PDC Energy (PDCE) 10-Q 5 Nov 20 2020 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2020	Oct. 22, 2020
Cover [Abstract]
Entity Incorporation, State or Country Code	DE
Title of 12(b) Security	Common stock, par value $0.01 per share
Security Exchange Name	NASDAQ
Entity Tax Identification Number	95-2636730
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80203
City Area Code	303
Local Phone Number	860-5800
Entity Registrant Name	PDC ENERGY, INC.
Entity Address, Address Line One	1775 Sherman Street,
Entity Address, Address Line Two	Suite 3000
Entity Address, City or Town	Denver
Entity Central Index Key	0000077877
Trading Symbol	PDCE
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2020
Document Transition Report	false
Entity File Number	001-37419
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		99,637,673
Smaller Reporting Company	false
Entity Emerging Growth Company	false
Entity Current Reporting Status	Yes

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 3,818	$ 963
Accounts receivable, net	207,151	266,354
Fair value of derivatives	138,652	28,078
Prepaid expenses and other current assets	11,964	8,635
Total current assets	361,585	304,030
Properties and equipment, net	4,885,234	4,095,202
Fair value of derivatives	13,027	3,746
Other assets	72,682	45,702
Total Assets	5,332,528	4,448,680
Current liabilities:
Accounts payable	103,504	98,934
Production tax liability	122,555	76,236
Fair value of derivatives	63,957	2,921
Funds held for distribution	174,084	98,393
Other Long-term Debt, Current	190,608	0
Accrued interest payable	21,179	14,284
Other accrued expenses	81,892	70,462
Total current liabilities	757,779	361,230
Long-term debt	1,525,999	1,177,226
Deferred income taxes	0	195,841
Asset retirement obligations	133,356	95,051
Fair value of derivatives	46,460	692
Other liabilities	250,535	283,133
Total liabilities	2,714,129	2,113,173
Commitments and contingent liabilities (Note 12)
Stockholders' Equity:
Common shares - par value $0.01 per share, 150,000,000 authorized, 99,639,727 and 61,652,412 issued as of September 30, 2020 and December 31, 2019, respectively	996	617
Additional paid-in capital	3,383,648	2,384,309
Accumulated Deficit	(765,575)	(47,945)
Treasury shares - at cost, 17,150 and 34,922 as of September 30, 2020 and December 31, 2019, respectively	(670)	(1,474)
Total stockholders' equity	2,618,399	2,335,507
Total Liabilities and Stockholders' Equity	$ 5,332,528	$ 4,448,680

Balance Sheet Parenthetical (Pa

Balance Sheet Parenthetical (Parentheticals) - $ / shares	Sep. 30, 2020	Dec. 31, 2019
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	150,000,000	150,000,000
Common stock, shares issued	99,639,727	61,652,412
Preferred stock, par value	$ 0.01	$ 0.01
Preferred Stock, Shares Authorized	50,000,000	50,000,000
Preferred Stock, Shares Issued	0	0
Treasury shares, at cost	17,150	34,922

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenues:
Crude oil, natural gas and NGLs sales	$ 314,920	$ 307,409	$ 809,156	$ 967,464
Commodity price risk management gain (loss), net	(68,061)	54,867	245,851	(87,858)
Other income	2,358	3,667	5,656	11,495
Total revenues	249,217	365,943	1,060,663	891,101
Costs, expenses and other:
Lease operating expenses	37,338	36,498	122,680	106,047
Production taxes	14,621	13,039	40,937	57,849
Transportation, gathering and processing expenses	24,399	10,999	54,844	34,631
Exploration, geologic and geophysical expense	162	209	1,026	3,492
General and administrative expense	32,490	41,091	130,007	123,497
Depreciation, depletion and amortization	144,504	171,839	470,152	491,784
Accretion of asset retirement obligations	2,420	1,356	7,398	4,503
Impairment of properties and equipment	1,221	167	882,327	37,021
Loss (gain) on sale of properties and equipment	(289)	43,872	(642)	9,599
Other expenses	1,936	2,492	6,083	8,882
Total cost, expenses and other	258,802	321,562	1,714,812	877,305
Income (loss) from operations	(9,585)	44,381	(654,149)	13,796
Interest expense	(21,022)	(17,811)	(66,977)	(53,679)
Income (loss) before income taxes	(30,607)	26,570	(721,126)	(39,883)
Income tax (expense) benefit	(176)	(10,662)	3,496	4,163
Net income (loss)	$ (30,783)	$ 15,908	$ (717,630)	$ (35,720)
Earnings per share:
Basic	$ (0.31)	$ 0.25	$ (7.34)	$ (0.55)
Diluted	$ (0.31)	$ 0.25	$ (7.34)	$ (0.55)
Weighted-average common shares outstanding
Basic	99,617	62,547	97,762	64,835
Diluted	99,617	62,595	97,762	64,835

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Statement of Cash Flows [Abstract]
Net income (loss)	$ (717,630)	$ (35,720)
Adjustments to net income (loss) to reconcile to net cash provided by operating activities:
Net change in fair value of unsettled commodity derivatives	(18,338)	68,058
Depreciation, depletion and amortization	470,152	491,784
Impairment of properties and equipment	882,327	37,021
Accretion of asset retirement obligations	7,398	4,503
Non-cash stock-based compensation	17,441	18,124
Loss (gain) on sale of properties and equipment	(642)	9,599
Amortization of debt discount and issuance costs	12,546	10,139
Deferred income taxes	(2,431)	(4,389)
Other	1,950	2,761
Changes in assets and liabilities	(3,461)	49,092
Net cash from operating activities	649,312	650,972
Cash flows from investing activities:
Capital expenditures for development of crude oil and natural gas properties	(445,505)	(755,828)
Capital expenditures for other properties and equipment	(1,940)	(15,522)
Acquisition of crude oil and natural gas properties, including settlement adjustments	(139,812)	(12,445)
Proceeds from sale of properties and equipment	1,539	1,528
Proceeds from Divestiture of Businesses	1,796	202,046
Increase (Decrease) in Restricted Cash	0	8,001
Net cash from investing activities	(583,922)	(572,220)
Cash flows from financing activities:
Proceeds from revolving credit facility	1,485,600	1,300,000
Repayment of revolving credit facility	(1,204,600)	(1,235,500)
Proceeds from Secured Notes Payable	148,500	0
Payments of Debt Issuance Costs	6,197	53
Proceeds from (Repurchase of) Equity	(23,819)	(142,665)
Payments for Repurchase of Common Stock	(8,412)	(3,874)
Early Repayment of Senior Debt	452,153	0
Finance Lease, Principal Payments	(1,454)	(1,492)
Net cash from financing activities	(62,535)	(83,584)
Net change in cash, cash equivalents, and restricted cash	2,855	(4,832)
Cash, cash equivalents and restricted cash, beginning of period	963	9,399
Cash, cash equivalents and restricted cash, end of period	3,818	4,567
Cash payments (receipts) for:
Interest, net of capitalized interest	51,556	41,483
Income taxes	(204)	261
Non-cash investing and financing activities:
Change in accounts payable related to purchases of properties and equipment	31,403	32,943
Change in asset retirement obligation, with a corresponding change to crude oil and natural gas properties, net of disposals	$ 44,339	$ 13,493

Consolidated Statement of Equit

Consolidated Statement of Equity (Statement) - USD ($) $ in Thousands	Total	Parent [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock, Common [Member]	Retained Earnings [Member]	Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Shares, Issued							45,220
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent		$ 2,526,708	$ 661	$ 2,519,423		$ 8,727	$ (2,103)
Shares, Outstanding			66,148,609
Issuance of treasury shares			0				64,372
Purchase of treasury shares		(1,460)					$ (1,460)
Issuance of treasury shares		0	$ 0	2,547			$ (2,547)
Net income (loss)		(120,176)				(120,176)
Shares Issued, Shares, Share-based Payment Arrangement, after Forfeiture			48,254				0
Shares Issued, Value, Share-based Payment Arrangement, after Forfeiture		4,683	$ 1	4,682			$ 0
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation							(41,787)
Weighted Average Number of Shares Outstanding, Basic	64,835,000
Net income (loss)	$ (35,720)
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0
Shares, Issued							(22,635)
Stockholders' Equity Attributable to Parent		2,409,755	$ 662	2,521,558		(111,449)	$ (1,016)
Shares, Outstanding			66,196,863
Issuance of treasury shares			0				24,604
Purchase of treasury shares		(2,257)			$ (2,257)
Issuance of treasury shares			$ 0	995			$ (995)
Net income (loss)		68,548				68,548
Shares Issued, Shares, Share-based Payment Arrangement, after Forfeiture			148,040				0
Shares Issued, Value, Share-based Payment Arrangement, after Forfeiture		7,575	$ 1	7,574			$ 0
Treasury Stock, Shares, Retired			(2,182)				2,182
Treasury Stock, Retired, Cost Method, Amount				78	$ (78)
Stock Repurchased During Period, Shares					(3,136,406)
Stock Repurchased and Retired During Period, Shares			(2,822,259)		2,822,259
Stock Repurchased During Period, Value		(105,215)			$ (105,215)
Stock Repurchased and Retired During Period, Value			$ (28)	(94,085)	$ 94,113
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation					(54,784)
Shares, Issued							(364,780)
Stockholders' Equity Attributable to Parent		2,378,406	$ 635	2,433,974		(42,901)	$ (13,302)
Shares, Outstanding			63,520,462
Weighted Average Number of Shares Outstanding, Basic	62,547,000
Issuance of treasury shares			0				14,973
Purchase of treasury shares		(157)			$ (157)
Issuance of treasury shares		0	$ 0	614			$ (614)
Net income (loss)	$ 15,908	15,908				15,908
Shares Issued, Shares, Share-based Payment Arrangement, after Forfeiture			10,808				0
Shares Issued, Value, Share-based Payment Arrangement, after Forfeiture		5,866	$ 0	5,866			$ 0
Treasury Stock, Shares, Retired			(995)				995
Treasury Stock, Retired, Cost Method, Amount				32	$ (32)
Stock Repurchased During Period, Shares					(1,228,310)
Stock Repurchased and Retired During Period, Shares			(1,442,457)		1,442,457
Stock Repurchased During Period, Value		(40,268)			$ (40,268)
Stock Repurchased and Retired During Period, Value			$ (14)	(48,536)	$ 48,550
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation					(4,750)
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	32,000
Shares, Issued							139,415
Stockholders' Equity Attributable to Parent		2,359,755	$ 621	2,390,658		(26,993)	$ (4,531)
Shares, Outstanding			62,087,818
Shares, Issued							34,922
Stockholders' Equity Attributable to Parent	$ 2,335,507	2,335,507	$ 617	2,384,309		(47,945)	$ (1,474)
Shares, Outstanding			61,652,412
Issuance of treasury shares			0		69,327
Purchase of treasury shares		(7,693)			$ (7,693)
Issuance of treasury shares			$ 0	0	0
Net income (loss)		(465,015)				(465,015)
Stock Issued During Period, Shares, Acquisitions			39,182,045
Stock Issued During Period, Value, Acquisitions		1,015,312	$ (391)	1,014,921
Shares Issued, Shares, Share-based Payment Arrangement, after Forfeiture			120,952				0
Shares Issued, Value, Share-based Payment Arrangement, after Forfeiture		(5,672)	$ 1	(3,713)			$ 1,958
Treasury Stock, Shares, Retired			(251,287)				251,287
Treasury Stock, Retired, Cost Method, Amount			$ (3)	6,425	$ (6,428)
Stock Repurchased During Period, Shares					(1,266,000)
Stock Repurchased and Retired During Period, Shares			(1,266,000)		1,266,000
Stock Repurchased During Period, Value		(23,819)			$ (23,819)
Stock Repurchased and Retired During Period, Value			$ (12)	(23,807)	$ 23,819
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation					(306,185)
Weighted Average Number of Shares Outstanding, Basic	97,762,000
Net income (loss)	$ (717,630)
Stock Repurchased During Period, Shares					1,300,000
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0
Shares, Issued							(20,493)
Stockholders' Equity Attributable to Parent		2,859,964	$ 994	3,372,711		(512,960)	$ (781)
Shares, Outstanding			99,438,122
Issuance of treasury shares			0				12,200
Purchase of treasury shares		(487)			$ (487)
Issuance of treasury shares		0	$ 0	0			$ 0
Net income (loss)		(221,832)				(221,832)
Shares Issued, Shares, Share-based Payment Arrangement, after Forfeiture			212,809				0
Shares Issued, Value, Share-based Payment Arrangement, after Forfeiture		6,364	$ 2	6,164			$ 198
Treasury Stock, Shares, Retired			(39,374)				39,374
Treasury Stock, Retired, Cost Method, Amount				322	$ (322)
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation					(64,219)
Shares, Issued							33,138
Stockholders' Equity Attributable to Parent		2,644,009	$ 996	3,378,553		(734,792)	$ (748)
Shares, Outstanding			99,611,557
Weighted Average Number of Shares Outstanding, Basic	99,617,000
Issuance of treasury shares			0				23,974
Purchase of treasury shares		(232)			$ (232)
Issuance of treasury shares		0	$ 0	0			$ 0
Net income (loss)	$ (30,783)	(30,783)				(30,783)
Shares Issued, Shares, Share-based Payment Arrangement, after Forfeiture			36,826				0
Shares Issued, Value, Share-based Payment Arrangement, after Forfeiture		5,405	$ 0	5,216			$ 189
Treasury Stock, Shares, Retired			(8,656)				8,656
Treasury Stock, Retired, Cost Method, Amount				121	$ (121)
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation					(16,642)
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0
Shares, Issued							17,150
Stockholders' Equity Attributable to Parent	$ 2,618,399	$ 2,618,399	$ 996	$ 3,383,648		$ (765,575)	$ (670)
Shares, Outstanding			99,639,727

NATURE OF OPERATIONS AND BASIS

NATURE OF OPERATIONS AND BASIS OF PRESENTATION	9 Months Ended
	Sep. 30, 2020
NATURE OF OPERATIONS AND BASIS OF PRESENTATION [Abstract]
Nature of Operations	NATURE OF OPERATIONS AND BASIS OF PRESENTATION PDC Energy, Inc. is a domestic independent exploration and production company that acquires, explores and develops properties for the production of crude oil, natural gas and NGLs, with operations in the Wattenberg Field in Colorado and the Delaware Basin in Texas. Our operations in the Wattenberg Field are focused in the horizontal Niobrara and Codell plays and our Delaware Basin operations are primarily focused in the Wolfcamp zones. As of September 30, 2020, we owned an interest in approximately 3,800 gross productive wells. The accompanying unaudited condensed consolidated financial statements include the accounts of PDC and our wholly-owned subsidiaries. All material intercompany accounts and transactions have been eliminated in consolidation. In our opinion, the accompanying condensed consolidated financial statements contain all adjustments, consisting of normal recurring adjustments necessary for a fair presentation of our financial statements for interim periods in accordance with accounting principles generally accepted in the United States of America ("U.S. GAAP") and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in audited financial statements have been condensed or omitted. The December 31, 2019 condensed consolidated balance sheet data was derived from audited statements, but does not include all disclosures required by U.S. GAAP. The information presented in this Quarterly Report on Form 10-Q should be read in conjunction with our audited consolidated financial statements and notes thereto included in our 2019 Form 10-K. Our results of operations and cash flows for the nine months ended September 30, 2020 are not necessarily indicative of the results to be expected for the full year or any other future period.

Recent Accounting Standards

Recent Accounting Standards	9 Months Ended
	Sep. 30, 2020
Significant Accounting Policies [Abstract]
Significant Accounting Policies [Text Block]	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Recently Adopted Accounting Pronouncement In March 2020, the SEC adopted final rules that amend the financial disclosure requirements for subsidiary issuers and guarantors of registered debt securities in Rule 3-10 of Regulation S-X. The amended rules, which can be found under new Rule 13-01 of Regulation S-X, narrow the circumstances that require separate financial statements of subsidiary issuers and guarantors and streamline the alternative disclosures required in lieu of those statements. The amended rules allow registrants, among other things, to disclose summarized financial information of the issuer and guarantors on a combined basis and to present only the most recently completed fiscal year and subsequent year-to-date interim period. The rule replaces the requirement to provide condensed consolidating financial information with a requirement to present summarized financial information of the issuers and guarantors. These disclosures may be provided outside the notes to the condensed consolidated financial statements. The rule is effective in the first quarter of 2021, with earlier adoption permitted. We early adopted the rule in the first quarter of 2020 and have provided these disclosures outside the notes to the condensed consolidated financial statements. Recently Issued Accounting Pronouncement but Not Yet Adopted In August 2020, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2020-06, Debt - Debt with conversion and other options and derivatives and hedging on contracts in entity's own equity. Amendments in this ASU simplify accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity's own equity. The amendments remove the separation models for convertible debt instruments with cash conversion features and convertible instruments with beneficial conversion features. Consequently, a convertible debt instrument will be accounted for as a single liability measured at its amortized cost and convertible preferred stock will be accounted for as a single equity instrument measured at its historical cost as long as no other features require bifurcation and recognition as derivatives. The amendments also modify the accounting for certain contracts in an entity's own equity that are currently accounted for as derivatives because of specific settlement provisions. Lastly, the earnings per share ("EPS") calculation is being amended to (i) require entities to use the if-converted method for all convertible instruments and include the effect of potential share settlement; (ii) clarify that the average market price for the period should be used in the computation of the diluted EPS denominator; and (iii) require entities to use the weighted-average share count from each quarter when calculating the year-to-date weighted average share count for all potentially dilutive securities. The amendments in this ASU are effective for fiscal years beginning after December 31, 2021, including interim periods within those fiscal years and early adoption is permitted. We are in the process of evaluating the potential impact of adopting this ASU and we do not expect to adopt the amendments early.

Business Combination (Notes)

Business Combination (Notes)	9 Months Ended
	Sep. 30, 2020
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	BUSINESS COMBINATION In January 2020, we merged with SRC in a transaction valued at $1.7 billion, inclusive of SRC's net debt (the "SRC Acquisition"). Upon closing, we issued approximately 39 million shares of our common stock to SRC shareholders and holders of SRC equity awards, reflecting the issuance of 0.158 of a share of our common stock in exchange for each outstanding share of SRC common stock and the cancellation of outstanding SRC equity awards pursuant to the merger agreement that we entered into with SRC (the "Merger Agreement"). During the nine months ended September 30, 2020, we recorded transaction costs related to the SRC Acquisition of $20.2 million. These expenses were accounted for separately from the assets and liabilities assumed and are included in general and administrative expense in the condensed consolidated statements of operations. The details of the estimated purchase price and the preliminary allocation of the purchase price are as follows: Nine Months Ended September 30, 2020 (in thousands) Consideration: Cash $ 40 Retirement of seller's credit facility 166,238 Total cash consideration 166,278 Common stock issued 1,009,015 Shares withheld in lieu of taxes 6,299 Total consideration $ 1,181,592 Recognized amounts of identifiable assets acquired and liabilities assumed: Assets acquired: Current assets $ 149,538 Properties and equipment, net - proved 1,607,175 Properties and equipment, net - unproved 109,615 Properties and equipment, net - other 16,242 Deferred tax asset 193,410 Other assets 13,266 Total assets acquired 2,089,246 Liabilities assumed: Current liabilities (257,285) Senior notes (555,500) Asset retirement obligations (41,901) Other liabilities (52,968) Total liabilities assumed (907,654) Total identifiable net assets acquired $ 1,181,592 This acquisition was accounted for under the acquisition method of accounting for business combinations. Accordingly, we conducted assessments of the net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values, while transaction and integration costs associated with the acquisition were expensed as incurred. The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market, and therefore represent Level 3 inputs. The fair values of crude oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of proved and unproved crude oil and natural gas properties include estimates of reserves, future operating and development costs, future commodity prices, estimated future cash flows, lease terms and expirations and a market-based weighted-average cost of capital rate of 10 percent. These inputs require significant judgments and estimates by management at the time of the valuation. As of the date of this report, we expect that the measurement period will extend into the fourth quarter of 2020, and the value of the assets and liabilities may be revised as appropriate. The results of operations for the SRC Acquisition since the closing date have been included in our condensed consolidated financial statements for the three and nine months ended September 30, 2020 and include approximately $82.0 million and $233.8 million of total revenue, respectively, and $20.7 million and $19.3 million of loss from operations for the three and nine months ended September 30, 2020, respectively. Pro Forma Information. The following unaudited pro forma financial information represents a summary of the consolidated results of operations for the nine months ended September 30, 2020 and for the three and nine months ended September 30, 2019, assuming the acquisition had been completed as of January 1, 2019. The financial information for the three months ended September 30, 2020 is included in our condensed consolidated statements of operations and therefore does not require a pro forma disclosure. The pro forma amounts for the nine months ended September 30, 2020 include an immaterial non-recurring adjustment which was not included in our pro forma information disclosed in our six months ended June 30, 2020 and our three months ended March 31, 2020 footnotes. The pro forma financial information includes certain non-recurring pro forma adjustments that were directly attributable to the business combination. The pro forma financial information is not necessarily indicative of the results of operations that would have been achieved if the acquisition had been effective as of these dates, or of future results. Three Months Ended September 30, Nine Months Ended September 30, 2019 2020 2019 (in thousands, except per share data) Total revenue $ 511,110 $ 1,082,003 $ 1,373,739 Net income (loss) 63,092 (677,636) 128,337 Earnings (loss) per share: Basic $ 0.62 $ (6.79) $ 1.23 Diluted 0.62 (6.79) 1.23

Revenue Recognition (Notes)

Revenue Recognition (Notes)	9 Months Ended
	Sep. 30, 2020
Revenue Recognition and Deferred Revenue [Abstract]
Revenue from Contract with Customer [Text Block]	REVENUE RECOGNITION Crude oil, natural gas and NGLs revenues are recognized when we have transferred control of crude oil, natural gas or NGLs production to the purchaser. We consider the transfer of control to have occurred when the purchaser has the ability to direct the use of, and obtain substantially all of the remaining benefits from, the crude oil, natural gas or NGLs production. We record sales revenue based on an estimate of the volumes delivered at estimated prices as determined by the applicable sales agreement. We estimate our sales volumes based on company-measured volume readings. We then adjust our crude oil, natural gas and NGLs sales in subsequent periods based on the data received from our purchasers that reflects actual volumes delivered and prices received. We receive payment for sales one to two months after actual delivery has occurred. The differences in sales estimates and actual sales are recorded one to two months later. Historically, these differences have not been material. Disaggregated Revenue. The following table presents crude oil, natural gas and NGLs sales disaggregated by commodity and operating region for the three and nine months ended September 30, 2020 and 2019: Three Months Ended September 30, Nine Months Ended September 30, Revenue by Commodity and Operating Region 2020 2019 Percent Change 2020 2019 Percent Change (in thousands) Crude oil Wattenberg Field $ 183,420 $ 185,543 (1.1) % $ 483,608 $ 569,518 (15.1) % Delaware Basin 42,591 70,175 (39.3) % 107,347 191,452 (43.9) % Total $ 226,011 $ 255,718 (11.6) % $ 590,955 $ 760,970 (22.3) % Natural gas Wattenberg Field $ 39,759 $ 23,949 66.0 % $ 109,279 $ 100,779 8.4 % Delaware Basin 2,140 2,613 (18.1) % 3,183 9,293 (65.7) % Total $ 41,899 $ 26,562 57.7 % $ 112,462 $ 110,072 2.2 % NGLs Wattenberg Field $ 38,871 $ 16,906 129.9 % $ 86,875 $ 67,305 29.1 % Delaware Basin 8,139 8,223 (1.0) % 18,864 29,117 (35.2) % Total $ 47,010 $ 25,129 87.1 % $ 105,739 $ 96,422 9.7 % Crude oil, natural gas and NGLs Wattenberg Field $ 262,050 $ 226,398 15.7 % $ 679,762 $ 737,602 (7.8) % Delaware Basin 52,870 81,011 (34.7) % 129,394 229,862 (43.7) % Total $ 314,920 $ 307,409 2.4 % $ 809,156 $ 967,464 (16.4) % Contract Assets. Contract assets include material contributions in aid of construction, which are common in purchase and processing agreements with midstream service providers that are our customers. The intent of the payments is primarily to reimburse the customer for actual costs incurred related to the construction of its gathering and processing infrastructure. Contract assets are included in other assets in the condensed consolidated balance sheet. The contract assets are amortized as a reduction to crude oil, natural gas and NGLs sales revenue during the periods in which the related production is transferred to the customer. The following table presents the changes in carrying amounts of the contract assets associated with our crude oil, natural gas and NGLs sales revenue for the nine months ended September 30, 2020: Amount (in thousands) Beginning balance, January 1, 2020 $ 11,494 Additions 15,627 Amortized as a reduction to crude oil, natural gas and NGLs sales (1,588) Ending balance, September 30, 2020 $ 25,533

Fair Value Measurements and Dis

Fair Value Measurements and Disclosures	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Fair Value, Measurement Inputs, Disclosure	FAIR VALUE OF FINANCIAL INSTRUMENTS Determination of Fair Value Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Our fair value measurements are estimated pursuant to a fair value hierarchy that requires us to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date, giving the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability, and may affect the valuation of the assets and liabilities and their placement within the fair value hierarchy levels. The three levels of inputs that may be used to measure fair value are defined as: Level 1 – Quoted prices (unadjusted) for identical assets or liabilities in active markets. Level 2 – Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived from observable market data by correlation or other means. Level 3 – Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity. Derivative Financial Instruments We measure the fair value of our derivative instruments based upon a pricing model that utilizes market-based inputs, including, but not limited to, the contractual price of the underlying position, current market prices, crude oil and natural gas forward curves, discount rates such as the LIBOR curve for a similar duration of each outstanding position, volatility factors and nonperformance risk. Nonperformance risk considers the effect of our credit standing on the fair value of derivative liabilities and the effect of our counterparties' credit standings on the fair value of derivative assets. Both inputs to the model are based on published credit default swap rates and the duration of each outstanding derivative position. We validate our fair value measurement by corroborating the original source of inputs, monitoring changes in valuation methods and assumptions and through the review of counterparty statements and other supporting documentation. Our crude oil and natural gas fixed-price swaps are included in Level 2. Our collars are included in Level 3. Our basis swaps are included in Level 2 and Level 3. The following table presents, for each applicable level within the fair value hierarchy, our derivative assets and liabilities, including both current and non-current portions, measured at fair value on a recurring basis: As of September 30, 2020 As of December 31, 2019 Significant Other Significant Total Significant Other Significant Total (in thousands) Total assets $ 130,134 $ 21,545 $ 151,679 $ 22,886 $ 8,938 $ 31,824 Total liabilities (79,658) (30,759) (110,417) (3,089) (524) (3,613) Net derivative instruments $ 50,476 $ (9,214) $ 41,262 $ 19,797 $ 8,414 $ 28,211 The following table presents a reconciliation of our Level 3 assets measured at fair value: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Fair value of Level 3 instruments, net asset beginning of period $ 26,958 $ 22,504 $ 8,414 $ 58,329 Changes in fair value included in condensed consolidated statement of operations line item: Commodity price risk management gain (loss), net (21,521) 10,846 32,840 (22,077) Settlements included in condensed consolidated statement of operations line items: Commodity price risk management loss, net (14,652) (2,445) (50,469) (5,347) Fair value of Level 3 instruments, net asset end of period $ (9,215) $ 30,905 $ (9,215) $ 30,905 Net change in fair value of Level 3 unsettled derivatives included in condensed consolidated statement of operations line item: Commodity price risk management gain (loss), net $ (13,171) $ 6,787 $ 9,466 $ (11,620) The significant unobservable input used in the fair value measurement of our derivative contracts is the implied volatility curve, which is provided by a third-party vendor. A significant increase or decrease in the implied volatility, in isolation, would have a directionally similar effect resulting in a significantly higher or lower fair value measurement of our Level 3 derivative contracts. There has been no change in the methodology we apply to measure the fair value of our Level 3 derivative contracts during the periods covered by the financial statements. Non-Derivative Financial Assets and Liabilities We utilize fair value on a nonrecurring basis to review our proved crude oil and natural gas properties for possible impairment when events and circumstances indicate a possible decline in the recoverability of the carrying value of such assets. The fair value of the properties is determined based upon estimated future discounted cash flow, a Level 3 input, using estimated production and prices at which we reasonably expect the crude oil and natural gas will be sold. Unobservable inputs include estimated future crude oil and natural gas production, forward strip commodity pricing curves (adjusted for basis differentials), operating and development costs, future development plans and a discount rate of 17 percent, which was based on a weighted-average cost of capital for the area for which the assets are located (all of which were designated as Level 3 inputs within the fair value hierarchy). The portion of our long-term debt related to our revolving credit facility approximates fair value, as the applicable interest rates are variable and reflective of market rates. We have not elected to account for the portion of our debt related to our senior notes under the fair value option; however, we have determined an estimate of the fair values based on measurements of trading activity and broker and/or dealer quotes, respectively, which are published market prices, and therefore are Level 2 inputs. The table below presents these estimates of the fair value of the portion of our long-term debt related to our senior notes and convertible notes. As of September 30, 2020 As of December 31, 2019 Estimated Fair Value Percent of Par Estimated Fair Value Percent of Par (in millions) Senior Notes: 2021 Convertible Notes $ 192.6 96.3 % $ 188.6 94.3 % 2024 Senior Notes 382.8 95.7 % 409.2 102.3 % 2025 Senior Notes 96.1 93.9 % — — % 2026 Senior Notes (1) 696.8 92.9 % 599.4 99.9 % _____________ (1) Includes additional $150.0 million aggregate principal amount of 2026 Senior Notes issued in September 2020. For further discussion see footnote titled Long-term Debt. The carrying value of the financial instruments included in current assets and current liabilities approximate their fair values due to the short-term maturities of these instruments. Concentration of Risk Derivative Counterparties. A portion of our liquidity relates to commodity derivative instruments that enable us to manage a portion of our exposure to price volatility from producing crude oil and natural gas. These arrangements expose us to credit risk of nonperformance by our counterparties. We primarily use financial institutions who are also lenders under our revolving credit facility as counterparties to our commodity derivative contracts. To date, we have had no derivative counterparty default losses. We have evaluated the credit risk of our derivative assets from our counterparties using relevant credit market default rates, giving consideration to amounts outstanding for each counterparty and the duration of each outstanding derivative position. Based on our evaluation, we have determined that the potential impact of nonperformance of our current counterparties on the fair value of our derivative instruments is not significant at September 30, 2020; however, this determination may change. Cash and Cash Equivalents. We consider all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. Cash and cash equivalents potentially subject us to a concentration of credit risk as substantially all of our deposits held in financial institutions were in excess of the FDIC insurance limits at September 30, 2020 and December 31, 2019. We maintain our cash and cash equivalents in the form of money market and checking accounts with financial institutions that we believe are creditworthy and are also lenders under our revolving credit facility.

Derivative Financial Instrument

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2020
Derivative Instruments Not Designated as Hedging Instruments [Abstract]
Derivative Instruments and Hedging Activities Disclosure [Text Block]	COMMODITY DERIVATIVE FINANCIAL INSTRUMENTS Our results of operations and operating cash flows are affected by changes in market prices for crude oil, natural gas and NGLs. To manage a portion of our exposure to price volatility from producing crude oil and natural gas we enter into commodity derivative contracts such as collars, fixed-price swaps and basis protection swaps, to protect against price declines in future periods. We do not enter into derivative contracts for speculative or trading purposes. Collars are designed to establish floor and ceiling prices on anticipated future oil or gas production, while swaps establish a fixed price for anticipated future oil or gas production. While we structure these commodity derivatives to reduce our exposure to decreases in commodity prices, they also limit the benefit we might otherwise receive from price increases. We believe our commodity derivative instruments continue to be effective in achieving the risk management objectives for which they were intended. Depending on changes in oil and gas futures markets and management’s view of underlying supply and demand trends, we may increase or decrease our derivative positions from current levels. As of September 30, 2020, we had derivative instruments in place for a portion of our anticipated 2020, 2021 and 2022 production. Our commodity derivative contracts have been entered into at no upfront cost to us as we hedge our anticipated production at the then-prevailing commodity market prices, without adjustment for premium or discount. As of September 30, 2020, we had the following outstanding derivative contracts. When aggregating multiple contracts, the weighted-average contract price is shown. Collars Fixed-Price Swaps Commodity/ Index/ Quantity (Crude oil - MBbls Natural Gas - BBtu) Weighted-Average Quantity (Crude Oil - MBbls Gas and Basis- BBtu) Weighted- Fair Value September 30, 2020 (1) (in thousands) Floors Ceilings Crude Oil NYMEX 2020 900 $ 55.00 $ 71.68 3,174 $ 58.90 $ 71,119 2021 996 35.00 46.22 9,180 46.90 40,547 2022 — — — 3,984 40.01 (13,433) Total Crude Oil 1,896 16,338 $ 98,233 Natural Gas NYMEX 2020 17,308 $ 2.02 $ 2.34 1,000 $ 2.30 $ (6,576) 2021 62,625 2.46 2.86 31,800 2.40 (31,070) 2022 8,700 2.50 2.79 8,700 2.62 (21) Total Natural Gas 88,633 41,500 $ (37,667) Basis Protection - Natural Gas CIG 2020 — $ — $ — 17,350 $ (0.48) $ (4,627) 2021 — — — 94,425 (0.46) (13,433) 2022 — — — 17,400 (0.36) (733) Waha 2020 — — — 1,000 (1.40) (511) Total Basis Protection - Natural Gas — 130,175 $ (19,304) Commodity Derivatives Fair Value $ 41,262 _____________ (1) Approximately 14 percent of the fair value of our commodity derivative assets and 28 percent of the fair value of our commodity derivative liabilities were measured using significant unobservable inputs (Level 3). Subsequent to September 30, 2020, we entered into the following commodity derivative positions covering our natural gas production: Collars Fixed-Price Swaps Commodity/ Index/ Quantity (BBtu) Weighted-Average Quantity (BBtu) Weighted- Floors Ceilings NYMEX 2022 8,700 $ 2.50 $ 3.00 — — Basis Protection CIG 2022 — — — 8,700 $ (0.31) We have not elected to designate any of our derivative instruments as cash flow hedges; therefore, these instruments do not qualify for hedge accounting. Accordingly, changes in the fair value of our derivative instruments are recorded in the condensed consolidated statements of operations. The following table presents the condensed consolidated balance sheet line item and fair value amounts of our derivative instruments as of September 30, 2020 and December 31, 2019: Fair Value Derivative Instruments: Condensed Consolidated Balance Sheet Line Item September 30, 2020 December 31, 2019 (in thousands) Derivative assets: Current Commodity derivative contracts Fair value of derivatives $ 138,652 $ 27,766 Basis protection derivative contracts Fair value of derivatives — 312 138,652 28,078 Non-current Commodity derivative contracts Fair value of derivatives 13,027 3,746 Total derivative assets $ 151,679 $ 31,824 Derivative liabilities: Current Commodity derivative contracts Fair value of derivatives $ 50,969 $ 529 Basis protection derivative contracts Fair value of derivatives 12,988 2,392 63,957 2,921 Non-current Commodity derivative contracts Fair value of derivatives 40,144 692 Basis protection derivative contracts Fair value of derivatives 6,316 — 46,460 692 Total derivative liabilities $ 110,417 $ 3,613 The following table presents the impact of our derivative instruments on our condensed consolidated statements of operations: Three Months Ended September 30, Nine Months Ended September 30, Condensed Consolidated Statement of Operations Line Item 2020 2019 2020 2019 (in thousands) Commodity price risk management gain (loss), net Net settlements $ 66,895 $ 1,845 $ 227,513 $ (19,800) Net change in fair value of unsettled derivatives (134,956) 53,022 18,338 (68,058) Total commodity price risk management gain (loss), net $ (68,061) $ 54,867 $ 245,851 $ (87,858) Our financial derivative agreements contain master netting provisions that provide for the net settlement of contracts through a single payment in the event of early termination. We have elected not to offset the fair value positions recorded on our condensed consolidated balance sheets. The following table reflects the impact of netting agreements on gross derivative assets and liabilities: As of September 30, 2020 Derivative Instruments, Gross Effect of Master Netting Agreements Derivative Instruments, Net (in thousands) Derivative assets: Derivative instruments, at fair value $ 151,679 $ (51,823) $ 99,856 Derivative liabilities: Derivative instruments, at fair value $ 110,417 $ (51,823) $ 58,594 As of December 31, 2019 Derivative Instruments, Gross Effect of Master Netting Agreements Derivative Instruments, Net (in thousands) Derivative assets: Derivative instruments, at fair value $ 31,824 $ (2,619) $ 29,205 Derivative liabilities: Derivative instruments, at fair value $ 3,613 $ (2,619) $ 994

Properties and Equipment

Properties and Equipment	9 Months Ended
	Sep. 30, 2020
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment Disclosure	PROPERTIES AND EQUIPMENT The following table presents the components of properties and equipment, net of accumulated depreciation, depletion and amortization ("DD&A"): September 30, 2020 December 31, 2019 (in thousands) Properties and equipment, net: Crude oil and natural gas properties Proved $ 7,389,676 $ 6,241,780 Unproved 381,428 403,379 Total crude oil and natural gas properties 7,771,104 6,645,159 Equipment and other 65,256 41,888 Land and buildings 24,859 12,312 Construction in progress 505,930 408,428 Properties and equipment, at cost 8,367,149 7,107,787 Accumulated DD&A (3,481,915) (3,012,585) Properties and equipment, net $ 4,885,234 $ 4,095,202 Impairment Charges. During the three months ended March 31, 2020, we recorded impairment charges of $881.1 million. The impairment charges during the three months ended March 31, 2020 were due to a significant decline in crude oil prices, which was considered a triggering event that required us to assess our crude oil and natural gas properties for possible impairment. As a result of our assessment, we recorded impairment charges of $881.1 million to our proved and unproved properties. Of these impairment charges, approximately $753.0 million was related to our Delaware Basin proved properties. These impairment charges represented the amount by which the carrying value of the crude oil and natural gas properties exceeded the estimated fair value. The estimated fair value was determined based on estimated future discounted net cash flows, a Level 3 input, using estimated production and realized prices at which we reasonably expect the crude oil and natural gas will be sold. In addition to our proved property impairment, we also recognized approximately $127.3 million of impairment charges for our unproved properties in the Delaware Basin. These impairment charges were recognized based on a review of our current drilling plans, estimated future cash flows for probable well locations and expected future lease expirations, primarily in areas where we have no development plans. There were no triggering events identified as of June 30 and September 30, 2020 and therefore we did not recognize any significant impairment write-downs with respect to our proved and unproved properties for the second and third quarter of 2020. During the nine months ended September 30, 2019, we recorded impairment charges totaling $10.3 million, including $0.1 million during the three months ended September 30, 2019 related to leaseholds and leasehold expirations within our non-focus areas of the Delaware Basin where we were no longer pursuing plans to develop the properties. During the nine months ended September 30, 2019, we also recorded impairments of $26.7 million related to certain midstream facility infrastructure in the Delaware Basin. We determined the fair value of the properties based upon estimated future discounted cash flow, a Level 3 input, using estimated production and prices at which we reasonably expect the crude oil and natural gas will be sold. Midstream Asset Divestitures. During the second quarter of 2019, we completed the sales of our Delaware Basin produced water gathering and disposal, crude oil gathering and natural gas gathering assets (the "Midstream Asset Divestitures") for aggregate proceeds of $345.6 million. The proceeds were received upon closing, with the exception of $82.0 million that we received in June 2020. Concurrent with the Midstream Asset Divestitures, we entered into agreements with the purchasers which provide us with certain gathering, processing, transportation and water disposal services. See footnote titled Other Accrued Expenses and Other Liabilities for further details regarding these agreements. Proceeds were allocated first to the assets sold based upon the fair values of the tangible assets sold, with the remainder of $179.6 million allocated to the acreage dedication agreements. We recorded an aggregate gain on the sale of $34.0 million based on the fair value of the tangible assets sold. Suspended Well Costs. The following table presents the capitalized exploratory well cost pending determination of proved reserves and included in properties and equipment, net on the condensed consolidated balance sheets: Nine Months Ended September 30, Year Ended December 31, 2019 (in thousands, except for number of wells) Beginning balance $ 16,078 $ 12,188 Additions to capitalized exploratory well costs pending the determination of proved reserves 11,540 31,901 Reclassifications to proved properties (20,392) (28,011) Ending balance $ 7,226 $ 16,078 Number of wells pending determination at period-end 2 4 During nine months ended September 30, 2020, two wells classified as exploratory at December 31, 2019 were reclassified as productive and no new wells drilled were classified as exploratory.

Other Accrued Expenses and Othe

Other Accrued Expenses and Other Liabilities (Notes)	9 Months Ended
	Sep. 30, 2020
Accrued Liabilities and Other Liabilities [Abstract]
Other Income and Other Expense Disclosure [Text Block]	OTHER ACCRUED EXPENSES AND OTHER LIABILITIES Other Accrued Expenses. The following table presents the components of other accrued expenses as of: September 30, 2020 December 31, 2019 (in thousands) Employee benefits $ 19,833 $ 21,611 Asset retirement obligations 30,348 32,200 Environmental expenses 11,988 2,256 Operating and finance leases 8,809 5,926 Other 10,914 8,469 Other accrued expenses $ 81,892 $ 70,462 Other Liabilities. The following table presents the components of other liabilities as of: September 30, 2020 December 31, 2019 (in thousands) Production taxes $ 46,500 $ 68,020 Deferred oil gathering credits 18,593 20,100 Deferred midstream gathering credits 170,508 175,897 Operating and finance leases 12,494 15,779 Other 2,440 3,337 Other liabilities $ 250,535 $ 283,133 Deferred Oil Gathering Credits. In 2018, we entered into an agreement that dedicates crude oil production from the majority of our Wattenberg Field acreage to the midstream provider's gathering lines and extends the term of the agreement through December 2029. The acreage dedication agreement resulted in an initial cash receipt and is being amortized over the life of the agreement. Amortization charges related to this deferred oil gathering credit totaling approximately $0.5 million for each of the three months ended September 30, 2020 and 2019 and $1.5 million for each of the nine months ended September 30, 2020 and 2019, are included as a reduction to transportation, gathering and processing expenses. Deferred Midstream Gathering Credits. In the second quarter of 2019, concurrent with the sale of our Delaware Basin midstream assets, we entered into agreements with the purchasers that dedicated the gathering of certain of our production and all water gathering and disposal volumes in the Delaware Basin. The terms of these agreements range from 10 to 22 years. The acreage dedication agreements resulted in initial cash receipts and are being amortized on a units-of-production basis. The amortization rates are assessed on an annual basis for changes in estimated future production. The following table presents the amortization charges recognized in the condensed consolidated statements of operations for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Crude oil, natural gas and NGL sales (1) $ — $ 201 $ 368 $ 259 Transportation, gathering and processing expenses 1,535 711 2,991 914 Lease operating expenses 686 373 1,458 557

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Long-term Debt	LONG-TERM DEBT Long-term debt consisted of the following as of: September 30, 2020 December 31, 2019 (in thousands) Senior Notes: 1.125% Convertible Notes due September 2021: Principal amount $ 200,000 $ 200,000 Unamortized discount (8,458) (14,763) Unamortized debt issuance costs (934) (1,666) Net of unamortized discount and debt issuance costs 190,608 183,571 6.125% Senior Notes due September 2024: Principal amount 400,000 400,000 Unamortized debt issuance costs (3,876) (4,611) Net of unamortized debt issuance costs 396,124 395,389 6.25% Senior Notes due December 2025: Principal amount 102,324 — Unamortized premium 914 — Net of unamortized premium 103,238 — 5.75% Senior Notes due May 2026: Principal amount 750,000 600,000 Unamortized discount (1,490) — Unamortized debt issuance costs (6,873) (5,734) Net of unamortized discount and debt issuance costs 741,637 594,266 Total senior notes 1,431,607 1,173,226 Revolving Credit Facility: Revolving credit facility due May 2023 285,000 4,000 Total debt, net of unamortized discount and premium and debt issuance costs 1,716,607 1,177,226 Less current portion of long-term debt 190,608 — Long-term debt $ 1,525,999 $ 1,177,226 Senior Notes 2021 Convertible Notes. In September 2016, we issued $200 million of 1.125% convertible notes due September 15, 2021 (the "2021 Convertible Notes"). Interest is payable semi-annually on March 15 and September 15. The conversion price at maturity is $85.39 per share. We allocated the gross proceeds of the 2021 Convertible Notes between the liability and equity components of the debt. The initial $160.5 million liability component was determined based on the fair value of similar debt instruments, excluding the conversion feature, priced on the same day we issued the 2021 Convertible Notes. The initial $39.5 million equity component represents the debt discount and was calculated as the difference between the fair value of the debt and the gross proceeds of the 2021 Convertible Notes. Approximately $4.8 million in costs associated with the issuance of the 2021 Convertible Notes were capitalized as debt issuance costs and are being amortized as interest expense over the life of the notes. Upon conversion, the 2021 Convertible Notes may be settled, at our sole election, in shares of our common stock, cash or a combination thereof. We have initially elected a combination settlement method to satisfy our conversion obligation, which allows us to settle the principal amount of the 2021 Convertible Notes in cash and to settle the excess conversion value, if any, in shares, as well as cash in lieu of fractional shares. 2024 Senior Notes. In September 2016, we issued $400 million aggregate principal amount of 6.125% senior notes due September 15, 2024 (the “2024 Senior Notes”). Interest is payable semi-annually on March 15 and September 15. Approximately $7.8 million in costs associated with the issuance of the 2024 Senior Notes were capitalized as debt issuance costs and are being amortized as interest expense over the life of the notes. 2025 Senior Notes. Upon completion of the SRC Acquisition in January 2020, we assumed $550 million aggregate principal amount of 6.25% senior notes due December 1, 2025 (the "2025 Senior Notes"). The 2025 Senior Notes were recorded at $555.5 million, representing the approximate fair value. The difference between the acquisition date fair value and the principal amount of the 2025 Senior Notes will be recognized as a reduction to interest expense over the remaining life of the notes. Interest is payable semi-annually on June 1 and December 1. On January 17, 2020, we commenced an offer to repurchase the 2025 Senior Notes from the holders at 101 percent of the principal amount of the 2025 Senior Notes, together with any accrued and unpaid interest. Upon expiration of the repurchase offer on February 18, 2020, holders of $447.7 million of the outstanding 2025 Senior Notes accepted the redemption offer for a total redemption price of approximately $452.2 million, plus accrued and unpaid interest of $6.2 million. The fair value of the 2025 Senior Notes approximated the repurchase offer price, resulting in recognition of an immaterial loss on extinguishment of the repurchased notes. The repurchase was funded by proceeds from our revolving credit facility. An aggregate principal amount of approximately $102.3 million remains outstanding. 2026 Senior Notes. In November 2017, we issued $600.0 million aggregate principal amount of 5.75% senior notes due May 15, 2026 (the "2026 Senior Notes"). Interest is payable semi-annually on May 15 and November 15. Approximately $7.6 million in costs associated with the issuance of the 2026 Senior Notes were capitalized as debt issuance costs and are being amortized as interest expense over the life of the notes. In September 2020, we issued an additional $150.0 million aggregate principal amount of the 2026 Senior Notes at a price equal to 99 percent of par, which resulted in net proceeds of $146.7 million, after deducting the original issuance discount of $1.5 million and debt issuance costs of $1.8 million. The additional 2026 Senior Notes issued have the same terms and conditions as the existing 2026 Senior Notes. Our wholly-owned subsidiary, PDC Permian, Inc., is a guarantor of our obligations under the 2021 Convertible Notes, the 2024 Senior Notes, the 2025 Senior Notes and the 2026 Senior Notes (collectively, the "Notes"). As of September 30, 2020, we were in compliance with all covenants related to the Notes. Revolving Credit Facility In May 2018, we entered into a Fourth Amended and Restated Credit Agreement (the “Restated Credit Agreement”). Among other things, the Restated Credit Agreement provides for a maximum credit amount of $2.5 billion. The amount we may borrow under the Restated Credit Agreement is subject to certain limitations. As a result of closing the SRC Acquisition, the borrowing base on our revolving credit facility increased to $2.1 billion and we elected to increase the aggregate commitment amount under our revolving credit facility to $1.7 billion. On May 5, 2020, we entered into a Second Amendment to the Restated Credit Agreement (the “Second Amendment”) that amended our interest rate and certain other provisions in the Restated Credit Agreement. In October 2020, as part of our fall 2020 semi-annual redetermination, the borrowing base of our credit facility was reduced to $1.6 billion, with a corresponding automatic reduction to our elected commitments of $1.6 billion. The revolving credit facility is available for working capital requirements, capital investments, acquisitions, to support letters of credit and for general corporate purposes. The borrowing base is based on, among other things, the loan value assigned to the proved reserves attributable to our crude oil and natural gas interests. The borrowing base is subject to a semi-annual redetermination on November 1 and May 1 based upon quantification of our reserves at June 30 and December 31, and is also subject to a redetermination upon the occurrence of certain events. Substantially all of our crude oil and natural gas properties have been mortgaged or pledged as security for our revolving credit facility. The outstanding principal amount under the revolving credit facility accrues interest at a varying interest rate that fluctuates with an alternate base rate (equal to the greatest of the administrative agent's prime rate, the federal funds rate plus a premium and the rate for dollar deposits in the London interbank market (“LIBOR”) for one month, plus a premium) or, at our election, a rate equal to LIBOR for certain time periods. Additionally, commitment fees, interest margin and other bank fees, charged as a component of interest, vary with our utilization of the facility. As of September 30, 2020, the applicable interest margin is 0.75 percent for the alternate base rate option or 1.75 percent for the LIBOR option, and the unused commitment fee is 0.375 percent. Principal payments are generally not required until the revolving credit facility expires in May 2023, unless the borrowing base falls below the outstanding balance. The revolving credit facility contains covenants customary for agreements of this type, with the most restrictive being certain financial tests on a quarterly basis. The financial tests, as defined per the revolving credit facility, include requirements to: (a) maintain a minimum current ratio of 1.0:1.0 and (b) not exceed a maximum leverage ratio of 4.0:1.0. As of September 30, 2020, we were in compliance with all covenants related to the revolving credit facility.

Leases (Notes)

Leases (Notes)	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Lessee Operating and Financing Leases [Text Block]	LEASES We determine if an arrangement is representative of a lease at contract inception. Right-of-use ("ROU") assets represent our right to use the underlying assets for the lease term and the corresponding lease liabilities represent our obligations to make lease payments arising from the leases. Operating and finance lease ROU assets and liabilities are recognized at the commencement date based on the present value of the expected lease payments over the lease term. As most of our leases do not provide an implicit interest rate, we utilize our incremental borrowing rate based on information available at the commencement date in determining the present value of lease payments. Subsequent measurement, as well as presentation of expenses and cash flows, will depend upon the classification of the lease as either a finance or operating lease. Terms of our leases include options to extend or terminate the lease only when we can ascertain that it is reasonably certain we will exercise that option. We have operating leases for office space and compressors and finance leases for vehicles. Our leases have remaining lease terms ranging from one to five years. The vehicle leases include options to renew for up to four years. Lease payments associated with vehicle leases also include a contractually stated residual value guarantee. The following table presents the components of lease costs: Three Months Ended September 30, Nine Months Ended September 30, Lease Costs 2020 2019 2020 2019 (in thousands) Operating lease costs $ 2,030 $ 1,093 $ 5,842 $ 3,824 Finance lease costs: Amortization of ROU assets 473 506 1,462 1,493 Interest on lease liabilities 44 66 150 195 Total finance lease costs 517 572 1,612 1,688 Short-term lease costs 17,975 35,118 149,960 147,223 Total lease costs $ 20,522 $ 36,783 $ 157,414 $ 152,735 Our operating lease costs are recorded in lease operating expenses or general and administrative expense and our finance lease costs are recorded in DD&A expense and interest expense. Our short-term lease costs include amounts that are capitalized as part of the cost of another asset and are recorded as properties and equipment or recognized as expense. The following table presents the balance sheet classification and other information regarding our leases as of: Leases Condensed Consolidated Balance Sheet Line Item September 30, 2020 December 31, 2019 (in thousands) Operating Leases: Operating lease ROU assets Other assets $ 13,484 $ 14,926 Operating lease obligation - short-term Other accrued expenses 7,183 4,159 Operating lease obligation - long-term Other liabilities 10,496 12,944 Total operating lease liabilities $ 17,679 $ 17,103 Finance Leases: Finance lease ROU assets Properties and equipment, net $ 3,647 $ 4,637 Finance lease obligation - short-term Other accrued expenses 1,626 1,767 Finance lease obligation - long-term Other liabilities 1,998 2,835 Total finance lease liabilities $ 3,624 $ 4,602 Weighted-average remaining lease term (years) Operating leases 3.15 4.28 Finance leases 2.72 3.17 Weighted-average discount rate Operating leases 5.0 % 5.0 % Finance leases 5.0 % 5.0 % Maturity of lease liabilities by year and in the aggregate, under operating and financing leases with terms of one year or more, as of September 30, 2020 consist of the following: Operating Leases Finance Leases Total (in thousands) 2020 (remaining after September 30, 2020) $ 2,294 $ 496 $ 2,790 2021 7,055 1,580 8,635 2022 5,516 955 6,471 2023 1,559 669 2,228 2024 950 141 1,091 Thereafter 1,698 9 1,707 Total lease payments 19,072 3,850 22,922 Less interest and discount (1,393) (226) (1,619) Present value of lease liabilities $ 17,679 $ 3,624 $ 21,303

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure	ASSET RETIREMENT OBLIGATIONS The following table presents the changes in carrying amounts of the asset retirement obligations associated with our working interests in crude oil and natural gas properties: Amount (in thousands) Balance at December 31, 2019 $ 127,251 Obligations incurred with development activities and other 7,588 Obligations incurred with acquisition 47,158 Accretion expense 7,398 Obligations discharged with asset retirements (25,545) Obligations discharged with divestitures (146) Balance at September 30, 2020 163,704 Current portion (30,348) Long-term portion $ 133,356 Our estimated asset retirement obligations liability is based on historical experience in plugging and abandoning wells, estimated economic lives and estimated plugging, abandonment and surface reclamation costs considering federal and state regulatory requirements in effect at that time. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised. To the extent future revisions to these assumptions impact the present value of the existing asset retirement obligations liability, a corresponding adjustment is made to the properties and equipment balance. Changes in the liability due to the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense. Short-term asset retirement obligations are included in other accrued expenses in our condensed consolidated balance sheets.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure	COMMITMENTS AND CONTINGENCIES Firm Transportation and Processing Agreements. We enter into contracts that provide firm transportation and processing on pipeline systems through which we transport or sell crude oil and natural gas. Satisfaction of the volume requirements includes volumes produced by us, purchased from third parties and produced by other third-party working, royalty and overriding royalty interest owners whose volumes we market on their behalf. Our condensed consolidated statements of operations reflect our share of these firm transportation and processing costs. These contracts require us to pay these transportation and processing charges whether or not the required volumes are delivered. We may from time to time find ourselves unable to market our commodities at prices acceptable to us, or at all, which could cause us to be unable to meet these obligations. In such cases, we may be subject to penalties, fees, minimum margins or other payments. The following table presents gross volume information related to our long-term firm transportation, sales and processing agreements for pipeline capacity and water delivery and disposal commitments: For the Twelve Months Ending September 30, Area 2021 2022 2023 2024 2025 and Total Expiration Natural gas (MMcf) Wattenberg Field 63,922 63,922 63,922 64,098 86,876 342,740 August 31, 2026 Delaware Basin 32,022 14,510 9,125 9,150 57,075 121,882 March 31, 2031 Gas Marketing 7,117 6,228 — — — 13,345 August 31, 2022 Total 103,061 84,660 73,047 73,248 143,951 477,967 Crude oil (MBbls) Wattenberg Field 17,338 15,500 13,035 9,882 18,900 74,655 August 31, 2026 Delaware Basin 8,214 8,030 8,030 2,024 — 26,298 December 31, 2023 Total 25,552 23,530 21,065 11,906 18,900 100,953 Water (MBbls) Wattenberg Field 6,207 6,207 6,206 6,224 1,564 26,408 December 31, 2024 Dollar commitment (in thousands) $ 140,186 $ 117,235 $ 97,036 $ 70,981 $ 117,736 $ 543,174 Wattenberg Field. We entered into two facilities expansion agreements with our primary midstream provider to expand and improve its natural gas gathering pipelines and processing facilities. The midstream provider completed and turned on line the first of the two 200 MMcfd cryogenic plants in August 2018 and the second plant was completed in August 2019. We are bound to the volume requirements in these agreements on the first day of the calendar month following the actual in-service date of the relevant plant. Both agreements require baseline volume commitments, consisting of our gross wellhead volume delivered in November 2016 to this midstream provider, and incremental wellhead volume commitments of 51.5 MMcfd and 33.5 MMcfd for the first and second agreements, respectively, for seven years. In addition, as a result of the SRC Acquisition, we are subject to substantially similar facilities expansion agreements with the same primary midstream provider of 46.4 MMcfd and 43.8 MMcfd, respectively. We may be required to pay shortfall fees for any volumes under the 97.9 MMcfd and 77.3 MMcfd incremental commitments. Any shortfall in these volume commitments may be offset by other producers’ volumes sold to the midstream provider that are greater than a certain total baseline volume. We are also required for the first three years of the contracts to guarantee a certain target profit margin to the midstream provider on these incremental volumes. The actual shortfall in target profit margin incurred, which we guaranteed to our midstream provider, was included as part of contract assets as part of Other assets in the condensed consolidated balance sheets. Delaware Basin . In May 2018, we entered into a firm sales agreement that is effective from June 2018 through December 2023 with an integrated marketing company for our crude oil production in the Delaware Basin. Contracted volumes are currently 24,000 barrels of crude oil per day and decrease over time to 22,000 barrels per day. This agreement is expected to provide price diversification through realization of export market pricing via a Corpus Christi terminal and exposure to Brent-weighted prices. Crude Oil, Natural Gas and NGLs Sales . For the three months ended September 30, 2020 and 2019, amounts related to long-term transportation volumes in the table above were $4.5 million and $13.7 million, respectively, and were netted against our crude oil and natural gas sales. For the nine months ended September 30, 2020 and 2019, amounts related to long-term transportation volumes in the table above were $17.6 million and $36.8 million, respectively, and were netted against our crude oil and natural gas sales. Litigation and Legal Items. We are involved in various legal proceedings. We review the status of these proceedings on an ongoing basis and, from time to time, may settle or otherwise resolve these matters on terms and conditions that management believes are in our best interests. We have provided the necessary estimated accruals in the accompanying balance sheets where deemed appropriate for litigation and legal related items that are ongoing and not yet concluded. Although the results cannot be known with certainty, we currently believe that the ultimate results of such proceedings will not have a material adverse effect on our financial position, results of operations or liquidity. Environmental. Due to the nature of the natural gas and oil industry, we are exposed to environmental risks. We have various policies and procedures to minimize and mitigate the risks from environmental contamination. We conduct periodic reviews and simulated drills to identify changes in our environmental risk profile. Liabilities are recorded when environmental damages resulting from past events are probable and the costs can be reasonably estimated. Except as discussed herein, we are not aware of any material environmental claims existing as of September 30, 2020 which have not been provided for or would otherwise have a material impact on our financial statements; however, there can be no assurance that current regulatory requirements will not change or that unknown potential past non-compliance with environmental laws or other environmental liabilities will not be discovered on our properties. Accrued environmental liabilities are recorded in other accrued expenses in the condensed consolidated balance sheets. The liability ultimately incurred with respect to a matter may exceed the related accrual. In recent years, we have been executing a program to plug and abandon certain of our older vertical wells in the Wattenberg Field. A self-audit of final reclamation activities associated with site retirements, which we concluded in 2019, identified deficiencies, including incomplete documentation and agency submittals, inadequate plant growth and incomplete earthwork. In December 2019, we formally disclosed these deficiencies to the Colorado Oil and Gas Conservation Commission ("COGCC") and are working to close this backlog of site reclamation work. On August 19, 2020, COGCC issued to PDC a Notice of Alleged Violation ("NOAV") citing a failure to comply with reclamation requirements at multiple locations. During 2020, we are similarly assessing reclamation activities at sites acquired through the SRC Acquisition. We do not believe potential penalties and other expenditures associated with the deficiencies disclosed to the COGCC and the resulting NOAV, nor any potential future disclosure of deficiencies associated with reclamation of sites acquired in the SRC Acquisition, will have a material effect on our financial condition or results of operations, but they may exceed $100,000. In July 2020, a ruling by the U.S. Court of Appeals for the District of Columbia Circuit found that the U.S. Environmental Protection Agency (“EPA”) established the northern boundary of the Denver Metro/Northern Front Range ozone non-attainment area based on erroneous criteria and ordered the EPA to reconsider that boundary, potentially including more land within the designated area. All of our Wattenberg Field operations and leaseholds are within the current non-attainment area. Accordingly, we do not expect the ruling to impact us, regardless of the results of the EPA’s boundary reconsideration. As part of our integration activities over the facilities acquired through the SRC Acquisition, we are in the process of conducting a comprehensive air quality compliance audit. We do not believe potential penalties and other expenditures associated with deficiencies identified through the audit will have a material effect on our financial condition or results of operations, but they may exceed $100,000. Clean Air Act Agreement and Related Consent Decree. In June 2017, following our receipt of a 2015 Clean Air Act information request from the EPA and a 2015 compliance advisory from the Colorado Department of Public Health and Environment's (“CDPHE”) Air Pollution Control Division, the U.S. Department of Justice, on behalf of the EPA and the state of Colorado, filed a complaint against us in the U.S. District Court for the District of Colorado, claiming that we failed to operate and maintain certain condensate collection facilities at 65 facilities so as to minimize leakage of volatile organic compounds in compliance with applicable law. In October 2017, we entered into a consent decree to resolve the lawsuit and the compliance advisory. Pursuant to the consent decree, we agreed to implement a variety of operational enhancements, and environmental mitigations and similar projects, including vapor control system modifications and verification, increased inspection and monitoring and installation of tank pressure monitors. While many of those actions are complete, some requirements will continue until the consent decree is terminated. In addition, as a result of the SRC Acquisition, we are subject to the obligations and requirements of a 2018 Compliance Order on Consent (“COC”) entered into by SRC with CDPHE, applicable to certain SRC oil and gas production facilities. The CDPHE has agreed to revise the COC to make the inspection and monitoring requirements, among others, consistent with those contained in our consent decree.

Common Stock Common Stock (Note

Common Stock Common Stock (Notes)	9 Months Ended
	Sep. 30, 2020
Equity [Abstract]
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]	COMMON STOCK Stock-Based Compensation Plans 2018 Equity Incentive Plan . In May 2020, our stockholders approved an amendment to increase the number of shares of our common stock reserved for issuance pursuant to our long-term equity compensation plan for employees and non-employee directors (the “2018 Plan”) from 1,800,000 to 7,050,000. The 2018 Plan was approved in May 2018 and expires in March 2028. Shares issued may be authorized but unissued shares, treasury shares or any combination thereof. Additionally, the 2018 Plan permits the reuse or reissuance of shares of common stock which were canceled, expired, forfeited or paid out in the form of cash. However, shares tendered or withheld to satisfy the exercise price of options or tax withholding obligations, and shares covering the portion of exercised stock-settled stock appreciation rights ("SARs") (regardless of the number of shares actually delivered), count against the share limit. Awards may be issued in the form of options, SARs, restricted stock, restricted stock units ("RSUs"), performance stock units ("PSUs") and other stock-based awards. Awards may vest over periods of continued service or upon the satisfaction of performance conditions set at the discretion of the Compensation Committee of the Board (the "Compensation Committee"), with a minimum one-year vesting period applicable to most awards. With regard to SARs and options, awards have a maximum exercisable period of ten years. As of September 30, 2020, there were 5,244,358 shares available for grant under the 2018 Plan. 2010 Long-Term Equity Compensation Plan . Our Amended and Restated 2010 Long-Term Equity Compensation Plan, which was approved by stockholders in 2013 (as the same has been amended and restated from time to time, the "2010 Plan"), remains outstanding and we may continue to use the 2010 Plan to grant awards. No awards may be granted under the 2010 Plan on or after June 5, 2023. As of September 30, 2020, there were 159,237 shares available for grant under the 2010 Plan. 2015 SRC Equity Incentive Plan . Pursuant to the closing of the SRC Acquisition, SRC granted 155,928 PSUs to certain SRC executives under the 2015 SRC Equity Incentive Plan (the “2015 SRC Plan”). These PSUs (the “SRC PSUs”) were granted prior to the consummation of the merger, were assumed and converted into PDC PSUs at a rate of 0.158 per share and remain subject to the same terms and conditions (including performance-vesting terms) that applied immediately prior to the closing of the SRC Acquisition. The PSUs will result in a payout between zero and 200 percent of the target PSUs awarded. As of September 30, 2020, there were no shares available for grant under the 2015 SRC Plan. Stock-based Compensation. The impact of our stock-based compensation plans on our results of operations was $5.4 million and $17.4 million for the three and nine months ended September 30, 2020, respectively, and $5.9 million and $18.1 million for the three and nine months ended September 30, 2019, respectively. Restricted Stock Units Time-Based Awards. The fair value of the time-based RSUs is amortized ratably over the requisite service period, primarily three years. The time-based RSUs generally vest ratably on each anniversary following the grant date provided that a participant is continuously employed. The following table presents the changes in non-vested time-based RSUs to all employees, including executive officers, for the nine months ended September 30, 2020: Shares Weighted-Average Non-vested at December 31, 2019 795,926 $ 45.51 Granted 1,151,273 12.00 Vested (444,611) 41.87 Forfeited (300,841) 22.87 Non-vested at September 30, 2020 1,201,747 20.42 The following table presents the weighted-average grant date fair value per share and related information as of/for the periods presented: As of/Nine Months Ended September 30, 2020 2019 (in thousands, except per share data) Total intrinsic value of time-based awards vested $ 6,124 $ 11,251 Total intrinsic value of time-based awards non-vested 14,896 22,673 Market price per share as of September 30 12.40 27.75 Weighted-average grant date fair value per share 12.00 40.38 Total compensation cost related to non-vested time-based awards and not yet recognized in our condensed consolidated statements of operations as of September 30, 2020 was $15.7 million. This cost is expected to be recognized over a weighted-average period of 2.0 years. Performance Stock Units Market-Based Awards. The fair value of the market-based PSUs is amortized ratably over the requisite service period, primarily three years. The market-based shares vest if the participant is continuously employed throughout the performance period and the market-based performance measure is achieved, with a maximum vesting period of three years. All compensation cost related to the market-based awards will be recognized if the requisite service period is fulfilled, even if the market condition is not achieved. The Compensation Committee awarded a total of 368,077 market-based PSUs to our executive officers during the nine months ended September 30, 2020. In addition to continuous employment, the vesting of these PSUs is contingent on a combination of absolute stock performance and our total stockholder return ("TSR"), which is essentially our stock price change, including any dividends over a three-year period ending on December 31, 2022, as compared to the TSR of a group of peer companies over the same period. The PSUs will result in a payout between zero and 250 percent of the target PSUs awarded. The weighted-average grant date fair value per PSU granted was computed using the Monte Carlo pricing model using the following assumptions: Nine Months Ended September 30, 2020 2019 Expected term of award (in years) 3 3 Risk-free interest rate 1.4 % 2.5 % Expected volatility 46.6 % 41.4 % Weighted-average grant date fair value per share $ 33.52 $ 56.68 The expected term of the awards was based on the requisite service period. The risk-free interest rate was based on the U.S. Treasury yields in effect at the time of grant and extrapolated to approximate the life of the award. The expected volatility was based on our historical volatility. SRC Performance Stock Units. The terms of the SRC PSUs are substantially the same as those of the PDC PSUs, except that the SRC PSUs do not require continuous employment and the performance period associated with the awards of January 1, 2019 through December 31, 2021 predates the grant date. The fair value of the SRC PSU awards was determined on the grant date of January 13, 2020 using the Monte Carlo pricing model using the following assumptions: Nine Months Ended September 30, 2020 Expected term of awards (in years) 2 Risk-free interest rate 1.6 % Expected volatility 56.9 % Weighted-average grant date fair value per share $ 33.35 The expected term of the awards is based on the number of years from the grant date through the end of the performance period. The risk-free interest rate was based on the U.S. Treasury yields in effect at the time of grant, extrapolated to approximate the life of the awards. The expected volatility was based on our historical volatility, as well as that of our peer group. The following table presents the change in non-vested market-based awards, including SRC PSUs, during the nine months ended September 30, 2020: Shares Weighted-Average Non-vested at December 31, 2019 221,142 $ 61.61 Granted 524,005 30.29 Vested (10,196) 12.44 Forfeited (89,597) 46.43 Non-vested at September 30, 2020 645,354 39.06 The following table presents the weighted-average grant date fair value per share and related information as of/for the periods presented: As of/Nine Months Ended September 30, 2020 2019 (in thousands, except per share data) Total intrinsic value of market-based awards non-vested $ 7,999 $ 6,719 Market price per common share as of September 30, 12.40 27.75 Weighted-average grant date fair value per share 30.29 56.68 Total compensation cost related to non-vested market-based awards not yet recognized in our condensed consolidated statements of operations as of September 30, 2020 was $9.3 million. This cost is expected to be recognized over a weighted-average period of 1.7 years. Stock Appreciation Rights The SARs vest ratably over a three-year period and may generally be exercised at any point after vesting through ten years from the date of issuance. Pursuant to the terms of the awards, upon exercise, the executive officers will receive, in shares of common stock, the excess of the market price of the award on the date of exercise over the market price of the award on the date of issuance. The following table presents the change in SARs during the nine months ended September 30, 2020: Shares Weighted-Average Outstanding at December 31, 2019 290,258 $ 46.64 Exercised (7,807) 24.44 Expired (71,776) 40.83 Outstanding at September 30, 2020 210,675 49.45 All outstanding SARs as of September 30, 2020 have vested and the related compensation cost has been fully recognized. Preferred Stock We are authorized to issue 50,000,000 shares of preferred stock, par value $0.01 per share, which may be issued in one or more series, with such rights, preferences, privileges and restrictions as shall be fixed by the Board from time to time. Through September 30, 2020, no shares of preferred stock have been issued. Stock Repurchase Program In April 2019, the Board approved the acquisition of up to $200 million of our outstanding common stock, depending on market conditions (the "Stock Repurchase Program"). Effective upon the closing of the SRC Acquisition, our Board approved an increase and extension to the Stock Repurchase Program from $200 million to $525 million. Repurchases under the Stock Repurchase Program can be made in open markets at our discretion and in compliance with safe harbor provisions, or in privately negotiated transactions. The Stock Repurchase Program does not require any specific number of shares to be acquired, and can be modified or discontinued by the Board at any time. During the nine months ended September 30, 2020, we repurchased 1.3 million shares of our outstanding common stock at a cost of $23.8 million. We suspended the program in March 2020. Approximately $346.8 million of our outstanding common stock remains available for repurchase under the program. If the program is reactivated, we expect repurchases made pursuant to the Stock Repurchase Program to extend beyond December 31, 2021, given current market conditions.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Tax Disclosure	INCOME TAXES We compute our quarterly tax provision using the effective tax rate method by applying the anticipated annual effective rate to our year-to-date income or loss, except for discrete items. Income tax on discrete items is computed and recorded in the period in which the specific transaction occurs. As previously noted, we recorded impairments totaling $882.3 million for the nine months ended September 30, 2020. These impairments resulted in three years of cumulative historical pre-tax losses and a net deferred tax asset position. We also have estimated net operating loss carryovers (“NOLs”) for federal income tax purposes of $470.0 million. These losses were a key consideration that led us to continue to provide a valuation allowance against our net deferred tax assets as of September 30, 2020 since we cannot conclude that it is more likely than not that our net deferred tax asset will be fully realized in future periods. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. At each reporting period, management considers the scheduled reversal of deferred tax liabilities, available taxes in carryback periods, tax planning strategies and projected future taxable income in making this assessment. Future events or new evidence which may lead us to conclude that it is more likely than not that our net deferred tax assets will be realized include, but are not limited to, cumulative historical pre-tax earnings, sustained or continued improvements in oil prices, and taxable events that could result from one or more transactions. We will continue to evaluate whether the valuation allowance is needed in future reporting periods. As noted in the footnote Business Combinations , the accounting for the SRC Acquisition is still in the measurement period. Additional adjustments during the measurement period for the SRC Acquisition may have an impact on the income tax provision in future periods, although such adjustments are not expected to be material. Other than business combination accounting adjustments during the measurement period, we will likely not have any additional income tax expense or benefit other than for state income taxes as long as we continue to conclude that it is appropriate to maintain a full valuation allowance against our net deferred tax assets. The effective income tax rate for the three and nine months ended September 30, 2020 was a 0.6 percent provision on loss and a 0.5 percent benefit on loss, respectively, compared to a 40.1 percent provision on income for the three months ended September 30, 2019 and a 10.4 percent benefit on loss for the nine months ended September 30, 2019. The effective tax rate for the three and nine months ended September 30, 2020 differs from the amount that would be provided by applying the statutory U.S. federal income tax rate of 21% to pre-tax income due to the effect of a full valuation allowance in effect at September 30, 2020. The effective tax rate for the three and nine months ended September 30, 2019 differs from the statutory U.S. federal income tax rate of 21% due to state income taxes, non-deductible lobbying expenses, stock-based compensation and non-deductible officers’ compensation. As of September 30, 2020, there is no liability for unrecognized income tax benefits. As of the date of this report, we are current with our income tax filings in all applicable state jurisdictions and are not currently under any state income tax examinations. The IRS has accepted our 2018 federal income tax return with no tax adjustments. We continue to voluntarily participate in the IRS CAP Program for the review of our 2019 and 2020 tax year. Participation in the IRS CAP Program has enabled us to have minimal uncertain tax benefits associated with our federal tax return filings.

Earnings per share

Earnings per share	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
Earnings Per Share	EARNINGS PER SHARE Basic earnings per share is computed by dividing net earnings by the weighted-average number of common shares outstanding for the period. Diluted earnings per share is similarly computed, except that the denominator includes the effect, using the treasury stock method, of unvested equity-based employee awards, convertible notes and shares held pursuant to our non-employee director deferred compensation plan, if including such potential shares of common stock is dilutive. The following table presents our weighted-average basic and diluted shares outstanding: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Weighted-average common shares outstanding - basic 99,617 62,547 97,762 64,835 Dilutive effect of: RSUs and PSUs — 32 — — Other equity-based awards — 16 — — Weighted-average common shares and equivalents outstanding - diluted 99,617 62,595 97,762 64,835 We reported a net loss for the three and nine months ended September 30, 2020 and the nine months ended September 30, 2019. As a result, our basic and diluted weighted-average common shares outstanding were the same for those periods because the effect of the common share equivalents was anti-dilutive. The following table presents the weighted-average common share equivalents excluded from the calculation of diluted earnings per share due to their anti-dilutive effect: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Weighted-average common share equivalents excluded from diluted earnings per share due to their anti-dilutive effect: RSUs and PSUs 1,831 947 1,715 980 Other equity-based awards 223 267 231 302 Total anti-dilutive common share equivalents 2,054 1,214 1,946 1,282 The 2021 Convertible Notes give the holders, at our election, the right to convert the aggregate principal amount into 2.3 million shares of our common stock at a conversion price of $85.39 per share. The 2021 Convertible Notes were not included in the diluted earnings per share calculation using the treasury stock method for any periods presented because the average market price of our common stock did not exceed the conversion price.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2020
Supplemental Cash Flow Elements [Abstract]
Cash Flow, Supplemental Disclosures [Text Block]	SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION Nine Months Ended September 30, 2020 2019 (in thousands) Supplemental cash flow information: Cash payments (receipts) for: Interest, net of capitalized interest $ 51,556 $ 41,483 Income taxes (204) 261 Non-cash investing and financing activities: Change in accounts payable related to capital expenditures $ (31,403) $ (32,943) Change in asset retirement obligations, with a corresponding change to crude oil and natural gas properties, net of disposals 44,339 13,493 Change in accounts payable related to the purchase and retirement of treasury shares — 2,818 Issuance of common stock for the acquisition of crude oil and natural gas properties, net 1,009,015 — Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6,714 $ 4,107 Operating cash flows from finance leases 155 193 ROU assets obtained in exchange for lease obligations: Operating leases $ 4,217 $ 1,428 Finance leases 703 2,323 Subsequent to the filing of our Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2019, we identified an immaterial error in our condensed consolidated statement of cash flows related to cash paid for capital expenditures for development of crude oil and natural gas properties for the period ended September 30, 2019. Our balance sheet and statement of operations for the relevant period were not impacted. We evaluated the error under the guidance of Accounting Standards Codification 250, Accounting Changes and Error Corrections ("ASC 250"). Based on the guidance in ASC 250, we determined that the error did not have a material impact on our previously-issued financial statements or those of the period of correction. The error resulted in an overstatement of cash flows from operations of $24.8 million and an overstatement of cash used in investing activities of $24.8 million in each period as follows: Nine Months Ended September 30, 2019 (dollars in thousands) Cash flows from operating activities, as reported $ 675,725 Adjustment (24,753) Cash flows from operating activities, as adjusted $ 650,972 Cash flows from investing activities, as reported $ (596,973) Adjustment 24,753 Cash flows from investing activities, as adjusted $ (572,220)

Significant Accounting Policies

Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Error Corrections and Prior Period Adjustments Restatement [Line Items]	Recently Adopted Accounting PronouncementIn March 2020, the SEC adopted final rules that amend the financial disclosure requirements for subsidiary issuers and guarantors of registered debt securities in Rule 3-10 of Regulation S-X. The amended rules, which can be found under new Rule 13-01 of Regulation S-X, narrow the circumstances that require separate financial statements of subsidiary issuers and guarantors and streamline the alternative disclosures required in lieu of those statements. The amended rules allow registrants, among other things, to disclose summarized financial information of the issuer and guarantors on a combined basis and to present only the most recently completed fiscal year and subsequent year-to-date interim period. The rule replaces the requirement to provide condensed consolidating financial information with a requirement to present summarized financial information of the issuers and guarantors. These disclosures may be provided outside the notes to the condensed consolidated financial statements. The rule is effective in the first quarter of 2021, with earlier adoption permitted. We early adopted the rule in the first quarter of 2020 and have
Consolidation, Policy	The accompanying unaudited condensed consolidated financial statements include the accounts of PDC and our wholly-owned subsidiaries. All material intercompany accounts and transactions have been eliminated in consolidation
Basis of Accounting, Policy	In our opinion, the accompanying condensed consolidated financial statements contain all adjustments, consisting of normal recurring adjustments necessary for a fair presentation of our financial statements for interim periods in accordance with accounting principles generally accepted in the United States of America ("U.S. GAAP") and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in audited financial statements have been condensed or omitted. The December 31, 2019 condensed consolidated balance sheet data was derived from audited statements, but does not include all disclosures required by U.S. GAAP. The information presented in this Quarterly Report on Form 10-Q should be read in conjunction with our audited consolidated financial statements and notes thereto included in our 2019 Form 10-K. Our results of operations and cash flows for the nine months ended September 30, 2020 are not necessarily indicative of the results to be expected for the full year or any other future period
Earnings Per Share, Policy	Basic earnings per share is computed by dividing net earnings by the weighted-average number of common shares outstanding for the period. Diluted earnings per share is similarly computed, except that the denominator includes the effect, using the treasury stock method, of unvested equity-based employee awards, convertible notes and shares held pursuant to our non-employee director deferred compensation plan, if including such potential shares of common stock is dilutive.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations (Policies)	9 Months Ended
	Sep. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation [Policy Text Block]	Our estimated asset retirement obligations liability is based on historical experience in plugging and abandoning wells, estimated economic lives and estimated plugging, abandonment and surface reclamation costs considering federal and state regulatory requirements in effect at that time. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised. To the extent future revisions to these assumptions impact the present value of the existing asset retirement obligations liability, a corresponding adjustment is made to the properties and equipment balance. Changes in the liability due to the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense. Short-term asset retirement obligations are included in other accrued expenses in our condensed consolidated balance sheets.

Business Combination Purchase P

Business Combination Purchase Price Transaction Details (Tables)	9 Months Ended
	Sep. 30, 2020
Business Combination, Separately Recognized Transactions [Line Items]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	BUSINESS COMBINATION In January 2020, we merged with SRC in a transaction valued at $1.7 billion, inclusive of SRC's net debt (the "SRC Acquisition"). Upon closing, we issued approximately 39 million shares of our common stock to SRC shareholders and holders of SRC equity awards, reflecting the issuance of 0.158 of a share of our common stock in exchange for each outstanding share of SRC common stock and the cancellation of outstanding SRC equity awards pursuant to the merger agreement that we entered into with SRC (the "Merger Agreement"). During the nine months ended September 30, 2020, we recorded transaction costs related to the SRC Acquisition of $20.2 million. These expenses were accounted for separately from the assets and liabilities assumed and are included in general and administrative expense in the condensed consolidated statements of operations. The details of the estimated purchase price and the preliminary allocation of the purchase price are as follows: Nine Months Ended September 30, 2020 (in thousands) Consideration: Cash $ 40 Retirement of seller's credit facility 166,238 Total cash consideration 166,278 Common stock issued 1,009,015 Shares withheld in lieu of taxes 6,299 Total consideration $ 1,181,592 Recognized amounts of identifiable assets acquired and liabilities assumed: Assets acquired: Current assets $ 149,538 Properties and equipment, net - proved 1,607,175 Properties and equipment, net - unproved 109,615 Properties and equipment, net - other 16,242 Deferred tax asset 193,410 Other assets 13,266 Total assets acquired 2,089,246 Liabilities assumed: Current liabilities (257,285) Senior notes (555,500) Asset retirement obligations (41,901) Other liabilities (52,968) Total liabilities assumed (907,654) Total identifiable net assets acquired $ 1,181,592 This acquisition was accounted for under the acquisition method of accounting for business combinations. Accordingly, we conducted assessments of the net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values, while transaction and integration costs associated with the acquisition were expensed as incurred. The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market, and therefore represent Level 3 inputs. The fair values of crude oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of proved and unproved crude oil and natural gas properties include estimates of reserves, future operating and development costs, future commodity prices, estimated future cash flows, lease terms and expirations and a market-based weighted-average cost of capital rate of 10 percent. These inputs require significant judgments and estimates by management at the time of the valuation. As of the date of this report, we expect that the measurement period will extend into the fourth quarter of 2020, and the value of the assets and liabilities may be revised as appropriate. The results of operations for the SRC Acquisition since the closing date have been included in our condensed consolidated financial statements for the three and nine months ended September 30, 2020 and include approximately $82.0 million and $233.8 million of total revenue, respectively, and $20.7 million and $19.3 million of loss from operations for the three and nine months ended September 30, 2020, respectively. Pro Forma Information. The following unaudited pro forma financial information represents a summary of the consolidated results of operations for the nine months ended September 30, 2020 and for the three and nine months ended September 30, 2019, assuming the acquisition had been completed as of January 1, 2019. The financial information for the three months ended September 30, 2020 is included in our condensed consolidated statements of operations and therefore does not require a pro forma disclosure. The pro forma amounts for the nine months ended September 30, 2020 include an immaterial non-recurring adjustment which was not included in our pro forma information disclosed in our six months ended June 30, 2020 and our three months ended March 31, 2020 footnotes. The pro forma financial information includes certain non-recurring pro forma adjustments that were directly attributable to the business combination. The pro forma financial information is not necessarily indicative of the results of operations that would have been achieved if the acquisition had been effective as of these dates, or of future results. Three Months Ended September 30, Nine Months Ended September 30, 2019 2020 2019 (in thousands, except per share data) Total revenue $ 511,110 $ 1,082,003 $ 1,373,739 Net income (loss) 63,092 (677,636) 128,337 Earnings (loss) per share: Basic $ 0.62 $ (6.79) $ 1.23 Diluted 0.62 (6.79) 1.23
Business Combination, Separately Recognized Transactions [Table Text Block]	The details of the estimated purchase price and the preliminary allocation of the purchase price are as follows: Nine Months Ended September 30, 2020 (in thousands) Consideration: Cash $ 40 Retirement of seller's credit facility 166,238 Total cash consideration 166,278 Common stock issued 1,009,015 Shares withheld in lieu of taxes 6,299 Total consideration $ 1,181,592 Recognized amounts of identifiable assets acquired and liabilities assumed: Assets acquired: Current assets $ 149,538 Properties and equipment, net - proved 1,607,175 Properties and equipment, net - unproved 109,615 Properties and equipment, net - other 16,242 Deferred tax asset 193,410 Other assets 13,266 Total assets acquired 2,089,246 Liabilities assumed: Current liabilities (257,285) Senior notes (555,500) Asset retirement obligations (41,901) Other liabilities (52,968) Total liabilities assumed (907,654) Total identifiable net assets acquired $ 1,181,592
Business Acquisition, Pro Forma Information [Table Text Block]	Three Months Ended September 30, Nine Months Ended September 30, 2019 2020 2019 (in thousands, except per share data) Total revenue $ 511,110 $ 1,082,003 $ 1,373,739 Net income (loss) 63,092 (677,636) 128,337 Earnings (loss) per share: Basic $ 0.62 $ (6.79) $ 1.23 Diluted 0.62 (6.79) 1.23

Revenue Recognition (Tables)

Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2020
Revenue Recognition and Deferred Revenue [Abstract]
Disaggregation of Revenue [Table Text Block]	Disaggregated Revenue. The following table presents crude oil, natural gas and NGLs sales disaggregated by commodity and operating region for the three and nine months ended September 30, 2020 and 2019: Three Months Ended September 30, Nine Months Ended September 30, Revenue by Commodity and Operating Region 2020 2019 Percent Change 2020 2019 Percent Change (in thousands) Crude oil Wattenberg Field $ 183,420 $ 185,543 (1.1) % $ 483,608 $ 569,518 (15.1) % Delaware Basin 42,591 70,175 (39.3) % 107,347 191,452 (43.9) % Total $ 226,011 $ 255,718 (11.6) % $ 590,955 $ 760,970 (22.3) % Natural gas Wattenberg Field $ 39,759 $ 23,949 66.0 % $ 109,279 $ 100,779 8.4 % Delaware Basin 2,140 2,613 (18.1) % 3,183 9,293 (65.7) % Total $ 41,899 $ 26,562 57.7 % $ 112,462 $ 110,072 2.2 % NGLs Wattenberg Field $ 38,871 $ 16,906 129.9 % $ 86,875 $ 67,305 29.1 % Delaware Basin 8,139 8,223 (1.0) % 18,864 29,117 (35.2) % Total $ 47,010 $ 25,129 87.1 % $ 105,739 $ 96,422 9.7 % Crude oil, natural gas and NGLs Wattenberg Field $ 262,050 $ 226,398 15.7 % $ 679,762 $ 737,602 (7.8) % Delaware Basin 52,870 81,011 (34.7) % 129,394 229,862 (43.7) % Total $ 314,920 $ 307,409 2.4 % $ 809,156 $ 967,464 (16.4) %
Contract with Customer, Asset and Liability	The following table presents the changes in carrying amounts of the contract assets associated with our crude oil, natural gas and NGLs sales revenue for the nine months ended September 30, 2020: Amount (in thousands) Beginning balance, January 1, 2020 $ 11,494 Additions 15,627 Amortized as a reduction to crude oil, natural gas and NGLs sales (1,588) Ending balance, September 30, 2020 $ 25,533

Fair Value Measurements and D_2

Fair Value Measurements and Disclosures (Tables)	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	The portion of our long-term debt related to our revolving credit facility approximates fair value, as the applicable interest rates are variable and reflective of market rates. We have not elected to account for the portion of our debt related to our senior notes under the fair value option; however, we have determined an estimate of the fair values based on measurements of trading activity and broker and/or dealer quotes, respectively, which are published market prices, and therefore are Level 2 inputs. The table below presents these estimates of the fair value of the portion of our long-term debt related to our senior notes and convertible notes. As of September 30, 2020 As of December 31, 2019 Estimated Fair Value Percent of Par Estimated Fair Value Percent of Par (in millions) Senior Notes: 2021 Convertible Notes $ 192.6 96.3 % $ 188.6 94.3 % 2024 Senior Notes 382.8 95.7 % 409.2 102.3 % 2025 Senior Notes 96.1 93.9 % — — % 2026 Senior Notes (1) 696.8 92.9 % 599.4 99.9 %
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	Our crude oil and natural gas fixed-price swaps are included in Level 2. Our collars are included in Level 3. Our basis swaps are included in Level 2 and Level 3. The following table presents, for each applicable level within the fair value hierarchy, our derivative assets and liabilities, including both current and non-current portions, measured at fair value on a recurring basis: As of September 30, 2020 As of December 31, 2019 Significant Other Significant Total Significant Other Significant Total (in thousands) Total assets $ 130,134 $ 21,545 $ 151,679 $ 22,886 $ 8,938 $ 31,824 Total liabilities (79,658) (30,759) (110,417) (3,089) (524) (3,613) Net derivative instruments $ 50,476 $ (9,214) $ 41,262 $ 19,797 $ 8,414 $ 28,211
Fair Value Assets and Liabilities Unobservable Input Reconciliation	The following table presents a reconciliation of our Level 3 assets measured at fair value: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Fair value of Level 3 instruments, net asset beginning of period $ 26,958 $ 22,504 $ 8,414 $ 58,329 Changes in fair value included in condensed consolidated statement of operations line item: Commodity price risk management gain (loss), net (21,521) 10,846 32,840 (22,077) Settlements included in condensed consolidated statement of operations line items: Commodity price risk management loss, net (14,652) (2,445) (50,469) (5,347) Fair value of Level 3 instruments, net asset end of period $ (9,215) $ 30,905 $ (9,215) $ 30,905 Net change in fair value of Level 3 unsettled derivatives included in condensed consolidated statement of operations line item: Commodity price risk management gain (loss), net $ (13,171) $ 6,787 $ 9,466 $ (11,620)

Derivative Financial Instrume_2

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2020
Derivative [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	As of September 30, 2020, we had the following outstanding derivative contracts. When aggregating multiple contracts, the weighted-average contract price is shown. Collars Fixed-Price Swaps Commodity/ Index/ Quantity (Crude oil - MBbls Natural Gas - BBtu) Weighted-Average Quantity (Crude Oil - MBbls Gas and Basis- BBtu) Weighted- Fair Value September 30, 2020 (1) (in thousands) Floors Ceilings Crude Oil NYMEX 2020 900 $ 55.00 $ 71.68 3,174 $ 58.90 $ 71,119 2021 996 35.00 46.22 9,180 46.90 40,547 2022 — — — 3,984 40.01 (13,433) Total Crude Oil 1,896 16,338 $ 98,233 Natural Gas NYMEX 2020 17,308 $ 2.02 $ 2.34 1,000 $ 2.30 $ (6,576) 2021 62,625 2.46 2.86 31,800 2.40 (31,070) 2022 8,700 2.50 2.79 8,700 2.62 (21) Total Natural Gas 88,633 41,500 $ (37,667) Basis Protection - Natural Gas CIG 2020 — $ — $ — 17,350 $ (0.48) $ (4,627) 2021 — — — 94,425 (0.46) (13,433) 2022 — — — 17,400 (0.36) (733) Waha 2020 — — — 1,000 (1.40) (511) Total Basis Protection - Natural Gas — 130,175 $ (19,304) Commodity Derivatives Fair Value $ 41,262 _____________
Schedule of Subsequent Events	Subsequent to September 30, 2020, we entered into the following commodity derivative positions covering our natural gas production: Collars Fixed-Price Swaps Commodity/ Index/ Quantity (BBtu) Weighted-Average Quantity (BBtu) Weighted- Floors Ceilings NYMEX 2022 8,700 $ 2.50 $ 3.00 — — Basis Protection CIG 2022 — — — 8,700 $ (0.31)
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]	The following table presents the condensed consolidated balance sheet line item and fair value amounts of our derivative instruments as of September 30, 2020 and December 31, 2019: Fair Value Derivative Instruments: Condensed Consolidated Balance Sheet Line Item September 30, 2020 December 31, 2019 (in thousands) Derivative assets: Current Commodity derivative contracts Fair value of derivatives $ 138,652 $ 27,766 Basis protection derivative contracts Fair value of derivatives — 312 138,652 28,078 Non-current Commodity derivative contracts Fair value of derivatives 13,027 3,746 Total derivative assets $ 151,679 $ 31,824 Derivative liabilities: Current Commodity derivative contracts Fair value of derivatives $ 50,969 $ 529 Basis protection derivative contracts Fair value of derivatives 12,988 2,392 63,957 2,921 Non-current Commodity derivative contracts Fair value of derivatives 40,144 692 Basis protection derivative contracts Fair value of derivatives 6,316 — 46,460 692 Total derivative liabilities $ 110,417 $ 3,613 The following table presents the impact of our derivative instruments on our condensed consolidated statements of operations: Three Months Ended September 30, Nine Months Ended September 30, Condensed Consolidated Statement of Operations Line Item 2020 2019 2020 2019 (in thousands) Commodity price risk management gain (loss), net Net settlements $ 66,895 $ 1,845 $ 227,513 $ (19,800) Net change in fair value of unsettled derivatives (134,956) 53,022 18,338 (68,058) Total commodity price risk management gain (loss), net $ (68,061) $ 54,867 $ 245,851 $ (87,858)
Derivatives Not Designated as Hedging Instruments [Table Text Block]	The following table reflects the impact of netting agreements on gross derivative assets and liabilities: As of September 30, 2020 Derivative Instruments, Gross Effect of Master Netting Agreements Derivative Instruments, Net (in thousands) Derivative assets: Derivative instruments, at fair value $ 151,679 $ (51,823) $ 99,856 Derivative liabilities: Derivative instruments, at fair value $ 110,417 $ (51,823) $ 58,594 As of December 31, 2019 Derivative Instruments, Gross Effect of Master Netting Agreements Derivative Instruments, Net (in thousands) Derivative assets: Derivative instruments, at fair value $ 31,824 $ (2,619) $ 29,205 Derivative liabilities: Derivative instruments, at fair value $ 3,613 $ (2,619) $ 994

Properties and Equipment (Table

Properties and Equipment (Tables)	9 Months Ended
	Sep. 30, 2020
Oil and Gas Property [Abstract]
Property, Plant and Equipment	The following table presents the components of properties and equipment, net of accumulated depreciation, depletion and amortization ("DD&A"): September 30, 2020 December 31, 2019 (in thousands) Properties and equipment, net: Crude oil and natural gas properties Proved $ 7,389,676 $ 6,241,780 Unproved 381,428 403,379 Total crude oil and natural gas properties 7,771,104 6,645,159 Equipment and other 65,256 41,888 Land and buildings 24,859 12,312 Construction in progress 505,930 408,428 Properties and equipment, at cost 8,367,149 7,107,787 Accumulated DD&A (3,481,915) (3,012,585) Properties and equipment, net $ 4,885,234 $ 4,095,202
Schedule of Aging of Capitalized Exploratory Well Costs [Table Text Block]	The following table presents the capitalized exploratory well cost pending determination of proved reserves and included in properties and equipment, net on the condensed consolidated balance sheets: Nine Months Ended September 30, Year Ended December 31, 2019 (in thousands, except for number of wells) Beginning balance $ 16,078 $ 12,188 Additions to capitalized exploratory well costs pending the determination of proved reserves 11,540 31,901 Reclassifications to proved properties (20,392) (28,011) Ending balance $ 7,226 $ 16,078 Number of wells pending determination at period-end 2 4

Other Accrued Expenses and Ot_2

Other Accrued Expenses and Other Liabilities (Tables)	9 Months Ended
	Sep. 30, 2020
Accrued Liabilities and Other Liabilities [Abstract]
Accounts Payable, Accrued Liabilities, and Other Liabilities Disclosure, Current [Text Block]	The following table presents the components of other accrued expenses as of: September 30, 2020 December 31, 2019 (in thousands) Employee benefits $ 19,833 $ 21,611 Asset retirement obligations 30,348 32,200 Environmental expenses 11,988 2,256 Operating and finance leases 8,809 5,926 Other 10,914 8,469 Other accrued expenses $ 81,892 $ 70,462
Accounts Payable, Accrued Liabilities, and Other Liabilities Disclosure, Noncurrent [Text Block]	The following table presents the components of other liabilities as of: September 30, 2020 December 31, 2019 (in thousands) Production taxes $ 46,500 $ 68,020 Deferred oil gathering credits 18,593 20,100 Deferred midstream gathering credits 170,508 175,897 Operating and finance leases 12,494 15,779 Other 2,440 3,337 Other liabilities $ 250,535 $ 283,133
Deferred Midstream Gathering Credits	The following table presents the amortization charges recognized in the condensed consolidated statements of operations for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Crude oil, natural gas and NGL sales (1) $ — $ 201 $ 368 $ 259 Transportation, gathering and processing expenses 1,535 711 2,991 914 Lease operating expenses 686 373 1,458 557

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	Long-term debt consisted of the following as of: September 30, 2020 December 31, 2019 (in thousands) Senior Notes: 1.125% Convertible Notes due September 2021: Principal amount $ 200,000 $ 200,000 Unamortized discount (8,458) (14,763) Unamortized debt issuance costs (934) (1,666) Net of unamortized discount and debt issuance costs 190,608 183,571 6.125% Senior Notes due September 2024: Principal amount 400,000 400,000 Unamortized debt issuance costs (3,876) (4,611) Net of unamortized debt issuance costs 396,124 395,389 6.25% Senior Notes due December 2025: Principal amount 102,324 — Unamortized premium 914 — Net of unamortized premium 103,238 — 5.75% Senior Notes due May 2026: Principal amount 750,000 600,000 Unamortized discount (1,490) — Unamortized debt issuance costs (6,873) (5,734) Net of unamortized discount and debt issuance costs 741,637 594,266 Total senior notes 1,431,607 1,173,226 Revolving Credit Facility: Revolving credit facility due May 2023 285,000 4,000 Total debt, net of unamortized discount and premium and debt issuance costs 1,716,607 1,177,226 Less current portion of long-term debt 190,608 — Long-term debt $ 1,525,999 $ 1,177,226

Leases Operating and Financing

Leases Operating and Financing Leases (Tables)	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Lease, Cost [Table Text Block]	The following table presents the components of lease costs: Three Months Ended September 30, Nine Months Ended September 30, Lease Costs 2020 2019 2020 2019 (in thousands) Operating lease costs $ 2,030 $ 1,093 $ 5,842 $ 3,824 Finance lease costs: Amortization of ROU assets 473 506 1,462 1,493 Interest on lease liabilities 44 66 150 195 Total finance lease costs 517 572 1,612 1,688 Short-term lease costs 17,975 35,118 149,960 147,223 Total lease costs $ 20,522 $ 36,783 $ 157,414 $ 152,735
Operating and Financing Leases Financial Statement Location [Table Text Block]	The following table presents the balance sheet classification and other information regarding our leases as of: Leases Condensed Consolidated Balance Sheet Line Item September 30, 2020 December 31, 2019 (in thousands) Operating Leases: Operating lease ROU assets Other assets $ 13,484 $ 14,926 Operating lease obligation - short-term Other accrued expenses 7,183 4,159 Operating lease obligation - long-term Other liabilities 10,496 12,944 Total operating lease liabilities $ 17,679 $ 17,103 Finance Leases: Finance lease ROU assets Properties and equipment, net $ 3,647 $ 4,637 Finance lease obligation - short-term Other accrued expenses 1,626 1,767 Finance lease obligation - long-term Other liabilities 1,998 2,835 Total finance lease liabilities $ 3,624 $ 4,602 Weighted-average remaining lease term (years) Operating leases 3.15 4.28 Finance leases 2.72 3.17 Weighted-average discount rate Operating leases 5.0 % 5.0 % Finance leases 5.0 % 5.0 %
Operating and Financing Lease, Liability, Maturity [Table Text Block]	Maturity of lease liabilities by year and in the aggregate, under operating and financing leases with terms of one year or more, as of September 30, 2020 consist of the following: Operating Leases Finance Leases Total (in thousands) 2020 (remaining after September 30, 2020) $ 2,294 $ 496 $ 2,790 2021 7,055 1,580 8,635 2022 5,516 955 6,471 2023 1,559 669 2,228 2024 950 141 1,091 Thereafter 1,698 9 1,707 Total lease payments 19,072 3,850 22,922 Less interest and discount (1,393) (226) (1,619) Present value of lease liabilities $ 17,679 $ 3,624 $ 21,303

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following table presents the changes in carrying amounts of the asset retirement obligations associated with our working interests in crude oil and natural gas properties: Amount (in thousands) Balance at December 31, 2019 $ 127,251 Obligations incurred with development activities and other 7,588 Obligations incurred with acquisition 47,158 Accretion expense 7,398 Obligations discharged with asset retirements (25,545) Obligations discharged with divestitures (146) Balance at September 30, 2020 163,704 Current portion (30,348) Long-term portion $ 133,356

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contigencies (Tables)	9 Months Ended
	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Supply Commitment	The following table presents gross volume information related to our long-term firm transportation, sales and processing agreements for pipeline capacity and water delivery and disposal commitments: For the Twelve Months Ending September 30, Area 2021 2022 2023 2024 2025 and Total Expiration Natural gas (MMcf) Wattenberg Field 63,922 63,922 63,922 64,098 86,876 342,740 August 31, 2026 Delaware Basin 32,022 14,510 9,125 9,150 57,075 121,882 March 31, 2031 Gas Marketing 7,117 6,228 — — — 13,345 August 31, 2022 Total 103,061 84,660 73,047 73,248 143,951 477,967 Crude oil (MBbls) Wattenberg Field 17,338 15,500 13,035 9,882 18,900 74,655 August 31, 2026 Delaware Basin 8,214 8,030 8,030 2,024 — 26,298 December 31, 2023 Total 25,552 23,530 21,065 11,906 18,900 100,953 Water (MBbls) Wattenberg Field 6,207 6,207 6,206 6,224 1,564 26,408 December 31, 2024 Dollar commitment (in thousands) $ 140,186 $ 117,235 $ 97,036 $ 70,981 $ 117,736 $ 543,174

Common Stock Common Stock (Tabl

Common Stock Common Stock (Tables)	9 Months Ended
	Sep. 30, 2020
Equity [Abstract]
Share-based Payment Arrangement, Cost by Plan [Table Text Block]	The impact of our stock-based compensation plans on our results of operations was $5.4 million and $17.4 million for the three and nine months ended September 30, 2020, respectively, and $5.9 million and $18.1 million for the three and nine months ended September 30, 2019, respectively.
Share-based Payment Arrangement, Restricted Stock and Restricted Stock Unit, Activity [Table Text Block]	The following table presents the changes in non-vested time-based RSUs to all employees, including executive officers, for the nine months ended September 30, 2020: Shares Weighted-Average Non-vested at December 31, 2019 795,926 $ 45.51 Granted 1,151,273 12.00 Vested (444,611) 41.87 Forfeited (300,841) 22.87 Non-vested at September 30, 2020 1,201,747 20.42 The following table presents the weighted-average grant date fair value per share and related information as of/for the periods presented: As of/Nine Months Ended September 30, 2020 2019 (in thousands, except per share data) Total intrinsic value of time-based awards vested $ 6,124 $ 11,251 Total intrinsic value of time-based awards non-vested 14,896 22,673 Market price per share as of September 30 12.40 27.75 Weighted-average grant date fair value per share 12.00 40.38
Restricted Stock Awards, Market-Based, Valuation assumptions [Table Text Block]	The Compensation Committee awarded a total of 368,077 market-based PSUs to our executive officers during the nine months ended September 30, 2020. In addition to continuous employment, the vesting of these PSUs is contingent on a combination of absolute stock performance and our total stockholder return ("TSR"), which is essentially our stock price change, including any dividends over a three-year period ending on December 31, 2022, as compared to the TSR of a group of peer companies over the same period. The PSUs will result in a payout between zero and 250 percent of the target PSUs awarded. The weighted-average grant date fair value per PSU granted was computed using the Monte Carlo pricing model using the following assumptions: Nine Months Ended September 30, 2020 2019 Expected term of award (in years) 3 3 Risk-free interest rate 1.4 % 2.5 % Expected volatility 46.6 % 41.4 % Weighted-average grant date fair value per share $ 33.52 $ 56.68 The expected term of the awards was based on the requisite service period. The risk-free interest rate was based on the U.S. Treasury yields in effect at the time of grant and extrapolated to approximate the life of the award. The expected volatility was based on our historical volatility. SRC Performance Stock Units. The terms of the SRC PSUs are substantially the same as those of the PDC PSUs, except that the SRC PSUs do not require continuous employment and the performance period associated with the awards of January 1, 2019 through December 31, 2021 predates the grant date. The fair value of the SRC PSU awards was determined on the grant date of January 13, 2020 using the Monte Carlo pricing model using the following assumptions: Nine Months Ended September 30, 2020 Expected term of awards (in years) 2 Risk-free interest rate 1.6 % Expected volatility 56.9 % Weighted-average grant date fair value per share $ 33.35
Schedule of Nonvested Performance-based Units Activity [Table Text Block]	The following table presents the change in non-vested market-based awards, including SRC PSUs, during the nine months ended September 30, 2020: Shares Weighted-Average Non-vested at December 31, 2019 221,142 $ 61.61 Granted 524,005 30.29 Vested (10,196) 12.44 Forfeited (89,597) 46.43 Non-vested at September 30, 2020 645,354 39.06 The following table presents the weighted-average grant date fair value per share and related information as of/for the periods presented: As of/Nine Months Ended September 30, 2020 2019 (in thousands, except per share data) Total intrinsic value of market-based awards non-vested $ 7,999 $ 6,719 Market price per common share as of September 30, 12.40 27.75 Weighted-average grant date fair value per share 30.29 56.68
Share-based Payment Arrangement, Stock Appreciation Right, Activity [Table Text Block]	The SARs vest ratably over a three-year period and may generally be exercised at any point after vesting through ten years from the date of issuance. Pursuant to the terms of the awards, upon exercise, the executive officers will receive, in shares of common stock, the excess of the market price of the award on the date of exercise over the market price of the award on the date of issuance. The following table presents the change in SARs during the nine months ended September 30, 2020: Shares Weighted-Average Outstanding at December 31, 2019 290,258 $ 46.64 Exercised (7,807) 24.44 Expired (71,776) 40.83 Outstanding at September 30, 2020 210,675 49.45

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
Schedule of Earnings Per Share Reconciliation	The following table presents our weighted-average basic and diluted shares outstanding: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Weighted-average common shares outstanding - basic 99,617 62,547 97,762 64,835 Dilutive effect of: RSUs and PSUs — 32 — — Other equity-based awards — 16 — — Weighted-average common shares and equivalents outstanding - diluted 99,617 62,595 97,762 64,835
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following table presents the weighted-average common share equivalents excluded from the calculation of diluted earnings per share due to their anti-dilutive effect: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Weighted-average common share equivalents excluded from diluted earnings per share due to their anti-dilutive effect: RSUs and PSUs 1,831 947 1,715 980 Other equity-based awards 223 267 231 302 Total anti-dilutive common share equivalents 2,054 1,214 1,946 1,282

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2020
Supplemental Cash Flow Elements [Abstract]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	Nine Months Ended September 30, 2020 2019 (in thousands) Supplemental cash flow information: Cash payments (receipts) for: Interest, net of capitalized interest $ 51,556 $ 41,483 Income taxes (204) 261 Non-cash investing and financing activities: Change in accounts payable related to capital expenditures $ (31,403) $ (32,943) Change in asset retirement obligations, with a corresponding change to crude oil and natural gas properties, net of disposals 44,339 13,493 Change in accounts payable related to the purchase and retirement of treasury shares — 2,818 Issuance of common stock for the acquisition of crude oil and natural gas properties, net 1,009,015 — Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6,714 $ 4,107 Operating cash flows from finance leases 155 193 ROU assets obtained in exchange for lease obligations: Operating leases $ 4,217 $ 1,428 Finance leases 703 2,323 Subsequent to the filing of our Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2019, we identified an immaterial error in our condensed consolidated statement of cash flows related to cash paid for capital expenditures for development of crude oil and natural gas properties for the period ended September 30, 2019. Our balance sheet and statement of operations for the relevant period were not impacted. We evaluated the error under the guidance of Accounting Standards Codification 250, Accounting Changes and Error Corrections ("ASC 250"). Based on the guidance in ASC 250, we determined that the error did not have a material impact on our previously-issued financial statements or those of the period of correction. The error resulted in an overstatement of cash flows from operations of $24.8 million and an overstatement of cash used in investing activities of $24.8 million in each period as follows: Nine Months Ended September 30, 2019 (dollars in thousands) Cash flows from operating activities, as reported $ 675,725 Adjustment (24,753) Cash flows from operating activities, as adjusted $ 650,972 Cash flows from investing activities, as reported $ (596,973) Adjustment 24,753 Cash flows from investing activities, as adjusted $ (572,220)

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation Additional Information (Details)	Sep. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Oil and gas producing wells, gross	3,800

Business Combination (Details)

Business Combination (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2020	Jun. 30, 2020	Jan. 14, 2020	Apr. 30, 2019
Business Acquisition [Line Items]
Document Period End Date		Sep. 30, 2020
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	39,000,000
Conversion of Stock, Shares Issued	0.158
Business Acquisition, Transaction Costs	$ 20,200	$ 20,200
Purch Price Adj Disc Cash Flow	10.00%	10.00%
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	$ 1,181,592	$ 1,181,592
Line of Credit Facility, Initial Borrowing Base	2,100,000	2,100,000
Revolving Credit Facility Elected Commitment Amount			$ 1,700,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt	555,500	555,500
Stock Repurchase Program, Authorized Amount				$ 525,000	$ 200,000
SRC Acquisition [Member]
Business Acquisition [Line Items]
Value of Transaction	$ 1,700,000	$ 1,700,000

Business Combination Schedule o

Business Combination Schedule of consideration, assets, and liabilities (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Consideration Transferred	$ 1,181,592
Business Combination, Contingent Consideration, Asset, Current	149,538
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	16,242
Business Combination Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Assets	193,410
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets	13,266
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets	2,089,246
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities	(257,285)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt	(555,500)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other	(41,901)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities	(52,968)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities	(907,654)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	1,181,592
Cash [Member]
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Consideration Transferred	40
Revolving Credit Facility
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Consideration Transferred	166,238
Cash and Cash Equivalents [Member]
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Consideration Transferred	166,278
Common Stock [Member]
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable	1,009,015
Shares withheld in lieu of taxes [Member]
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable	6,299
Proved [Member]
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	1,607,175
Unproved [Member]
Business Acquisition, Contingent Consideration [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	$ 109,615

Business Combination Proforma (

Business Combination Proforma (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Business Combinations [Abstract]
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual	$ 82,000		$ 233,800
Business Acquisition, Pro Forma Income (Loss) from Continuing Operations, Net of Tax	$ 20,700		19,300
Business Acquisition, Pro Forma Revenue		$ 511,110	1,082,003	$ 1,373,739
Business Acquisition, Pro Forma Net Income (Loss)		$ 63,092	$ (677,636)	$ 128,337
Business Acquisition, Pro Forma Earnings Per Share, Basic		$ 0.62	$ (6.79)	$ 1.23
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$ 0.62	$ (6.79)	$ 1.23

Revenue Recognition Revenue by

Revenue Recognition Revenue by Commodity and Location (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenue from Contract with Customer, Excluding Assessed Tax	$ 314,920	$ 307,409	$ 809,156	$ 967,464
Revenue year over year percentage change [Line Items]	2.40%		(16.40%)
Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax	$ 262,050	226,398
Revenue year over year percentage change [Line Items]	15.70%
Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax	$ 52,870	81,011
Revenue year over year percentage change [Line Items]	(34.70%)
Crude Oil [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 226,011	255,718
Revenue year over year percentage change [Line Items]	(11.60%)
Crude Oil [Member] | Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax	$ 183,420	185,543
Revenue year over year percentage change [Line Items]	(1.10%)
Crude Oil [Member] | Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax	$ 42,591	70,175
Revenue year over year percentage change [Line Items]	(39.30%)
Natural Gas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 41,899	26,562
Revenue year over year percentage change [Line Items]	57.70%
Natural Gas [Member] | Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax	$ 39,759	23,949
Revenue year over year percentage change [Line Items]	66.00%
Natural Gas [Member] | Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,140	2,613
Revenue year over year percentage change [Line Items]	(18.10%)
Natural Gas Liquids [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 47,010	25,129
Revenue year over year percentage change [Line Items]	87.10%
Natural Gas Liquids [Member] | Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax	$ 38,871	16,906
Revenue year over year percentage change [Line Items]	129.90%
Natural Gas Liquids [Member] | Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax	$ 8,139	$ 8,223
Revenue year over year percentage change [Line Items]	(1.00%)
Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax			$ 129,394	229,862
Revenue year over year percentage change [Line Items]			(43.70%)
Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax			$ 679,762	737,602
Revenue year over year percentage change [Line Items]			(7.80%)
Crude Oil [Member]
Revenue from Contract with Customer, Excluding Assessed Tax			$ 590,955	760,970
Revenue year over year percentage change [Line Items]			(22.30%)
Crude Oil [Member] | Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax			$ 483,608	569,518
Revenue year over year percentage change [Line Items]			(15.10%)
Crude Oil [Member] | Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax			$ 107,347	191,452
Revenue year over year percentage change [Line Items]			(43.90%)
Natural Gas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax			$ 112,462	110,072
Revenue year over year percentage change [Line Items]			2.20%
Natural Gas [Member] | Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax			$ 109,279	100,779
Revenue year over year percentage change [Line Items]			8.40%
Natural Gas [Member] | Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax			$ 3,183	9,293
Revenue year over year percentage change [Line Items]			(65.70%)
Natural Gas Liquids [Member]
Revenue from Contract with Customer, Excluding Assessed Tax			$ 105,739	96,422
Revenue year over year percentage change [Line Items]			9.70%
Natural Gas Liquids [Member] | Wattenberg Field
Revenue from Contract with Customer, Excluding Assessed Tax			$ 86,875	67,305
Revenue year over year percentage change [Line Items]			29.10%
Natural Gas Liquids [Member] | Delaware Basin
Revenue from Contract with Customer, Excluding Assessed Tax			$ 18,864	$ 29,117
Revenue year over year percentage change [Line Items]			(35.20%)

Revenue Recognition Capitalized

Revenue Recognition Capitalized Contract Costs (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)
Revenue Recognition and Deferred Revenue [Abstract]
Capitalized Contract Cost, Net	$ 11,494
Capitalized Contract Cost, Gross	15,627
Capitalized Contract Cost, Amortization	(1,588)
Capitalized Contract Cost, Net	$ 25,533

Fair Value Measurements and D_3

Fair Value Measurements and Disclosures (Details) - Fair Value - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Assets and Liabilities at Fair Value
Total assets	$ 151,679	$ 31,824
Total liabilities	(110,417)	(3,613)
Net asset (fair value)	41,262	28,211
Significant Other Observable Inputs (Level 2)
Assets and Liabilities at Fair Value
Total assets	130,134	22,886
Total liabilities	(79,658)	(3,089)
Net asset (fair value)	50,476	19,797
Significant Unobservable Inputs (Level 3)
Assets and Liabilities at Fair Value
Total assets	21,545	8,938
Total liabilities	(30,759)	(524)
Net asset (fair value)	$ (9,214)	$ 8,414

Reconciliation of Level 3 Fair

Reconciliation of Level 3 Fair Value Measurements (Details) - Derivative Financial Instrument Net Assets - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Roll-forward of Level 3 Assets
Fair Value, net assets (liabilities), beginning of period	$ 26,958	$ 22,504	$ 8,414	$ 58,329
Fair Value, net assets (liabilities), end of period	(9,215)	30,905	(9,215)	30,905
Commodity Price Risk Management (loss), net
Roll-forward of Level 3 Assets
Changes in fair value included in statement of operations line item:	(21,521)	10,846	32,840	(22,077)
Settlements included in statement of operations line items:	(14,652)	(2,445)	(50,469)	(5,347)
Net change in fair value of unsettled derivatives included in statement of operations line item	$ (13,171)	$ 6,787	$ 9,466	$ (11,620)

Fair Value Measurements and D_4

Fair Value Measurements and Disclosures of Senior Notes (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Accounts, Notes, Loans and Financing Receivable [Line Items]
Impairment Measurement Input	17.00%
1.125% Convertible Senior Notes due 2021 [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Notes Payable, Fair Value Disclosure	$ 192.6	$ 188.6
Senior Notes Percent of Par	96.30%	94.30%
6.125% Senior Notes due 2024 [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Notes Payable, Fair Value Disclosure	$ 382.8	$ 409.2
Senior Notes Percent of Par	95.70%	102.30%
6.25% Senior Notes due 2025 [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Notes Payable, Fair Value Disclosure	$ 96.1	$ 0
Senior Notes Percent of Par	93.90%	0.00%
5.75% Senior Notes due 2026 [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Notes Payable, Fair Value Disclosure	$ 696.8	$ 599.4
Senior Notes Percent of Par	92.90%	99.90%

Derivative Financial Instrume_3

Derivative Financial Instruments Additional Information (Details) MMBTU in Thousands	3 Months Ended	9 Months Ended
	Dec. 31, 2020MMBTU	Sep. 30, 2020MMBTU	Oct. 31, 2020$ / Unit
Natural Gas [Member] | Collars
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		88,633
Natural Gas [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		41,500
2020 | Natural Gas [Member] | Collars
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		17,308
2020 | Natural Gas [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		1,000
2020 | Natural Gas [Member] | Basis Protection - CIG [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		17,350
2021 | Natural Gas [Member] | Collars
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		62,625
2021 | Natural Gas [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		31,800
2021 | Natural Gas [Member] | Basis Protection - CIG [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		94,425
2022 | Natural Gas [Member] | Collars
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		8,700
2022 | Natural Gas [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		8,700
2022 | Natural Gas [Member] | Basis Protection - CIG [Member] | Fixed Price Swaps
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure		17,400
Subsequent Event [Member] | 2022 | Natural Gas [Member] | Commodity Option [Member]
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure	8,700
Subsequent Event [Member] | 2022 | Natural Gas [Member] | Basis Protection - CIG [Member]
Derivatives in Place for Anticipated Production
Derivative, Nonmonetary Notional Amount, Energy Measure	8,700
Natural Gas [Member] | Subsequent Event [Member] | 2022 | CME SWAPS MARKETS (NYMEX) [Member]
Derivatives in Place for Anticipated Production
Derivative, Floor Price | $ / Unit			2.50
Derivative, Cap Price | $ / Unit			3
Natural Gas [Member] | Subsequent Event [Member] | 2022 | CIG [Member]
Derivatives in Place for Anticipated Production
Derivative, Swap Type, Average Fixed Price | $ / Unit			(0.31)

Fair Value of Derivative and Ba

Fair Value of Derivative and Balance Sheet Location (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value
Derivative Asset, Fair Value, Gross Asset	$ 151,679	$ 31,824
Derivative liability, gross	110,417	3,613
Current Assets
Derivatives, Fair Value
Fair Value of Derivatives	0	312
Derivative Asset, Fair Value, Gross Asset	138,652	28,078
Current Liabilities
Derivatives, Fair Value
Fair Value of Derivatives	12,988	2,392
Derivative liability, gross	63,957	2,921
Non Current Liabilities
Derivatives, Fair Value
Fair Value of Derivatives	6,316	0
Derivative liability, gross	46,460	692
Commodity Contracts Related to Natural Gas and Crude Oil Sales | Current Assets
Derivatives, Fair Value
Fair Value of Derivatives	138,652	27,766
Commodity Contracts Related to Natural Gas and Crude Oil Sales | Non Current Assets
Derivatives, Fair Value
Fair Value of Derivatives	13,027	3,746
Commodity Contracts Related to Natural Gas and Crude Oil Sales | Current Liabilities
Derivatives, Fair Value
Fair Value of Derivatives	50,969	529
Commodity Contracts Related to Natural Gas and Crude Oil Sales | Non Current Liabilities
Derivatives, Fair Value
Fair Value of Derivatives	$ 40,144	$ 692

Impact of Derivative Instrument

Impact of Derivative Instruments on Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 66,895	$ 1,845	$ 227,513	$ (19,800)
Net change in fair value of unsettled derivatives	(134,956)	53,022	18,338	(68,058)
Commodity price risk management gain (loss), net	(68,061)	54,867	245,851	(87,858)
Commodity Price Risk Management (loss), net
Derivative [Line Items]
Commodity price risk management gain (loss), net	$ (68,061)	$ 54,867	$ 245,851	$ (87,858)

Derivative Financial Instrume_4

Derivative Financial Instruments Impact of Netting Agreements (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative Asset:
Derivative assets, gross	$ (151,679)	$ (31,824)
Effect of master netting agreements	51,823	2,619
Derivative asset, net	99,856	29,205
Derivative Liability:
Derivative liability, gross	110,417	3,613
Effect of master netting agreements	(51,823)	(2,619)
Derivative liability, net	$ 58,594	$ 994

Derivative Financial Instrume_5

Derivative Financial Instruments Outstanding Derivative Contracts (Details) MMBTU in Thousands, $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)MMBTU$ / UnitMBbls
Derivative [Line Items]
FV Commodity Derivatives Assets measured with Level 3	14.00%
Derivative, Fair Value, Net | $	$ 41,262
FV Commodity Derivatives Liabilities measured with Level 3	28.00%
Natural Gas [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	88,633
Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (37,667)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	41,500
Crude Oil [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	1,896
Crude Oil [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	16,338
Derivative, Fair Value, Net | $	$ 98,233
2020 | Natural Gas [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	17,308
2020 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	1,000
2020 | Crude Oil [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	900
2020 | Crude Oil [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	3,174
Derivative, Fair Value, Net | $	$ 71,119
2021 | Natural Gas [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	62,625
2021 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	31,800
2021 | Crude Oil [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	996
2021 | Crude Oil [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	9,180
Derivative, Fair Value, Net | $	$ 40,547
2022 | Natural Gas [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	8,700
2022 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	8,700
2022 | Crude Oil [Member] | Collars
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	0
2022 | Crude Oil [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	3,984
Derivative, Fair Value, Net | $	$ (13,433)
Natural Gas [Member] | 2020 | Collars | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Floor Price	2.02
Derivative, Cap Price	2.34
Natural Gas [Member] | 2020 | Fixed Price Swaps | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	2.30
Natural Gas [Member] | 2020 | Fixed Price Swaps | CIG [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.48)
Natural Gas [Member] | 2020 | Fixed Price Swaps | Waha [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(1.40)
Natural Gas [Member] | 2021 | Collars | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Floor Price	2.46
Derivative, Cap Price	2.86
Natural Gas [Member] | 2021 | Fixed Price Swaps | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	2.40
Natural Gas [Member] | 2021 | Fixed Price Swaps | CIG [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.46)
Natural Gas [Member] | 2022 | Collars | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Floor Price	2.50
Derivative, Cap Price	2.79
Natural Gas [Member] | 2022 | Fixed Price Swaps | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	2.62
Natural Gas [Member] | 2022 | Fixed Price Swaps | CIG [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.36)
Crude Oil [Member] | 2020 | Collars | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Floor Price	55
Derivative, Cap Price	71.68
Crude Oil [Member] | 2020 | Fixed Price Swaps | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	58.90
Crude Oil [Member] | 2021 | Collars | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Floor Price	35
Derivative, Cap Price	46.22
Crude Oil [Member] | 2021 | Fixed Price Swaps | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	46.90
Crude Oil [Member] | 2022 | Collars | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Floor Price	0
Derivative, Cap Price	0
Crude Oil [Member] | 2022 | Fixed Price Swaps | CME SWAPS MARKETS (NYMEX) [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	40.01
CME SWAPS MARKETS (NYMEX) [Member] | 2020 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (6,576)
CME SWAPS MARKETS (NYMEX) [Member] | 2021 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	(31,070)
CME SWAPS MARKETS (NYMEX) [Member] | 2022 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	(21)
Basis Protection - CIG [Member] | 2020 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (4,627)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	17,350
Basis Protection - CIG [Member] | 2021 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (13,433)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	94,425
Basis Protection - CIG [Member] | 2022 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (733)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	17,400
Basis Protection - Waha [Member] | 2020 | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (511)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	1,000
Basis Protection Contracts Related to Natural Gas Marketing [Member] | Natural Gas [Member] | Fixed Price Swaps
Derivative [Line Items]
Derivative, Fair Value, Net | $	$ (19,304)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	130,175

Properties and Equipment (Detai

Properties and Equipment (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Mar. 31, 2020USD ($)	Sep. 30, 2020USD ($)Wells	Dec. 31, 2019USD ($)Wells	Dec. 31, 2018USD ($)
Property, Plant and Equipment [Line Items]
Document Period End Date		Sep. 30, 2020
Reclassification to Well, Facilities, and Equipment Based on Determination of Proved Reserves	$ (28,011)	$ (20,392)
Proved Natural Gas and Crude Oil Properties		7,389,676	$ 6,241,780
Unproved Natural Gas and Crude Oil Properties		381,428	403,379
Total Natural Gas and Crude Oil Properties		7,771,104	6,645,159
Equipment and other		65,256	41,888
Land and Buildings		24,859	12,312
Construction in Progress		505,930	408,428
Properties and equipment, at cost		8,367,149	7,107,787
Accumulated DD&A		(3,481,915)	(3,012,585)
Property, Plant and Equipment, Net		4,885,234	4,095,202
Capitalized Exploratory Well Cost, Additions Pending Determination of Proved Reserves	31,901	11,540
Capitalized Exploratory Well Costs		$ 7,226	$ 16,078	$ 12,188
Wells to be completed | Wells		2	4
Impairment of properties and equipment	881,100
Delaware Basin Proved Property Impairment	753,000
Delaware Basin Unproved Property Impairment	$ 127,300

Impairment of Natural Gas and C

Impairment of Natural Gas and Crude Oil Properties (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Mar. 31, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)Wells	Sep. 30, 2019USD ($)
Impairment of natural gas and crude oil properties [Line Items]
Oil and Gas, Exploratory Well Drilled, Net Productive, Number | Wells			2
Delaware Basin Proved Property Impairment	$ 753,000
Delaware Basin Unproved Property Impairment	127,300
Results of Operations, Impairment of Oil and Gas Properties	$ 881,100
Midstream Asset Divestitures [Member]
Impairment of natural gas and crude oil properties [Line Items]
Impairment related to midstream facility infrastructure				$ 26,700
Delaware Basin Assets [Member]
Impairment of natural gas and crude oil properties [Line Items]
Results of Operations, Impairment of Oil and Gas Properties			$ 882,300
Impairment of Leasehold		$ 100		$ 10,300

Properties and Equipment Explor

Properties and Equipment Exploration, geologic, and geophysical expense (Details)	9 Months Ended
	Sep. 30, 2020Wells
Property, Plant and Equipment [Line Items]
Oil and Gas, Exploratory Well Drilled, Net Productive, Number	2
Oil and Gas, Exploratory Well Drilled, Net Nonproductive, Number	0

Properties and Equipment Midstr

Properties and Equipment Midstream Asset Divestiture (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Long Lived Assets Held-for-sale [Line Items]
Proceeds from Divestiture of Businesses, Net of Cash Divested		$ 82,000
Residual Proceeds Allocated to Acreage Dedication Agreements			$ 179,600
Gain (Loss) on Disposition of Property Plant Equipment	$ 289		(43,872)	$ 642	$ (9,599)
Midstream Asset Divestitures [Member]
Long Lived Assets Held-for-sale [Line Items]
Proceeds from Sales of Assets, Investing Activities			$ 345,600
Midstream Gas Gathering
Long Lived Assets Held-for-sale [Line Items]
Gain (Loss) on Disposition of Other Assets					$ 34,000

Other Accrued Expense (Details)

Other Accrued Expense (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Schedule of Other Accrued Expense [Line Items]
Asset Retirement Obligation, Current	$ 30,348
Other accrued expenses	81,892	$ 70,462
Current Liabilities
Schedule of Other Accrued Expense [Line Items]
Accrued Employee Benefits, Current	19,833	21,611
Asset Retirement Obligation, Current	30,348	32,200
Accrued Environmental Loss Contingencies, Current	11,988	2,256
Operating and Finance Lease Liability, Current	8,809	5,926
Other Accrued Liabilities	10,914	8,469
Other accrued expenses	$ 81,892	$ 70,462

Other Liabilities (Details)

Other Liabilities (Details) - Non Current Liabilities - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Schedule of Other Liabilities [Line Items]
Production Tax Liability	$ 46,500	$ 68,020
Deferred oil gathering credits	18,593	20,100
Deferred Midstream gathering credits	170,508	175,897
Operating and Finance Lease Liability, Noncurrent	12,494	15,779
Other Accrued Liabilities	2,440	3,337
Other Accrued Liabilities, Noncurrent	$ 250,535	$ 283,133

Other Accrued Expenses Deferred

Other Accrued Expenses Deferred Midstream Gathering Credits (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Deferred Midstream Gathering Credits [Line Items]
Amortization of Other Deferred Charges	$ 500		$ 1,500
Midstream Oil Gathering
Deferred Midstream Gathering Credits [Line Items]
Amortization of Other Deferred Charges	0	$ 201	368	$ 259
Midstream Gas Gathering
Deferred Midstream Gathering Credits [Line Items]
Amortization of Other Deferred Charges	1,535	711	2,991	914
Midstream Water Gathering
Deferred Midstream Gathering Credits [Line Items]
Amortization of Other Deferred Charges	$ 686	$ 373	$ 1,458	$ 557

Schedule of Long-Term Debt (Det

Schedule of Long-Term Debt (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019	Nov. 14, 2017	Sep. 14, 2016
Debt Instrument
Document Period End Date	Sep. 30, 2020
Total senior notes	$ 1,431,607	$ 1,173,226
Debt, Long-term and Short-term, Combined Amount	1,716,607	1,177,226
Long-term debt	1,525,999	1,177,226
Long-term Debt, Current Maturities	190,608	0
1.125% Convertible Senior Notes due 2021 [Member]
Debt Instrument
Principal amount	200,000	200,000
Unamortized Discount	(8,458)	(14,763)
Unamortized Debt Issuance Expense	934	1,666		$ 4,800
Convertible Debt	190,608	183,571
6.125% Senior Notes due 2024 [Member]
Debt Instrument
Unamortized Debt Issuance Expense	3,876	4,611		$ 7,800
Senior Notes, Noncurrent	396,124	395,389
Principal amount	400,000	400,000
6.25% Senior Notes due 2025 [Member]
Debt Instrument
Unamortized Debt Issuance Expense	914	0
Senior Notes, Noncurrent	103,238	0
Principal amount	102,324	0
5.75% Senior Notes due 2026 [Member]
Debt Instrument
Unamortized Discount	(1,490)	0
Unamortized Debt Issuance Expense	6,873	5,734	$ 7,600
Senior Notes, Noncurrent	741,637	594,266
Principal amount	600,000	600,000
Revolving Credit Facility
Debt Instrument
Revolving credit facility	285,000	$ 4,000
5.75% Senior Notes due 2026 [Member]
Debt Instrument
Principal amount	$ 750,000

Long-Term Debt Additional Infor

Long-Term Debt Additional Information (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2020	Oct. 29, 2020	Jun. 30, 2020	Dec. 31, 2019	Jun. 30, 2018	Nov. 14, 2017	Sep. 14, 2016
Debt Instrument
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt	$ 555,500	$ 555,500
Document Period End Date		Sep. 30, 2020
Line of Credit Facility, Initial Borrowing Base	2,100,000	$ 2,100,000
Revolving Credit Facility Elected Commitment Amount				$ 1,700,000
Debt Issuance Costs, Line of Credit Arrangements, Net	$ 9,400	$ 9,400			$ 8,900
Line of Credit Facility, Weighted Average Interest Rate	2.20%	2.20%
1.125% Convertible Senior Notes due 2021 [Member]
Debt Instrument
Debt Instrument, Interest Rate, Stated Percentage	1.125%	1.125%
Debt Instrument, Frequency of Periodic Payment		semi-annually
6.125% Senior Notes due 2024 [Member]
Debt Instrument
Debt Instrument, Interest Rate, Stated Percentage	6.125%	6.125%
Debt Instrument, Frequency of Periodic Payment		semi-annually
6.25% Senior Notes due 2025 [Member]
Debt Instrument
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
Debt Instrument, Frequency of Periodic Payment		semi-annually
Senior Notes ($)	$ 102,300	$ 102,300
5.75% Senior Notes due 2026 [Member]
Debt Instrument
Debt Instrument, Interest Rate, Stated Percentage	5.75%	5.75%
Debt Instrument, Frequency of Periodic Payment		semi-annually
Senior Notes ($)	$ 750,000	$ 750,000
1.125% Convertible Senior Notes due 2021 [Member]
Debt Instrument
Convertible senior notes fair value	$ 200,000	$ 200,000			200,000
Convertible Note, Conversion Price	$ 85.39	$ 85.39
Liability component of gross proceeds of Convertible Notes	$ 160,500	$ 160,500
Debt Instrument, Convertible, Carrying Amount of Equity Component	39,500	39,500
Unamortized Debt Issuance Expense	(934)	(934)			(1,666)			$ (4,800)
Debt Instrument, Unamortized Discount	8,458	8,458			14,763
6.125% Senior Notes due 2024 [Member]
Debt Instrument
Unamortized Debt Issuance Expense	(3,876)	(3,876)			(4,611)			$ (7,800)
Senior Notes ($)	400,000	400,000			400,000
6.25% Senior Notes due 2025 [Member]
Debt Instrument
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt	555,500	$ 555,500
Debt Conversion, Original Debt, Interest Rate of Debt		101.00%
Debt Instrument, Repurchased Face Amount	447,700	$ 447,700
Redemption offer accepted		452,200
Debt Instrument, Repurchase Amount	6,200	6,200
Unamortized Debt Issuance Expense	(914)	(914)			0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt	550,000	550,000
Senior Notes ($)	102,324	102,324			0
5.75% Senior Notes due 2026 [Member]
Debt Instrument
Unamortized Debt Issuance Expense	(6,873)	(6,873)			(5,734)		$ (7,600)
Senior Notes ($)	600,000	600,000			600,000
Debt Instrument, Unamortized Discount	1,490	$ 1,490			0
5.75% Senior Notes due 2026 [Member] | Issuance of additional aggregate principal for 2026 Senior Notes [Member]
Debt Instrument
Debt Conversion, Original Debt, Interest Rate of Debt		99.00%
Unamortized Debt Issuance Expense	(1,800)	$ (1,800)
Senior Notes ($)	150,000	150,000
Proceeds from Debt, Net of Issuance Costs	146,700
Debt Instrument, Unamortized Discount	1,500	1,500
Revolving Credit Facility
Debt Instrument
Long-term Line of Credit	$ 285,000	$ 285,000			$ 4,000
Initial Borrowing Base [Member] | Revolving Credit Facility
Debt Instrument
Line Of Credit Facility Initial Borrowing Capacity						$ 2,500,000
Alternate Base Rate Option [Member]
Debt Instrument
Line of Credit Facility, Interest Rate at Period End	0.75%	0.75%
LIBOR Option [Member]
Debt Instrument
Line of Credit Facility, Interest Rate at Period End	1.75%	1.75%
Unused Commitment Fee [Member]
Debt Instrument
Line of Credit Facility, Interest Rate at Period End	0.375%	0.375%
Subsequent Event [Member]
Debt Instrument
Line of Credit Facility, Initial Borrowing Base			$ 1,600,000
Revolving Credit Facility Elected Commitment Amount			$ 1,600,000

Leases Leases - Narrative (Deta

Leases Leases - Narrative (Details)	9 Months Ended
	Sep. 30, 2020
Lessor, Lease, Description [Line Items]
Document Period End Date	Sep. 30, 2020
Minimum [Member]
Lessor, Lease, Description [Line Items]
Operating and Financing Lease Renewal Term	1 year
Maximum [Member]
Lessor, Lease, Description [Line Items]
Operating and Financing Lease Renewal Term	5 years

Leases Leases - Lease Cost (Det

Leases Leases - Lease Cost (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Lease, Cost [Abstract]
Operating Lease, Cost	$ 2,030	$ 1,093	$ 5,842	$ 3,824
Finance Lease, Right-of-Use Asset, Amortization	473	506	1,462	1,493
Finance Lease, Interest Payment on Liability	44	66	150	195
Finance Lease, Cost	517	572	1,612	1,688
Short-term Lease, Cost	17,975	35,118	149,960	147,223
Lease, Cost	$ 20,522	$ 36,783	$ 157,414	$ 152,735

Leases Leases - Lease Assets an

Leases Leases - Lease Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Assets and Liabilities, Lessee [Abstract]
Operating lease ROU assets	$ 13,484	$ 14,926
Operating lease obligation - short-term	7,183	4,159
Operating lease obligation - long-term	10,496	12,944
Operating Lease, Liability	17,679	17,103
Finance lease ROU assets	3,647	4,637
Finance lease obligation - short-term	1,626	1,767
Finance lease obligation - long-term	1,998	2,835
Finance Lease, Liability	$ 3,624	$ 4,602
Operating Lease, Weighted Average Remaining Lease Term	3 years 1 month 24 days	4 years 3 months 10 days
Finance Lease, Weighted Average Remaining Lease Term	2 years 8 months 19 days	3 years 2 months 1 day
Operating Lease, Weighted Average Discount Rate, Percent	5.00%	5.00%
Finance Lease, Weighted Average Discount Rate, Percent	5.00%	5.00%

Leases Leases - Maturity of Lea

Leases Leases - Maturity of Lease Liabilities Operating (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Leases [Abstract]
2020	$ 2,294
2021	7,055
2022	5,516
2023	1,559
2024	950
Thereafter	1,698
Total Operating Lease Payments	19,072
Less interest and discount operating, total	(1,393)
Operating Lease, Liability	$ 17,679	$ 17,103

Leases Leases - Maturity of L_2

Leases Leases - Maturity of Lease Liabilities Financing (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Leases [Abstract]
2020	$ 496
2021	1,580
2022	955
2023	669
2024	141
Thereafter	9
Total Financing Lease Payments	3,850
Less interest and discount financing, total	(226)
Finance Lease, Liability	$ 3,624	$ 4,602

Leases Leases - Maturity of L_3

Leases Leases - Maturity of Lease Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Operating and Financing Lease Liabilities, Payments, Rolling Maturity [Abstract]
2020	$ 2,790
2021	8,635
2022	6,471
2023	2,228
2024	1,091
Thereafter	1,707
Total Lease Payments	22,922
Less interest and discount, total	(1,619)
Present value of lease liabilities	$ 21,303
Operating Lease, Weighted Average Remaining Lease Term	3 years 1 month 24 days	4 years 3 months 10 days
Finance Lease, Weighted Average Remaining Lease Term	2 years 8 months 19 days	3 years 2 months 1 day

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis
Balance at beginning of period			$ 127,251
Obligations incurred with development activities			7,588
Accretion expense	$ 2,420	$ 1,356	7,398	$ 4,503
Obligations discharged asset retirements			(25,545)
Balance end of period	163,704		163,704
Less current portion	(30,348)		(30,348)
Asset retirement obligations	$ 133,356		133,356		$ 95,051
Asset Retirement Obligation, Revision of Estimate			(146)
SRC [Domain]
Asset Retirement Obligation, Roll Forward Analysis
Obligations incurred with development activities			$ 47,158

Commitments and Contingencies_2

Commitments and Contingencies Commitments and Contigencies (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)MMcfMBbls
Supply Commitment
Dollar Commitment ($ in thousands) | $	$ 543,174
First Year Commitment [Member]
Supply Commitment
Dollar Commitment ($ in thousands) | $	140,186
Second Year Commitment [Member]
Supply Commitment
Dollar Commitment ($ in thousands) | $	117,235
Third Year Commitment [Member]
Supply Commitment
Dollar Commitment ($ in thousands) | $	97,036
Fourth Year Commitment [Member]
Supply Commitment
Dollar Commitment ($ in thousands) | $	70,981
commitments 5 years and beyond [Member]
Supply Commitment
Dollar Commitment ($ in thousands) | $	$ 117,736
First facilities agreement with midstream provider [Member]
Supply Commitment
Incremental volume commitment	51.5
incremental volume commitment	97.9
Second facilities agreement with midstream provider [Member]
Supply Commitment
Incremental volume commitment	33.5
incremental volume commitment	77.3
Natural Gas (MMcf) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	477,967
Natural Gas (MMcf) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	103,061
Natural Gas (MMcf) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	84,660
Natural Gas (MMcf) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	73,047
Natural Gas (MMcf) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	73,248
Natural Gas (MMcf) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	143,951
Crude Oil (MBbls) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	100,953
Crude Oil (MBbls) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	25,552
Crude Oil (MBbls) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	23,530
Crude Oil (MBbls) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	21,065
Crude Oil (MBbls) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	11,906
Crude Oil (MBbls) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	18,900
Wattenberg Field | Natural Gas (MMcf) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	342,740
Wattenberg Field | Natural Gas (MMcf) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	63,922
Wattenberg Field | Natural Gas (MMcf) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	63,922
Wattenberg Field | Natural Gas (MMcf) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	63,922
Wattenberg Field | Natural Gas (MMcf) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	64,098
Wattenberg Field | Natural Gas (MMcf) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	86,876
Wattenberg Field | Natural Gas (MMcf) [Member] | Supply Contract Expiration Date [Member]
Supply Commitment
Supply Commitments Contract Expiration Date	Aug. 31, 2026
Wattenberg Field | Crude Oil (MBbls) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	74,655
Wattenberg Field | Crude Oil (MBbls) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	17,338
Wattenberg Field | Crude Oil (MBbls) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	15,500
Wattenberg Field | Crude Oil (MBbls) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	13,035
Wattenberg Field | Crude Oil (MBbls) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	9,882
Wattenberg Field | Crude Oil (MBbls) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	18,900
Wattenberg Field | Crude Oil (MBbls) [Member] | Supply Contract Expiration Date [Member]
Supply Commitment
Supply Commitments Contract Expiration Date	Aug. 31, 2026
Wattenberg Field | Water (MBbls) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	26,408
Wattenberg Field | Water (MBbls) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	6,207
Wattenberg Field | Water (MBbls) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	6,207
Wattenberg Field | Water (MBbls) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	6,206
Wattenberg Field | Water (MBbls) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	6,224
Wattenberg Field | Water (MBbls) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	1,564
Wattenberg Field | Water (MBbls) [Member] | Supply Contract Expiration Date [Member]
Supply Commitment
Supply Commitments Contract Expiration Date	Dec. 31, 2024
Delaware Basin | Natural Gas (MMcf) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	121,882
Delaware Basin | Natural Gas (MMcf) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	32,022
Delaware Basin | Natural Gas (MMcf) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	14,510
Delaware Basin | Natural Gas (MMcf) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	9,125
Delaware Basin | Natural Gas (MMcf) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	9,150
Delaware Basin | Natural Gas (MMcf) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	57,075
Delaware Basin | Natural Gas (MMcf) [Member] | Supply Contract Expiration Date [Member]
Supply Commitment
Supply Commitments Contract Expiration Date	Mar. 31, 2031
Delaware Basin | Crude Oil (MBbls) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	26,298
Delaware Basin | Crude Oil (MBbls) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	8,214
Delaware Basin | Crude Oil (MBbls) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	8,030
Delaware Basin | Crude Oil (MBbls) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	8,030
Delaware Basin | Crude Oil (MBbls) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	2,024
Delaware Basin | Crude Oil (MBbls) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes | MBbls	0
Delaware Basin | Crude Oil (MBbls) [Member] | Supply Contract Expiration Date [Member]
Supply Commitment
Supply Commitments Contract Expiration Date	Dec. 31, 2023
Appalachiain Basin | Natural Gas (MMcf) [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	13,345
Appalachiain Basin | Natural Gas (MMcf) [Member] | First Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	7,117
Appalachiain Basin | Natural Gas (MMcf) [Member] | Second Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	6,228
Appalachiain Basin | Natural Gas (MMcf) [Member] | Third Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	0
Appalachiain Basin | Natural Gas (MMcf) [Member] | Fourth Year Commitment [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	0
Appalachiain Basin | Natural Gas (MMcf) [Member] | commitments 5 years and beyond [Member]
Supply Commitment
Oil and Gas Delivery Commitments Volumes	0
Appalachiain Basin | Natural Gas (MMcf) [Member] | Supply Contract Expiration Date [Member]
Supply Commitment
Supply Commitments Contract Expiration Date	Aug. 31, 2022

Commitments and Contingencies A

Commitments and Contingencies Additional information (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)bblMMcf	Sep. 30, 2019USD ($)
Loss Contingencies [Line Items]
Document Period End Date			Sep. 30, 2020
First facilities agreement with midstream provider [Member]
Loss Contingencies [Line Items]
incremental volume commitment | MMcf			97.9
Delaware Basin/Wattenberg Field [Member]
Loss Contingencies [Line Items]
Transportation netted against Revenue | $	$ 4.5	$ 13.7	$ 17.6	$ 36.8
Minimum [Member] | Delaware Basin
Loss Contingencies [Line Items]
Committed Barrels of Crude Oil per day			24,000
Maximum [Member] | Delaware Basin
Loss Contingencies [Line Items]
Committed Barrels of Crude Oil per day			22,000

Commitments and Contingencies N

Commitments and Contingencies New Plant (Details)	9 Months Ended
	Sep. 30, 2020MMcf
Natural Gas (MMcf) [Member]
Property, Plant and Equipment [Line Items]
Qualitative and Quantitative Information, Transferor's Continuing Involvement, Third Party Commitments	200
First facilities agreement with midstream provider [Member]
Property, Plant and Equipment [Line Items]
incremental volume commitment	97.9
Second facilities agreement with midstream provider [Member]
Property, Plant and Equipment [Line Items]
incremental volume commitment	77.3
SRC [Domain] | First facilities agreement with midstream provider [Member]
Property, Plant and Equipment [Line Items]
incremental volume commitment	46.4
SRC [Domain] | Second facilities agreement with midstream provider [Member]
Property, Plant and Equipment [Line Items]
incremental volume commitment	43.8

Common Stock Stock Based Compen

Common Stock Stock Based Compensation Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Jun. 30, 2020	Mar. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Expense	$ 5,400	$ 5,900	$ 17,400	$ 18,100
Common Stock, Capital Shares Reserved for Future Issuance					7,050,000	1,800,000
2018 Equity Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock shares remain avaliable for issuance	5,244,358		5,244,358
2010 Long-Term Equity Compensation Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock shares remain avaliable for issuance	159,237		159,237

Common Stock COMMON STOCK Restr

Common Stock COMMON STOCK Restricted Stock - Time Based Awards (Details) - Restricted stock - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award	The fair value of the time-based RSUs is amortized ratably over the requisite service period, primarily three years. The time-based RSUs generally vest ratably on each anniversary following the grant date provided that a participant is continuously employed.
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	1,201,747		795,926
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 20.42		$ 45.51
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	1,151,273
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 12	$ 40.38
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	444,611
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 41.87
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	300,841
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 22.87
Aggregate intrinsic value of non-vested awards	$ 14,896	$ 22,673
Share Price	$ 12.40	$ 27.75
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 15,700
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	2 years
Service Vesting Period
Total intrinsic value of time based awards vested	$ 6,124	$ 11,251

Common Stock COMMON STOCK Res_2

Common Stock COMMON STOCK Restricted Stock - Market Based Awards (Details) - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Jan. 14, 2020	Dec. 31, 2019	Apr. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Repurchase Program, Authorized Amount			$ 525,000		$ 200,000
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Shares Payout Range	0.00%
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Shares Payout Range	250.00%
Restricted Stock - Market Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award	The fair value of the market-based PSUs is amortized ratably over the requisite service period, primarily three years. The market-based shares vest if the participant is continuously employed throughout the performance period and the market-based performance measure is achieved, with a maximum vesting period of three years. All compensation cost related to the market-based awards will be recognized if the requisite service period is fulfilled, even if the market condition is not achieved.
Market based performance shares granted to executives	368,077
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	3 years	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.40%	2.50%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	46.60%	41.40%
Aggregate intrinsic value of non-vested awards	$ 7,999	$ 6,719
Share Price	$ 12.40	$ 27.75
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 33.52	$ 56.68
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 9,300
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	1 year 8 months 12 days
Restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award	The fair value of the time-based RSUs is amortized ratably over the requisite service period, primarily three years. The time-based RSUs generally vest ratably on each anniversary following the grant date provided that a participant is continuously employed.
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	1,201,747			795,926
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	1,151,273
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 20.42			$ 45.51
Aggregate intrinsic value of non-vested awards	$ 14,896	$ 22,673
Share Price	$ 12.40	$ 27.75
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 12	$ 40.38
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 15,700
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	2 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	444,611
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 41.87
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(300,841)
Restricted Stock - Market Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	2 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.60%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	56.90%
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Grant Date Intrinsic Value	$ 33.35
SRC [Domain] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Shares Payout Range	0.00%
SRC [Domain] | Maximum Borrowing Base [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Shares Payout Range	200.00%
SRC [Domain] | Restricted Stock - Market Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Market based performance shares granted to executives	155,928
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	645,354			221,142
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	524,005
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 39.06			$ 61.61
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 30.29
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(10,196)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 12.44
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(89,597)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$ 46.43

Common Stock COMMON STOCK Stock

Common Stock COMMON STOCK Stock Appreciation Rights (Details) - USD ($) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Restricted Stock - Market Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 9.3
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	1 year 8 months 12 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 33.52	$ 56.68
Restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	1,201,747		795,926
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 15.7
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	2 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 20.42		$ 45.51
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	1,151,273
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 12	$ 40.38
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	444,611
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 41.87
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	300,841
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	210,675		290,258
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price	$ 49.45		$ 46.64
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	(7,807)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Exercise Price	$ 24.44
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period	(71,776)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$ 40.83
SRC [Domain] | Restricted Stock - Market Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	645,354		221,142
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$ 46.43
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 39.06		$ 61.61
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	524,005
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 30.29
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(10,196)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 12.44
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	89,597

Common Stock Preferred Stock (D

Common Stock Preferred Stock (Details) - $ / shares	Sep. 30, 2020	Dec. 31, 2019	Jun. 23, 2008
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Preferred Stock, Shares Authorized	50,000,000	50,000,000
Preferred Stock, Shares Issued	0	0
Preferred stock, par value	$ 0.01	$ 0.01	$ 0.01
Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Preferred Stock, Shares Authorized			50,000,000
Preferred Stock, Shares Issued	0

Common Stock Stock Repurchase (

Common Stock Stock Repurchase (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Jan. 14, 2020	Apr. 30, 2019
Equity, Class of Treasury Stock [Line Items]
Document Period End Date				Sep. 30, 2020
Stock Repurchase Program, Authorized Amount						$ 525,000	$ 200,000
Payments for Repurchase of Common Stock				$ 8,412	$ 3,874
Treasury Stock, Common [Member]
Equity, Class of Treasury Stock [Line Items]
Stock Repurchased During Period, Shares	(1,266,000)	(1,228,310)	(3,136,406)	1,300,000
Payments for Repurchase of Common Stock				$ 23,800
Treasury Stock remaining to be repurchased				$ 346,800

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Operating Loss Carryforwards [Line Items]
Results of Operations, Impairment of Oil and Gas Properties		$ 881.1
Deferred Tax Assets, Operating Loss Carryforwards, Domestic	$ 470			$ 470
Effective Income Tax Rate, Continuing Operations	(0.60%)		40.10%	0.50%	10.40%
Delaware Basin Assets [Member]
Operating Loss Carryforwards [Line Items]
Results of Operations, Impairment of Oil and Gas Properties				$ 882.3

Earnings Per Share (Details)

Earnings Per Share (Details) - $ / shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Earnings Per Share, Basic, by Common Class, Including Two Class Method
Document Period End Date			Sep. 30, 2020
Reconciliation of Weighted-Average Diluted Shares Outstanding
Weighted Average Number of Shares Outstanding, Basic	99,617	62,547	97,762	64,835
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0	32	0	0
Anti-dilutive Effect
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2,054	1,214	1,946	1,282
Convertible Senior Note
Convertible Note, Shares To Be Received Upon Conversion (in thousands)			2,300
Restricted stock
Anti-dilutive Effect
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	1,831	947	1,715	980
Stock Appreciation Rights (SARs) [Member]
Reconciliation of Weighted-Average Diluted Shares Outstanding
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0	16	0	0
Anti-dilutive Effect
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	223	267	231	302
1.125% Convertible Senior Notes due 2021 [Member]
Convertible Senior Note
Convertible Note, Conversion Price	$ 85.39		$ 85.39

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) shares in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Supplemental Cash Flow Elements [Line Items]
Interest, net of capitalized interest	$ 51,556,000	$ 41,483,000
Income taxes	(204,000)	261,000
Capital Expenditures Incurred but Not yet Paid	(31,403,000)	(32,943,000)
Increase (Decrease) in Asset Retirement Obligations	44,339,000	13,493,000
Change in accounts payable related to the purchase and retirement of treasury shares [Line Items]	$ 0	$ 2,818,000
Noncash or Part Noncash Acquisition, Noncash Financial or Equity Instrument Consideration, Shares Issued	1,009,015	0
Operating Lease, Payments	$ 6,714,000	$ 4,107,000
Operating Cash Flow from Financing Leases	155,000	193,000
Finance Lease, Principal Payments	1,454,000	1,492,000
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	4,217,000	1,428,000
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	$ 703,000	$ 2,323,000

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information Correction of Error (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	$ 24,800
Sept 19 Cash from Ops as reported [Domain]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	675,725
Sept 19 Cash from Ops Adjustment [Domain]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	(24,753)
Sept 19 Cash from Ops as Adjusted [Domain]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	650,972
Sept 19 Cash from Investing as Reported [Domain]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	(596,973)
Sept 19 Cash from Investing Adjustment [Domain]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	24,753
Sept 19 Cash from Investing as Adjusted [Domain]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Immaterial Error Correction	$ (572,220)