936,542	2,449,485	2,593,430
North Region [Member] | Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0	0	0
South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	301,501	336,696	878,924	931,188
South Region [Member] | Transferred at Point in Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	301,501	336,696	878,924	931,188
South Region [Member] | Transferred over Time
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	0	0	0	0
Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	989,297	1,038,558	2,905,561	2,891,722
Transportation expenses	53,000	39,300	140,700	119,900
Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	766,112	859,764	2,346,669	2,395,745
Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	223,185	178,794	558,892	495,977
Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	92,103	234,680	422,848	632,896
Transportation expenses	9,000	6,700	23,900	22,600
Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	13,787	76,778	102,816	197,685
Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	78,316	157,902	320,032	435,211
Operated properties | Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	804,580	793,757	2,311,260	2,234,607
Operated properties | Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	593,729	634,251	1,787,776	1,791,045
Operated properties | Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	210,851	159,506	523,484	443,562
Operated properties | Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	82,089	200,549	374,611	542,237
Operated properties | Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	10,719	60,381	83,831	153,627
Operated properties | Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	71,370	140,168	290,780	388,610
Non-operated properties | Crude oil sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	184,717	244,801	594,301	657,115
Non-operated properties | Crude oil sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	172,383	225,513	558,893	604,700
Non-operated properties | Crude oil sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	12,334	19,288	35,408	52,415
Non-operated properties | Natural gas sales
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	10,014	34,131	48,237	90,659
Non-operated properties | Natural gas sales | North Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	3,068	16,397	18,985	44,058
Non-operated properties | Natural gas sales | South Region [Member]
Disaggregation of Revenue [Line Items]
Crude oil and natural gas sales	$ 6,946	$ 17,734	$ 29,252	$ 46,601

Derivative Instruments - Summar

Derivative Instruments - Summary of Outstanding Contracts with Respect to Natural Gas (Detail) - Natural Gas [Member]	9 Months Ended
	Sep. 30, 2019MMBTU$ / MMBTU
October 2019 to December 2019 Swaps [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	31,734,000
Swaps Weighted Average Price	2.85
November 2019 to December 2019 Collars [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus | MMBTU	18,300,000
Derivative, Average Floor Price	2.52
Derivative, Average Cap Price	3
Minimum [Member] | November 2019 to December 2019 Collars [Member]
Derivative [Line Items]
Derivative, Floor Price	2.50
Derivative, Cap Price	3
Maximum [Member] | November 2019 to December 2019 Collars [Member]
Derivative [Line Items]
Derivative, Floor Price	2.55
Derivative, Cap Price	3.01

Derivative Instruments - Realiz

Derivative Instruments - Realized and Unrealized Gains and Losses on Derivative Instruments (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net			$ 1,303	$ (12,013)
Gain (loss) on natural gas derivatives, net	$ 1,195	$ (2,025)	53,519	(4,536)
Swap [Member] | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	30,484	(1,477)	46,799	7,477
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(32,606)	(548)	3,468	(12,013)
Collars | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	0	5,417	0
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	3,317	0	(2,165)	0
Crude Oil and Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	30,484	(1,477)	52,216	7,477
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	(29,289)	(548)	1,303	(12,013)
Gain (loss) on natural gas derivatives, net	$ 1,195	$ (2,025)	$ 53,519	$ (4,536)

Derivative Instruments - Gross

Derivative Instruments - Gross Amounts of Recognized Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gross amounts of recognized assets	$ 23,456	$ 16,789
Gross amounts offset on balance sheet	(6,526)	(1,177)
Net amounts of assets on balance sheet	16,930	15,612
Gross amounts of recognized liabilities	(6,541)	(1,177)
Gross amounts offset on balance sheet	6,526	1,177
Net amounts of liabilities on balance sheet	$ (15)	$ 0

Derivative Instruments - Reconc

Derivative Instruments - Reconciles Net Amounts Derivative Assets and Liabilities (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative assets	$ 16,930	$ 15,612
Noncurrent derivative assets	0	0
Net amounts of assets on balance sheet	16,930	15,612
Derivative liabilities	(15)	0
Noncurrent derivative liabilities	0	0
Net amounts of liabilities on balance sheet	(15)	0
Total derivative assets (liabilities), net	$ 16,915	$ 15,612

Fair Value Measurements - Valua

Fair Value Measurements - Valuation of Financial Instruments by Pricing Levels (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Derivative assets (liabilities):
Derivative assets (liabilities)	$ 16,915	$ 15,612
Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	13,598	10,130
Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	3,317	5,482
Fair Value, Inputs, Level 1 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 1 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 1 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 2 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	16,915	15,612
Fair Value, Inputs, Level 2 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	13,598	10,130
Fair Value, Inputs, Level 2 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	3,317	5,482
Fair Value, Inputs, Level 3 [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 3 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	$ 0	$ 0

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2019
Fair Value Measurements [Line Items]
Operating cost escalation assumption used in impairment assessment	3.00%
Discount factor utilized as standardized measure for future net cash flows	10.00%
Productive life of field (in years)	50 years
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		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	$ 0	$ 0	$ 0	$ 0
Unproved property impairments	20,199	23,770	66,854	86,715
Property impairments	$ 20,199	$ 23,770	$ 66,854	$ 86,715

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values of Financial Instruments not Recorded at Fair Value (Detail) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
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	$ 300,000	$ 0
Note payable	5,946	7,700
Total debt	5,570,829	5,768,349
Carrying Amount | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,099,097	1,598,404
Carrying Amount | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,490,728	1,488,960
Carrying Amount | 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	994,016	993,151
Carrying Amount | 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	989,398	988,617
Carrying Amount | 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	691,644	691,517
Estimated Fair Value
Fair Value Measurements [Line Items]
Credit facility	300,000	0
Note payable	5,900	7,700
Total debt	5,735,300	5,583,700
Estimated Fair Value | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,109,400	1,590,900
Estimated Fair Value | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,557,400	1,476,300
Estimated Fair Value | 3.8% Senior Notes due 2024
Fair Value Measurements [Line Items]
Senior notes	1,019,800	947,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Fair Value Measurements [Line Items]
Senior notes	1,033,200	942,800
Estimated Fair Value | 4.9% Senior Notes due 2044
Fair Value Measurements [Line Items]
Senior notes	$ 709,600	$ 618,800

Long-Term Debt - Long-Term Debt

Long-Term Debt - Long-Term Debt (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Less: Current portion of long-term debt	$ (2,416)	$ (2,360)
Long-term debt, net of current portion	$ 5,568,413	5,765,989
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	$ 300,000	0
Note payable	5,946	7,700
Total debt	5,570,829	5,768,349
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,097	1,598,404
Carrying Amount | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,490,728	1,488,960
Carrying Amount | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	994,016	993,151
Carrying Amount | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	989,398	988,617
Carrying Amount | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	691,644	691,517
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	300,000	0
Note payable	5,900	7,700
Total debt	5,735,300	5,583,700
Estimated Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,109,400	1,590,900
Estimated Fair Value | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,557,400	1,476,300
Estimated Fair Value | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	1,019,800	947,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	1,033,200	942,800
Estimated Fair Value | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 709,600	$ 618,800

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 12, 2019	Dec. 31, 2018	Aug. 16, 2018
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	$ 35,100		$ 35,100			$ 39,400
Line of credit facility, maturity date			Apr. 9, 2023
Aggregate amount of lender commitments on credit facility	1,500,000		$ 1,500,000
Line of credit facility, commitment fee percentage, per annum			0.20%
Current portion of long-term debt	2,416		$ 2,416			2,360
Line of Credit Facility, Covenant Terms			0.65
TotalRedemptionAmount					$ 516,500		$ 415,100
Loss on extinguishment of debt	$ 4,584	$ 7,133	$ 4,584	$ 7,133
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	3.60%		3.60%
Line of Credit Facility, Remaining Borrowing Capacity	$ 1,200,000		$ 1,200,000
2022 Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount					$ 500,000		$ 400,000
Debt Instrument, Maturity Date			Sep. 15, 2022
Debt Instrument, Redemption Price, Percentage	100.833%	101.667%
4.5% Senior Notes due 2023
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.50%		4.50%
Debt Instrument, Maturity Date, Description			2023
Note payable
Debt Instrument [Line Items]
Notes Payable	$ 22,000		$ 22,000
Loan term			10 years
Debt Instrument, stated interest rate	3.14%		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%		5.00%
Debt Instrument, Maturity Date, Description			2022
3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.80%		3.80%
Debt Instrument, Maturity Date, Description			2024
4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.375%		4.375%
Debt Instrument, Maturity Date, Description			2028
4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%		4.90%
Debt Instrument, Maturity Date, Description			2044
Estimated Fair Value
Debt Instrument [Line Items]
Credit facility	$ 300,000		$ 300,000			0
Notes Payable	5,900		5,900			7,700
Estimated Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,109,400		1,109,400			1,590,900
Estimated Fair Value | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	1,019,800		1,019,800			947,200
Estimated Fair Value | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	1,033,200		1,033,200			942,800
Estimated Fair Value | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	709,600		709,600			618,800
Carrying Amount
Debt Instrument [Line Items]
Credit facility	300,000		300,000			0
Notes Payable	5,946		5,946			7,700
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,099,097		1,099,097			1,598,404
Carrying Amount | 3.8% Senior Notes due 2024
Debt Instrument [Line Items]
Senior notes	994,016		994,016			993,151
Carrying Amount | 4.375% Senior Notes Due 2028
Debt Instrument [Line Items]
Senior notes	989,398		989,398			988,617
Carrying Amount | 4.9% Senior Notes due 2044
Debt Instrument [Line Items]
Senior notes	$ 691,644		$ 691,644			$ 691,517

Long-Term Debt Long-Term Debt -

Long-Term Debt Long-Term Debt - Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
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	$ 1,500,000
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	$ 1,000,000
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	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)
Lessee, Lease, Description [Line Items]
ASU 2016-02 Lease assets and liabilities recognition		$ 19,000
Operating Lease, Liability	$ 10,219	10,219
Operating lease costs	2,784	9,330
Variable Lease, Cost	3,820	11,633
Short-term Lease, Cost	47,956	142,634
Lease, Cost	54,560	163,597
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	615	615
Operating cash flows from operating leases	$ 202	$ 600
Operating Lease, Weighted Average Remaining Lease Term	9 years 2 months 12 days	9 years 2 months 12 days
Weighted average discount rate	4.80%	4.80%
Drilling rig commitments [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 4,706	$ 4,706
Surface use agreements [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	3,932	3,932
Field equipment [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	1,238	1,238
Other [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 343	$ 343

Leases Leases and lease commitm

Leases Leases and lease commitments, Maturities of operating leases (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease payments remainder of fiscal year	$ 1,797
Operating lease payments, due year two	3,959
Operating lease payments, due year three	710
Operating lease payments, due year four	696
Operating lease payments, due year five	629
Operating lease payments, remaining due thereafter	5,322
Operating lease payments due	13,113
Imputed interest	(2,894)
Operating Lease, Liability	10,219
Current portion of operating leases	(5,242)	$ 0
Operating lease liabilities, net of current portion	$ 4,977	$ 0

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies - Additional Information (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation Agreement Expiration Date	2031
Future Drilling Commitments At Balance Sheet Date	$ 57,000
Drilling Commitments Year One	29,000
Drilling Commitments Year Two	28,000
Operating Lease, Liability	10,219
Purchase Obligation	2,260,000
Purchase Obligation, Future Minimum Payments, Remainder of Fiscal Year	68,000
Purchase Obligation, Due in Second Year	285,000
Purchase Obligation, Due in Third Year	332,000
Purchase Obligation, Due in Fourth Year	330,000
Purchase Obligation, Due in Fifth Year	331,000
Purchase Obligation, Due after Fifth Year	$ 913,000
Future Drilling Commitments End Date	2020-09
Drilling rig commitments [Member]
Long-term Purchase Commitment [Line Items]
Operating Lease, Liability	$ 4,706

Commitments and Contingencies L

Commitments and Contingencies Loss Contingencies (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017
Loss Contingencies [Line Items]
Estimated Litigation Liability, Current	$ 3.1
Legal proceedings recorded as a liability under other noncurrent liabilities	$ 5.4	$ 4.7
Strack royalty payment litigation [Member]
Loss Contingencies [Line Items]
Estimated Litigation Liability, Current			$ 59.6

Stock Based Compensation - Stoc

Stock Based Compensation - Stock Based Compensation Expenses (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Share-based Payment Arrangement [Abstract]
Non-cash equity compensation	$ 12.9	$ 11.7	$ 37.2	$ 33.2

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)shares
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock available to grant | shares	13,021,268
Fair value at vesting date | $	$ 78
Unrecognized compensation expense related to non-vested | $	$ 82
Unrecognized compensation expense related to non-vested, period for recognition, in years	1 year 6 months
Restricted stock [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants vest over periods, in years	1 year
Restricted stock [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants vest over periods, in years	3 years
2013 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock available for issue | shares	19,680,072

Stock Based Compensation - Summ

Stock Based Compensation - Summary of Changes in Non Vested Shares of Restricted Stock Outstanding (Detail)	9 Months Ended
	Sep. 30, 2019$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested shares, beginning balance | shares	4,022,409
Granted (unaudited), shares | shares	1,496,186
Vested shares | shares	(1,691,097)
Forfeited (unaudited), shares | shares	(314,613)
Non-vested shares, ending balance | shares	3,512,885
Non-vested, weighted average grant-date fair value, beginning of period | $ / shares	$ 38.44
Granted, weighted average grant-date fair value | $ / shares	43.99
Vested, weighted average grant-date fair value | $ / shares	23.48
Forfeited, weighted average grant-date fair value | $ / shares	47.36
Non-vested, weighted average grant-date fair value, end of period | $ / shares	$ 47.21

Shareholders' Equity Share Repu

Shareholders' Equity Share Repurchase (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	May 31, 2019
Shareholders' Equity [Abstract]
Stock Repurchase Program, Authorized Amount								$ 1,000,000
Stock Repurchased and Retired During Period, Shares							5,006,553
Stock Repurchased and Retired During Period, Value	$ 389	$ 562	$ 20,622	$ 684	$ 773	$ 14,846	$ 172,000

Shareholders' Equity Dividend (

Shareholders' Equity Dividend (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Dividend [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.05
Dividends payable	$ 18,587	$ 0

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income Taxes [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%	21.00%	21.00%	21.00%
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	$ 43,505	$ 86,443	$ 159,128	$ 217,311
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	7,312	12,349	26,648	31,044
Income Tax Reconciliation Equity Compensation	92	(235)	(8,124)	(2,103)
Effective Income Tax Rate Reconciliation, Other Adjustments, Amount	(1,162)	(1,091)	(266)	(2,018)
Income Tax Expense	$ 49,747	$ 97,466	$ 177,386	$ 244,234
Effective Income Tax Rate Reconciliation, Percent	24.00%	23.70%	23.40%	23.60%

Income Taxes Provision for inco

Income Taxes Provision for income taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Income Tax Expense	$ 49,747	$ 97,466	$ 177,386	$ 244,234
Effective Income Tax Rate Reconciliation, Percent	24.00%	23.70%	23.40%	23.60%

Asset Disposition (Details)

Asset Disposition (Details) $ in Millions	3 Months Ended
	Sep. 30, 2019USD ($)
STACK [Member]
Property Acquisition And Dispositions [Line Items]
Proceeds from Sale of Oil and Gas Property and Equipment	$ 85.3