Cimarex Energy (CIMXP) 10-Q 6 May 21 2021 Q1 Quarterly report Financial data

Cover Page

Cover Page - shares	3 Months Ended
	Mar. 31, 2021	Apr. 30, 2021
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2021
Document Transition Report	false
Entity File Number	001-31446
Entity Registrant Name	CIMAREX ENERGY CO
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	45-0466694
Entity Address, Address Line One	1700 Lincoln Street, Suite 3700
Entity Address, City or Town	Denver
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80203
City Area Code	303
Local Phone Number	295-3995
Title of 12(b) Security	Common Stock ($0.01 par value)
Trading Symbol	XEC
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		102,818,796
Entity Central Index Key	0001168054
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q1
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 523,798	$ 273,145
Accounts receivable, net of allowance:
Trade	65,272	49,650
Oil and gas sales	348,594	271,141
Gas gathering, processing, and marketing	13,098	11,694
Oil and gas well equipment and supplies	30,846	37,150
Derivative instruments	173	6,848
Prepaid expenses	5,875	7,113
Other current assets	429	597
Total current assets	988,085	657,338
Oil and gas properties at cost, using the full cost method of accounting:
Proved properties	21,374,434	21,281,840
Unproved properties and properties under development, not being amortized	1,203,910	1,142,183
Gross oil and gas properties	22,578,344	22,424,023
Less—accumulated depreciation, depletion, amortization, and impairment	(19,083,054)	(18,987,354)
Net oil and gas properties	3,495,290	3,436,669
Fixed assets, net of accumulated depreciation of $472,961 and $455,815, respectively	410,347	436,101
Derivative instruments	2,376	2,342
Deferred income taxes	0	20,472
Other assets	69,023	69,067
Total assets	4,965,121	4,621,989
Accounts payable:
Trade	39,505	21,902
Gas gathering, processing, and marketing	38,587	22,388
Accrued liabilities:
Exploration and development	68,550	50,014
Taxes other than income	38,661	29,051
Other	208,359	201,784
Derivative instruments	233,296	145,398
Revenue payable	201,935	130,637
Operating leases	57,120	59,051
Total current liabilities	886,013	660,225
Long-term debt principal	2,000,000	2,000,000
Less—unamortized debt issuance costs and discounts	(12,186)	(12,701)
Long-term debt, net	1,987,814	1,987,299
Deferred income taxes	19,698	0
Asset retirement obligation	166,542	165,595
Derivative instruments	22,611	17,749
Operating leases	122,720	134,705
Other liabilities	59,177	66,181
Total liabilities	3,264,575	3,031,754
Commitments and contingencies (Note 10)
Redeemable preferred stock - 8.125% Series A Cumulative Perpetual Convertible Preferred Stock, $0.01 par value, 28,165 shares authorized and issued (Note 5)	36,781	36,781
Stockholders’ equity:
Common stock, $0.01 par value, 200,000,000 shares authorized, 102,827,556 and 102,866,806 shares issued, respectively	1,028	1,029
Additional paid-in capital	3,193,760	3,211,562
Accumulated deficit	(1,531,023)	(1,659,137)
Total stockholders’ equity	1,663,765	1,553,454
Total liabilities and stockholders' equity	$ 4,965,121	$ 4,621,989

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Statement of Financial Position [Abstract]
Accumulated depreciation on fixed assets	$ 472,961	$ 455,815
Redeemable preferred stock dividend rate (as a percent)	8.125%	8.125%
Redeemable preferred stock, par value (USD per share)	$ 0.01	$ 0.01
Redeemable preferred stock authorized (shares)	28,165	28,165
Redeemable preferred stock issued (shares)	28,165	28,165
Common stock, par value (USD per share)	$ 0.01	$ 0.01
Common stock authorized (shares)	200,000,000	200,000,000
Common stock issued (shares)	102,827,556	102,866,806

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Revenues:
Revenues	$ 679,466	$ 472,830
Costs and expenses:
Impairment of oil and gas properties	0	333,651
Depreciation, depletion, and amortization	112,934	215,086
Asset retirement obligation	2,218	4,724
Impairment of goodwill	0	714,447
Production	74,806	87,236
Transportation, processing, and other operating	63,607	54,922
Gas gathering and other	10,478	8,298
Taxes other than income	40,986	30,961
General and administrative	25,260	25,509
Stock-based compensation	8,549	6,394
Loss (gain) on derivative instruments, net	161,935	(226,940)
Other operating expense, net	(933)	251
Total costs and expenses	499,840	1,254,539
Operating income (loss)	179,626	(781,709)
Other (income) and expense:
Interest expense	23,078	23,181
Capitalized interest	(11,565)	(13,182)
Other, net	(139)	(871)
Income (loss) before income tax	168,252	(790,837)
Income tax expense (benefit)	40,170	(16,555)
Net income (loss)	$ 128,082	$ (774,282)
Earnings (loss) per share to common stockholders:
Basic (USD per share)	$ 1.25	$ (7.77)
Diluted (USD per share)	$ 1.25	$ (7.77)
Oil sales
Revenues:
Revenues	$ 344,704	$ 360,980
Gas and NGL sales
Revenues:
Revenues	325,398	98,481
Gas gathering and other
Revenues:
Revenues	12,215	13,583
Gas marketing
Revenues:
Revenues	$ (2,851)	$ (214)

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash flows from operating activities:
Net (loss) income	$ 128,082	$ (774,282)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Impairment of oil and gas properties	0	333,651
Depreciation, depletion, and amortization	112,934	215,086
Asset retirement obligation	2,218	4,724
Impairment of goodwill	0	714,447
Deferred income taxes	40,170	(16,357)
Stock-based compensation	8,549	6,394
Loss (gain) on derivative instruments, net	161,935	(226,940)
Settlements on derivative instruments	(62,534)	43,114
Amortization of debt issuance costs and discounts	887	784
Changes in non-current assets and liabilities	(744)	2,410
Other, net	3,675	3,390
Changes in operating assets and liabilities:
Accounts receivable	(94,500)	119,605
Other current assets	774	(24)
Accounts payable and other current liabilities	101,466	(117,211)
Net cash provided by operating activities	402,912	308,791
Cash flows from investing activities:
Oil and gas capital expenditures	(130,007)	(258,820)
Acquisition of oil and gas properties	(310)	(7,250)
Other capital expenditures	(3,531)	(26,425)
Sales of oil and gas assets	5,035	830
Sales of other assets	385	181
Net cash used by investing activities	(128,428)	(291,484)
Cash flows from financing activities:
Borrowings of long-term debt	0	101,000
Repayments of long-term debt	0	(101,000)
Financing fees	(100)	(100)
Finance lease payments	(1,067)	(1,465)
Dividends paid	(23,049)	(21,593)
Employee withholding taxes paid upon the net settlement of equity-classified stock awards	0	(165)
Proceeds from exercise of stock options	385	0
Net cash used by financing activities	(23,831)	(23,323)
Net change in cash and cash equivalents	250,653	(6,016)
Cash and cash equivalents at beginning of period	273,145	94,722
Cash and cash equivalents at end of period	$ 523,798	$ 88,706

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Additional Paid-in Capital	Accumulated Deficit
Balance at beginning of period (shares) at Dec. 31, 2019		102,145
Balance at beginning of period at Dec. 31, 2019	$ 3,576,141	$ 1,021	$ 3,243,325	$ 331,795
Increase (Decrease) in Stockholders' Equity
Dividends paid on stock awards subsequently forfeited	29		6	23
Dividends declared on common stock	(22,548)			(22,548)
Dividends declared on redeemable preferred stock	(1,269)			(1,269)
Net income	(774,282)			(774,282)
Common stock reacquired and retired (shares)		(12)
Common stock reacquired and retired	(165)		(165)
Restricted stock forfeited and retired (shares)		(31)
Stock-based compensation	11,594		11,594
Balance at end of period (shares) at Mar. 31, 2020		102,102
Balance at end of period at Mar. 31, 2020	2,789,500	$ 1,021	3,254,760	(466,281)
Balance at beginning of period (shares) at Dec. 31, 2020		102,867
Balance at beginning of period at Dec. 31, 2020	1,553,454	$ 1,029	3,211,562	(1,659,137)
Increase (Decrease) in Stockholders' Equity
Dividends paid on stock awards subsequently forfeited	46		14	32
Dividends declared on common stock	(27,845)		(27,845)	0
Dividends declared on redeemable preferred stock	(572)		(572)	0
Net income	128,082			128,082
Issuance of restricted stock awards (shares)		25
Restricted stock forfeited and retired (shares)		(73)
Restricted stock forfeited and retired	0	$ (1)	1
Exercise of stock options (shares)		9
Exercise of stock options	385		385
Stock-based compensation	10,215		10,215
Balance at end of period (shares) at Mar. 31, 2021		102,828
Balance at end of period at Mar. 31, 2021	$ 1,663,765	$ 1,028	$ 3,193,760	$ (1,531,023)

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Stockholders' Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Common Stock
Dividends declared per common share (USD per share)	$ 0.27	$ 0.22
Preferred Stock
Dividends declared per preferred share (USD per share)	$ 20.3125	$ 20.3125

BASIS OF PRESENTATION

BASIS OF PRESENTATION	3 Months Ended
	Mar. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF PRESENTATION	BASIS OF PRESENTATION Cimarex Energy Co. (“Cimarex,” “company,” “we,” or “us”), a Delaware corporation, is an independent oil and gas exploration and production company. Our operations are located entirely within the United States, mainly in Texas, New Mexico, and Oklahoma. The accompanying unaudited financial statements have been prepared pursuant to rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain disclosures required by accounting principles generally accepted in the United States and normally included in Annual Reports on Form 10-K have been omitted. Although management believes that our disclosures in these interim financial statements are adequate, they should be read in conjunction with the financial statements, summary of significant accounting policies, and footnotes included in our Annual Report on Form 10-K for the year ended December 31, 2020. In the opinion of management, the accompanying financial statements reflect all adjustments necessary to fairly present our financial position, results of operations, and cash flows for the periods and as of the dates shown. The accounts of Cimarex and its subsidiaries are presented in the accompanying financial statements, with intercompany balances and transactions eliminated in consolidation. Certain amounts in the prior year financial statements have been reclassified to conform to the 2021 financial statement presentation. Use of Estimates Areas of significance requiring the use of management’s judgments include the estimation of proved oil and gas reserves used in calculating depletion, the estimation of future net revenues used in computing ceiling test limitations, and the estimation of future abandonment obligations used in recording asset retirement obligations. Estimates and judgments also are required in determining allowances for credit losses, impairments of unproved properties and other assets, valuation of deferred tax assets, fair value measurements, lease liabilities, and contingencies. We analyze our estimates and base them on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Actual results may differ from these estimates under different assumptions or conditions. Oil and Gas Well Equipment and Supplies Our oil and gas well equipment and supplies are valued at the lower of cost and net realizable value, where net realizable value is based on estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. Declines in the price of oil and gas well equipment and supplies in future periods could cause us to recognize impairments on these assets. An impairment would not affect cash flow from operating activities, but would adversely affect our net income and stockholders’ equity. Oil and Gas Properties We use the full cost method of accounting for our oil and gas operations. All costs associated with property acquisition, exploration, and development activities are capitalized. Under the full cost method of accounting, we are required to perform a quarterly ceiling test calculation to test our oil and gas properties for possible impairment. If the net capitalized cost of our oil and gas properties, as adjusted for income taxes, exceeds the ceiling limitation, the excess is charged to expense. The ceiling limitation is equal to the sum of: (i) the present value discounted at 10% of estimated future net revenues from proved reserves, (ii) the cost of properties not being amortized, and (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized, as adjusted for income taxes. We currently do not have any unproven properties that are being amortized. Estimated future net revenues are determined based on trailing twelve-month average commodity prices and estimated proved reserve quantities, operating costs, and capital expenditures. The quarterly ceiling test is primarily impacted by commodity prices, changes in estimated reserve quantities, overall exploration and development costs, and deferred taxes. If pricing conditions decline, or if there is a negative impact on one or more of the other components of the calculation, we may incur a full cost ceiling test impairment. The calculated ceiling limitation is not intended to be indicative of the fair market value of our proved reserves or future results. Impairment charges do not affect cash flow from operating activities, but do adversely affect our net income and various components of our balance sheet. Any impairment of oil and gas properties is not reversible at a later date. We did not incur a ceiling test impairment for the three months ended March 31, 2021. At March 31, 2021, a decline in the value of the ceiling limitation of approximately 12% or more would have resulted in an impairment. For the three months ended March 31, 2020, we incurred a $333.7 million ceiling test impairment resulting primarily from the impact of decreases in the 12-month average trailing prices for oil, gas, and NGLs as well as significant basis differentials utilized in determining the estimated future net cash flows from proved reserves. Goodwill Goodwill represents the excess of the purchase price of business combinations over the fair value of the net assets acquired and is tested for impairment at least annually. During the three months ended March 31, 2020, the company’s market capitalization declined significantly, caused by macroeconomic and geopolitical conditions including the collapse of oil prices driven by surplus supply and decreased demand caused by the COVID-19 pandemic. In addition, the uncertainty related to oil demand significantly impacted our investment and operating decisions at the time. As a result of these events and circumstances, we performed an interim quantitative impairment test for goodwill as of March 31, 2020, which utilized quoted market prices for our common stock as a basis for determining the fair value of our reporting unit. Based upon this test, we concluded that goodwill was fully impaired at March 31, 2020. The following table reflects components of the change in the carrying amount of goodwill for the three months ended March 31, 2020 (subsequent to March 31, 2020 through March 31, 2021 we have not recognized any additional goodwill balance): (in thousands) Three Months Ended Goodwill balance at January 1, 2020 $ 716,865 Business combination purchase price adjustments (2,418) Impairment (714,447) Goodwill balance at March 31, 2020 $ — Revenue Recognition Oil, Gas, and NGL Sales Revenue is recognized from the sales of oil, gas, and NGLs when the customer obtains control of the product, when we have no further obligations to perform related to the sale, and when collectability is probable. All of our sales of oil, gas, and NGLs are made under contracts with customers, which typically include variable consideration based on monthly pricing tied to local indices and monthly volumes delivered. The nature of our contracts with customers does not require us to constrain that variable consideration or to estimate the amount of transaction price attributable to future performance obligations for accounting purposes. As of March 31, 2021, we had open contracts with customers with terms of one month to multiple years, as well as “evergreen” contracts that renew on a periodic basis if not canceled by us or the customer. Performance obligations under our contracts with customers are typically satisfied at a point-in-time through monthly delivery of oil, gas, and/or NGLs. Our contracts with customers typically require payment within one month of delivery. Our gas is sold under various contracts. Under these contracts the gas and its components, including residue gas and NGLs, may be sold to a single purchaser or separate purchasers. Regardless of the contract, we are compensated for the value of the residue gas and NGLs at current market prices for each product. Depending on the specific contract terms, certain gathering, treating, transportation, processing, and other charges may be deducted against the prices we receive for the products. Our oil typically is sold at specific delivery points under contract terms that are common in our industry. Gas Gathering When we transport, process, and/or market third-party gas associated with our equity gas, we recognize revenue for the fees charged to third-parties for such services. Gas Marketing When we market and sell gas for other working interest owners, we act as agent under short-term sales and supply agreements and may earn a fee for such services. Revenues from such services are recognized as gas is delivered. Gas Imbalances Revenue from the sale of gas is recorded on the basis of gas actually sold by or for us. If our aggregate sales volumes for a well are greater (or less) than our proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented.

LONG-TERM DEBT

LONG-TERM DEBT	3 Months Ended
	Mar. 31, 2021
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT Long-term debt at March 31, 2021 and December 31, 2020 consisted of the following: March 31, 2021 December 31, 2020 (in thousands) Principal Unamortized Debt Issuance Costs and Discounts (1) Long-term Principal Unamortized Debt Issuance Costs and Discounts (1) Long-term 4.375% Notes due 2024 $ 750,000 $ (2,462) $ 747,538 $ 750,000 $ (2,672) $ 747,328 3.90% Notes due 2027 750,000 (5,350) 744,650 750,000 (5,541) 744,459 4.375% Notes due 2029 500,000 (4,374) 495,626 500,000 (4,488) 495,512 $ 2,000,000 $ (12,186) $ 1,987,814 $ 2,000,000 $ (12,701) $ 1,987,299 ________________________________________ (1) The 4.375% Notes due 2024 were issued at par, therefore, the amounts shown in the table are for unamortized debt issuance costs only. At March 31, 2021, the unamortized debt issuance costs and discount related to the 3.90% Notes due 2027 were $4.1 million and $1.2 million, respectively. At March 31, 2021, the unamortized debt issuance costs and discount related to the 4.375% Notes due 2029 were $3.8 million and $0.6 million, respectively. At December 31, 2020, the unamortized debt issuance costs and discount related to the 3.90% Notes due 2027 were $4.3 million and $1.3 million, respectively. At December 31, 2020, the unamortized debt issuance costs and discount related to the 4.375% Notes due 2029 were $3.9 million and $0.6 million, respectively. Bank Debt On June 3, 2020, we entered into the First Amendment to Amended and Restated Credit Agreement (the “First Amendment”) dated as of February 5, 2019 for our senior unsecured revolving credit facility (“Credit Facility”). The Credit Facility has aggregate commitments of $1.25 billion with an option for us to increase the aggregate commitments to $1.5 billion, and matures on February 5, 2024. There is no borrowing base subject to the discretion of the lenders based on the value of our proved reserves under the Credit Facility. The First Amendment, among other things: (i) allows up to $3.5 billion of non-cash impairment charge add-backs to Shareholders’ Equity for covenant calculation purposes, (ii) institutes traditional anti-cash hoarding provisions (if borrowings are outstanding under the Credit Facility) at a consolidated cash threshold of $175.0 million, (iii) reduces the priority lien debt basket from 15% of Consolidated Net Tangible Assets (as defined in the credit agreement) to a $50.0 million cap, and (iv) adds an acknowledgement and consent to European Union bail-in legislation. As of March 31, 2021, we had no bank borrowings outstanding under the Credit Facility, but did have letters of credit of $2.5 million outstanding, leaving an unused borrowing availability of $1.248 billion. At our option, borrowings under the Credit Facility may bear interest at either (a) LIBOR (or an alternate rate determined by the administrative agent for the Credit Facility in accordance with the Credit Facility when LIBOR is no longer available) plus 1.125 – 2.0% based on the credit rating for our senior unsecured long-term debt, or (b) a base rate (as defined in the credit agreement) plus 0.125 – 1.0%, based on the credit rating for our senior unsecured long-term debt. Unused borrowings are subject to a commitment fee of 0.125 – 0.35%, based on the credit rating for our senior unsecured long-term debt. The Credit Facility contains representations, warranties, covenants, and events of default that are customary for investment grade, senior unsecured bank credit agreements, including a financial covenant for the maintenance of a defined total debt-to-capitalization ratio of no greater than 65%. As of March 31, 2021, we were in compliance with all of the financial covenants. At March 31, 2021 and December 31, 2020, we had $4.0 million and $4.3 million, respectively, of unamortized debt issuance costs associated with our Credit Facility, which were recorded as assets and included in “Other assets” on our Condensed Consolidated Balance Sheets. These costs are being amortized to interest expense ratably over the life of the Credit Facility. Senior Notes In March 2019, we issued $500.0 million aggregate principal amount of 4.375% senior unsecured notes at 99.862% of par to yield 4.392% per annum. The notes are due March 15, 2029 and interest is payable semiannually on March 15 and September 15. The effective interest rate on these notes, including the amortization of debt issuance costs and discount, is 4.50%. In April 2017, we issued $750.0 million aggregate principal amount of 3.90% senior unsecured notes at 99.748% of par to yield 3.93% per annum. These notes are due May 15, 2027 and interest is payable semiannually on May 15 and November 15. The effective interest rate on these notes, including the amortization of debt issuance costs and discount, is 4.01%. In June 2014, we issued $750.0 million aggregate principal amount of 4.375% senior unsecured notes at par. These notes are due June 1, 2024 and interest is payable semiannually on June 1 and December 1. The effective interest rate on these notes, including the amortization of debt issuance costs, is 4.50%. Our senior unsecured notes are governed by indentures containing certain covenants, events of default, and other restrictive provisions with which we were in compliance as of March 31, 2021.

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	3 Months Ended
	Mar. 31, 2021
Derivative Instruments and Hedges, Assets [Abstract]
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS We periodically use derivative instruments to mitigate volatility in commodity prices. While the use of these instruments limits the downside risk of adverse price changes, their use may also limit future cash flow from favorable price changes. 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 March 31, 2021, we have entered into oil and gas collars, oil basis swaps, and oil “roll differential” swaps. Under our collars, we receive the difference between the published index price and a floor price if the index price is below the floor price or we pay the difference between the ceiling price and the index price if the index price is above the ceiling price. No amounts are paid or received if the index price is between the floor and the ceiling prices. By using a collar, we have fixed the minimum and maximum prices we can receive on the underlying production. Our basis swaps are settled based on the difference between a published index price plus or minus a fixed differential, as applicable, and the applicable local index price under which the underlying production is sold. By using a basis swap, we have fixed the differential between the published index price and certain of our physical pricing points. For our Permian oil production, the basis swaps fix the price differential between the WTI NYMEX (Cushing, Oklahoma) price and the WTI Midland price. For our Permian and Mid-Continent gas production, the contract prices in our collars are consistent with the index prices used to sell our production. Our roll differential swaps are settled based on the difference between the monthly roll differential and a fixed price per Bbl. The monthly roll differential is calculated as the sum of 2/3 of the difference in the WTI NYMEX closing settlement price for the first nearby month futures contract minus the second nearby month futures contract and 1/3 of the difference in the WTI NYMEX closing settlement price for the first nearby month futures contract minus the third nearby month futures contract. By using a roll differential swap, we have fixed the differential in pricing between the WTI NYMEX calendar month average price and the physical crude oil delivery month price. The following tables summarize our outstanding derivative contracts as of March 31, 2021: Oil Collars First Second Third Fourth Total 2021: WTI (1) Volume (Bbls) — 3,094,000 3,680,000 3,680,000 10,454,000 Weighted Avg Price - Floor $ — $ 34.62 $ 34.65 $ 34.65 $ 34.64 Weighted Avg Price - Ceiling $ — $ 43.28 $ 44.37 $ 44.37 $ 44.05 2022: WTI (1) Volume (Bbls) 2,340,000 1,729,000 920,000 — 4,989,000 Weighted Avg Price - Floor $ 37.31 $ 38.16 $ 40.00 $ — $ 38.10 Weighted Avg Price - Ceiling $ 48.41 $ 49.56 $ 49.19 $ — $ 48.95 ________________________________________ (1) The index price for these collars is West Texas Intermediate (“WTI”) as quoted on the New York Mercantile Exchange (“NYMEX”). Gas Collars First Second Third Fourth Total 2021: PEPL (1) Volume (MMBtu) — 9,100,000 8,280,000 8,280,000 25,660,000 Weighted Avg Price - Floor $ — $ 1.89 $ 2.00 $ 2.00 $ 1.96 Weighted Avg Price - Ceiling $ — $ 2.28 $ 2.42 $ 2.42 $ 2.37 Perm EP (2) Volume (MMBtu) — 7,280,000 6,440,000 6,440,000 20,160,000 Weighted Avg Price - Floor $ — $ 1.62 $ 1.86 $ 1.86 $ 1.77 Weighted Avg Price - Ceiling $ — $ 1.92 $ 2.22 $ 2.22 $ 2.11 Waha (3) Volume (MMBtu) — 9,100,000 8,280,000 8,280,000 25,660,000 Weighted Avg Price - Floor $ — $ 1.61 $ 1.82 $ 1.82 $ 1.74 Weighted Avg Price - Ceiling $ — $ 1.93 $ 2.17 $ 2.17 $ 2.09 2022: PEPL (1) Volume (MMBtu) 5,400,000 1,820,000 — — 7,220,000 Weighted Avg Price - Floor $ 2.13 $ 2.40 $ — $ — $ 2.20 Weighted Avg Price - Ceiling $ 2.55 $ 2.86 $ — $ — $ 2.63 Perm EP (2) Volume (MMBtu) 3,600,000 1,820,000 — — 5,420,000 Weighted Avg Price - Floor $ 2.13 $ 2.40 $ — $ — $ 2.22 Weighted Avg Price - Ceiling $ 2.53 $ 2.88 $ — $ — $ 2.65 Waha (3) Volume (MMBtu) 5,400,000 1,820,000 — — 7,220,000 Weighted Avg Price - Floor $ 1.98 $ 2.40 $ — $ — $ 2.09 Weighted Avg Price - Ceiling $ 2.39 $ 2.86 $ — $ — $ 2.50 ________________________________________ (1) The index price for these collars is Panhandle Eastern Pipe Line, Tex/OK Mid-Continent Index (“PEPL”) as quoted in Platt’s Inside FERC. (2) The index price for these collars is El Paso Natural Gas Company, Permian Basin Index (“Perm EP”) as quoted in Platt’s Inside FERC. (3) The index price for these collars is Waha West Texas Natural Gas Index (“Waha”) as quoted in Platt’s Inside FERC. Oil Basis Swaps First Second Third Fourth Total 2021: WTI Midland (1) Volume (Bbls) — 3,003,000 3,220,000 3,220,000 9,443,000 Weighted Avg Differential (2) $ — $ (0.02) $ (0.08) $ (0.08) $ (0.06) 2022: WTI Midland (1) Volume (Bbls) 1,980,000 1,365,000 644,000 — 3,989,000 Weighted Avg Differential (2) $ 0.25 $ 0.31 $ 0.38 $ — $ 0.29 ________________________________________ (1) The index price we pay under these basis swaps is WTI Midland as quoted by Argus Americas Crude. (2) The index price we receive under these basis swaps is WTI as quoted on the NYMEX plus or minus, as applicable, the weighted average differential shown in the table. Oil Roll Differential Swaps First Second Third Fourth Total 2021: WTI (1) Volume (Bbls) — 1,001,000 1,656,000 1,656,000 4,313,000 Weighted Avg Price $ — $ (0.22) $ (0.10) $ (0.10) $ (0.13) 2022: WTI (1) Volume (Bbls) 1,620,000 1,001,000 644,000 — 3,265,000 Weighted Avg Price $ (0.10) $ (0.01) $ 0.10 $ — $ (0.03) ________________________________________ (1) The index price used to determine the settlement “roll” is WTI as quoted on the NYMEX. The following table summarizes our derivative contracts entered into subsequent to March 31, 2021 through April 30, 2021: Gas Collars First Second Third Fourth Total 2021: Waha (1) Volume (MMBtu) — — 920,000 920,000 1,840,000 Weighted Avg Price - Floor $ — $ — $ 2.40 $ 2.40 $ 2.40 Weighted Avg Price - Ceiling $ — $ — $ 2.77 $ 2.77 $ 2.77 2022: Waha (1) Volume (MMBtu) 900,000 910,000 920,000 — 2,730,000 Weighted Avg Price - Floor $ 2.40 $ 2.40 $ 2.40 $ — $ 2.40 Weighted Avg Price - Ceiling $ 2.77 $ 2.77 $ 2.77 $ — $ 2.77 ________________________________________ (1) The index price for these collars is Waha as quoted in Platt’s Inside FERC. Derivative Gains and Losses Net gains and losses on our derivative instruments are a function of fluctuations in the underlying commodity index prices as compared to the contracted prices and the monthly cash settlements (if any) of the instruments. We have elected not to designate our derivatives as hedging instruments for accounting purposes and, therefore, we do not apply hedge accounting treatment to our derivative instruments. Consequently, changes in the fair value of our derivative instruments and cash settlements on the instruments are included as a component of operating costs and expenses as either a net gain or loss on derivative instruments. Cash settlements of our contracts are included in cash flows from operating activities in our statements of cash flows. The following table presents the components of “Loss (gain) on derivative instruments, net” for the periods indicated. Three Months Ended (in thousands) 2021 2020 Decrease (increase) in fair value of derivative instruments, net: Gas contracts $ (447) $ 12,493 Oil contracts 99,848 (196,319) 99,401 (183,826) Cash payments (receipts) on derivative instruments, net: Gas contracts 15,265 (11,719) Oil contracts 47,269 (31,395) 62,534 (43,114) Loss (gain) on derivative instruments, net $ 161,935 $ (226,940) Derivative Fair Value Our derivative contracts are carried at their fair value on our balance sheet using Level 2 inputs and are subject to master netting arrangements, which allow us to offset recognized asset and liability fair value amounts on contracts with the same counterparty. Our accounting policy is to not offset asset and liability positions in our balance sheets. The following tables present the amounts and classifications of our derivative assets and liabilities as of March 31, 2021 and December 31, 2020, as well as the potential effect of netting arrangements on our recognized derivative asset and liability amounts. March 31, 2021 (in thousands) Balance Sheet Location Asset Liability Oil contracts Current assets — Derivative instruments $ 173 $ — Gas contracts Non-current assets — Derivative instruments 2,376 — Oil contracts Current liabilities — Derivative instruments — 191,019 Gas contracts Current liabilities — Derivative instruments — 42,277 Oil contracts Non-current liabilities — Derivative instruments — 22,611 Total gross amounts presented in the balance sheet 2,549 255,907 Less: gross amounts not offset in the balance sheet (2,549) (2,549) Net amount $ — $ 253,358 December 31, 2020 (in thousands) Balance Sheet Location Asset Liability Oil contracts Current assets — Derivative instruments $ 5,425 $ — Gas contracts Current assets — Derivative instruments 1,423 — Gas contracts Non-current assets — Derivative instruments 2,342 — Oil contracts Current liabilities — Derivative instruments — 106,507 Gas contracts Current liabilities — Derivative instruments — 38,891 Oil contracts Non-current liabilities — Derivative instruments — 12,526 Gas contracts Non-current liabilities — Derivative instruments — 5,223 Total gross amounts presented in the balance sheet 9,190 163,147 Less: gross amounts not offset in the balance sheet (8,863) (8,863) Net amount $ 327 $ 154,284 We are exposed to financial risks associated with our derivative contracts from non-performance by our counterparties. We mitigate our exposure to any single counterparty by contracting with a number of financial institutions, each of which has a high credit rating and is a member of our bank credit facility. Our member banks do not require us to post collateral for our derivative liability positions, nor do we require our counterparties to post collateral for our benefit. In the future we may enter into derivative instruments with counterparties outside our bank group to obtain competitive terms and to spread counterparty risk.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	3 Months Ended
	Mar. 31, 2021
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS Fair value is 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. Authoritative accounting guidance has established a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. This hierarchy consists of three broad levels. Level 1 inputs are the highest priority and consist of unadjusted quoted prices in active markets for identical assets and liabilities. Level 2 inputs are other than quoted prices that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable. The following table provides fair value measurement information for certain assets and liabilities as of March 31, 2021 and December 31, 2020: March 31, 2021 December 31, 2020 (in thousands) Book Fair Book Fair Financial Assets (Liabilities): 4.375% Notes due 2024 $ (750,000) $ (815,625) $ (750,000) $ (818,025) 3.90% Notes due 2027 $ (750,000) $ (816,075) $ (750,000) $ (826,575) 4.375% Notes due 2029 $ (500,000) $ (553,050) $ (500,000) $ (567,250) Derivative instruments — assets $ 2,549 $ 2,549 $ 9,190 $ 9,190 Derivative instruments — liabilities $ (255,907) $ (255,907) $ (163,147) $ (163,147) Assessing the significance of a particular input to the fair value measurement requires judgment, including the consideration of factors specific to the asset or liability. The fair value (Level 1) of our fixed rate notes was based on quoted market prices. The fair value of our derivative instruments (Level 2) was estimated using discounted cash flow and option pricing models. These models use certain observable variables including forward prices, volatility curves, interest rates, and credit ratings and spreads. The fair value estimates are adjusted relative to non-performance risk as appropriate. See Note 3 for further information on the fair value of our derivative instruments. Other Financial Instruments The carrying amounts of our cash, cash equivalents, accounts receivable, accounts payable, and accrued liabilities approximate fair value because of the short-term maturities and/or liquid nature of these assets and liabilities. Included in “Accrued liabilities — Other” at March 31, 2021 are accrued operating expenses (e.g., production, transportation, and midstream expenses) of approximately $74.1 million. Included in “Accrued liabilities — Other” at December 31, 2020 are: (i) accrued operating expenses (e.g., production, transportation, and midstream expenses) of approximately $67.4 million and (ii) accrued general and administrative costs of approximately $46.8 million, which consisted primarily of $34.1 million in regular payroll-related costs and $11.3 million in voluntary early retirement incentive program and involuntary reduction in workforce severance accruals (the aggregate balance for these severance accruals decreased to $5.0 million at March 31, 2021 due to payments made during the first quarter of 2021). Most of our accounts receivable balances are uncollateralized and result from transactions with other companies in the oil and gas industry. Concentration of customers may impact our overall credit risk because our customers may be similarly affected by changes in economic or other conditions within the industry. We conduct credit analyses prior to making any sales to new customers or increasing credit for existing customers and may require parent company guarantees, letters of credit, or prepayments when deemed necessary. For properties we operate, we have the right to realize amounts due to us from non-operators by netting the non-operators’ share of production revenues from those properties.

CAPITAL STOCK

CAPITAL STOCK	3 Months Ended
	Mar. 31, 2021
Stockholders' Equity Note [Abstract]
CAPITAL STOCK	CAPITAL STOCK Authorized capital stock consists of 200 million shares of common stock and 15 million shares of preferred stock. At March 31, 2021, there were 102.8 million shares of common stock outstanding and 28.2 thousand shares of 8.125% Series A Cumulative Perpetual Convertible Preferred Stock outstanding (the “Preferred Stock”). Holders of the Preferred Stock are entitled to receive, when, as, and if declared by the Board, cumulative cash dividends at an annual rate of 8.125% of each share’s liquidation preference of $1,000. In the event of any liquidation, winding up, or dissolution of Cimarex, each holder will be entitled to receive in respect of its shares, up to each share’s liquidation preference, with the total liquidation preference being $28.2 million in the aggregate at March 31, 2021, after satisfaction of liabilities and any senior stock (of which there is currently none) and before any payment or distribution to holders of junior stock (including common stock). Each holder has the right at any time, at its option, to convert any or all of such holder’s shares of Preferred Stock into a certain number of shares of Cimarex common stock based on a conversion rate that adjusts upon the occurrence of certain events, including the payment of cash dividends to common shareholders, and $471.40 in cash per share of Preferred Stock. The March 31, 2021 conversion rate was 8.42579 shares of common stock for each share of Preferred Stock. As a result of the cash component included in the redemption feature of the Preferred Stock conversion option, which conversion is not solely within our control, the instruments are classified as “Redeemable preferred stock” in temporary equity on the Condensed Consolidated Balance Sheets. Dividends Common Stock In February 2021, our Board of Directors declared a cash dividend of $0.27 per share of common stock. The dividend is payable on or before June 1, 2021 to stockholders of record on May 14, 2021. Dividends declared are recorded as a reduction of retained earnings to the extent retained earnings are available at the close of the period prior to the date of the declared dividend. Dividends in excess of retained earnings are recorded as a reduction of additional paid-in capital. The $27.9 million dividend declared during the first quarter 2021 was recorded as a reduction of additional paid-in capital and is included as a payable in “Accrued liabilities — Other” on the Condensed Consolidated Balance Sheet at March 31, 2021. Nonforfeitable dividends paid on unvested stock awards that subsequently forfeit are reclassified out of retained earnings or additional paid-in capital, as applicable, to stock-based compensation expense in the period in which the stock award forfeitures occur. Future dividend payments will depend on our level of earnings, financial requirements, and other factors considered relevant by our Board of Directors. Preferred Stock

STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION	3 Months Ended
	Mar. 31, 2021
Retirement Benefits [Abstract]
STOCK-BASED COMPENSATION	STOCK-BASED COMPENSATION We have recognized stock-based compensation cost as shown below for the periods indicated. Three Months Ended (in thousands) 2021 2020 Restricted stock awards: Performance stock awards $ 3,282 $ 4,060 Service-based stock awards 8,299 7,377 11,581 11,437 Stock option awards 474 498 Total stock-based compensation cost 12,055 11,935 Less amounts capitalized to oil and gas properties (3,506) (5,541) Stock-based compensation expense $ 8,549 $ 6,394

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	3 Months Ended
	Mar. 31, 2021
Asset Retirement Obligation [Abstract]
ASSET RETIREMENT OBLIGATIONS	ASSET RETIREMENT OBLIGATIONS The following table reflects the components of the change in the carrying amount of the asset retirement obligation for the three months ended March 31, 2021: (in thousands) Three Months Ended Asset retirement obligation at January 1, 2021 $ 177,867 Liabilities incurred 363 Liability settlements and disposals (2,173) Accretion expense 1,866 Asset retirement obligation at March 31, 2021 177,923 Less current obligation (11,381) Long-term asset retirement obligation $ 166,542

EARNINGS (LOSS) PER SHARE

EARNINGS (LOSS) PER SHARE	3 Months Ended
	Mar. 31, 2021
Earnings Per Share [Abstract]
EARNINGS (LOSS) PER SHARE	EARNINGS (LOSS) PER SHARE The calculations of basic and diluted net earnings (loss) per common share under the two-class method are presented below for the periods indicated. Earnings (loss) per share are based on whole numbers rather than the rounded numbers presented. Three Months Ended March 31, 2021 2020 (in thousands, except per share information) Income (Numerator) Shares (Denominator) Per-Share Amount Income (Numerator) Shares (Denominator) Per-Share Amount Net income (loss) $ 128,082 $ (774,282) Less: dividends and net income attributable to participating securities (1) (2,779) (550) Less: redeemable preferred stock dividends (572) (1,269) Basic earnings (loss) per share Income (loss) available to common stockholders 124,731 100,126 $ 1.25 (776,101) 99,842 $ (7.77) Effects of dilutive securities Dilutive securities (2) 1 37 — — Diluted earnings (loss) per share Income (loss) available to common stockholders and assumed conversions $ 124,732 100,163 $ 1.25 $ (776,101) 99,842 $ (7.77) ________________________________________ (1) Participating securities do not have a contractual obligation to share in the losses of the entity, therefore, net losses are not attributable to participating securities. (2) Inclusion of certain potential common shares would have an anti-dilutive effect, therefore, these shares were excluded from the calculations of diluted earnings (loss) per share. Excluded from the calculation for the three months ended March 31, 2021 were 496.1 thousand potential common shares from the assumed exercise of employee stock options and 237.3 thousand potential common shares from the assumed conversion of the Preferred Stock. Excluded from the calculation for the three months ended March 31, 2020 were 474.5 thousand potential common shares from the assumed exercise of employee stock options, 511.1 thousand potential common shares from the assumed conversion of the Preferred Stock, and 8.8 thousand potential common shares from the assumed vesting of incremental shares of unvested restricted stock units.

INCOME TAXES

INCOME TAXES	3 Months Ended
	Mar. 31, 2021
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The components of our provision for income taxes and our combined federal and state effective income tax rates were as follows: Three Months Ended (in thousands) 2021 2020 Current tax benefit $ — $ (198) Deferred tax expense (benefit) 40,170 (16,357) $ 40,170 $ (16,555) Combined federal and state effective income tax rate 23.9 % 2.1 % Our combined federal and state effective income tax rates differ from the U.S. federal statutory rate of 21% primarily due to state income taxes, non-deductible expenses, and changes in valuation allowances. The combined federal and state effective income tax rate for the three months ended March 31, 2020 was impacted by the non-deductible impairment of goodwill recorded during the first quarter 2020. At December 31, 2020, we had a U.S. net tax operating loss carryforward of approximately $1.997 billion; $1.773 billion of which is subject to expiration in tax years 2032 through 2037 and $224.4 million of which is not subject to expiration. We believe that the carryforward, net of valuation allowance, will be utilized before it expires. We also had enhanced oil recovery and marginal well credits of $4.2 million at December 31, 2020. The total valuation allowance on state net operating losses at December 31, 2020 was $120.7 million since it is not more likely than not that these additional state net operating losses will be utilized before they expire. When assessing the need for a valuation allowance against a deferred tax asset, both positive and negative evidence is considered when determining the ability to utilize our deferred tax assets. Based on our estimate of the timing of future reversals of existing taxable temporary differences, our estimate of future taxable income exclusive of reversing temporary differences and carryforwards, the length of time before the deferred tax assets associated with the net operating loss carryovers begin to expire, and tax planning strategies that could be implemented to accelerate taxable amounts to utilize expiring carryovers, we believe it is more likely than not that the benefit from the deferred tax asset recorded in the financial statements will be realized. We will continue to assess all available positive and negative evidence to estimate whether sufficient future taxable income will be generated in order to utilize the deferred tax assets. Additional valuation allowances may be required in future periods if additional losses are incurred or other circumstances change. At March 31, 2021, we had no unrecognized tax benefits that would impact our effective tax rate and have made no provisions for interest or penalties related to uncertain tax positions. The tax years 2017 through 2019 remain open to examination by the Internal Revenue Service of the United States. We file tax returns with various state taxing authorities, which remain open to examination for tax years 2016 through 2019.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES At March 31, 2021, we had estimated commitments of approximately: (i) $282.1 million to finish drilling, completing, or performing other work on wells and various other infrastructure projects in progress and (ii) $5.2 million to finish midstream construction in progress. At March 31, 2021, we had firm sales contracts to deliver approximately 456.5 Bcf of gas over the next 10.3 years. If we do not deliver this gas, our estimated financial commitment, calculated using the April 2021 index prices, would be approximately $913.0 million. The value of this commitment will fluctuate due to price volatility and actual volumes delivered. In connection with gas gathering and processing agreements, we have volume commitments over the next 7.8 years. If we do not deliver the committed gas or NGLs, as applicable, the estimated maximum amount that would be payable under these commitments, calculated as of March 31, 2021, would be approximately $621.9 million. We have minimum volume delivery commitments associated with agreements to reimburse connection costs to various pipelines. If we do not deliver this gas or oil, as applicable, the estimated maximum amount that would be payable under these commitments, calculated as of March 31, 2021, would be approximately $108.8 million. Of this total, we have accrued a liability of $4.2 million, representing the estimated amount we will have to pay due to insufficient forecasted volumes at particular connection points. At March 31, 2021, we have various firm transportation agreements for gas pipeline capacity with end dates ranging from 2021 - 2025 under which we will have to pay an estimated $14.5 million over the remaining terms of the agreements. We have minimum volume water delivery commitments associated with a water services agreement, which ends in 2030. If we do not deliver the water volumes, the estimated maximum amount that would be payable under this commitment, calculated as of March 31, 2021, would be approximately $62.5 million. All of the noted commitments were routine and made in the ordinary course of our business. Litigation In the ordinary course of business, we are involved with various litigation matters. When a loss contingency exists, we assess the likelihood that a future event or events will confirm the loss or impairment of an asset or the incurrence of a liability. If the likelihood is probable, we accrue a loss if reasonably estimable. Though some of the related claims may be significant, we believe the resolution of them, individually or in the aggregate, would not have a material adverse effect on our financial condition or results of operations.

SUPPLEMENTAL CASH FLOW INFORMAT

SUPPLEMENTAL CASH FLOW INFORMATION	3 Months Ended
	Mar. 31, 2021
Supplemental Cash Flow Elements [Abstract]
SUPPLEMENTAL CASH FLOW INFORMATION	SUPPLEMENTAL CASH FLOW INFORMATION Three Months Ended (in thousands) 2021 2020 Cash paid during the period for: Interest (net of capitalized amounts of $6,013, and $7,328, respectively) $ 5,985 $ 5,559 Income taxes $ 30 $ — Cash received for income tax refunds $ 266 $ 204

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	3 Months Ended
	Mar. 31, 2021
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONSHelmerich & Payne, Inc. (“H&P”) provides contract drilling services to Cimarex. Cimarex incurred drilling costs of approximately $2.8 million and $15.6 million related to these services during the three months ended March 31, 2021 and 2020, respectively. Hans Helmerich, a director of Cimarex, is Chairman of the Board of Directors of H&P.

BASIS OF PRESENTATION (Policies

BASIS OF PRESENTATION (Policies)	3 Months Ended
	Mar. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	BASIS OF PRESENTATIONCimarex Energy Co. (“Cimarex,” “company,” “we,” or “us”), a Delaware corporation, is an independent oil and gas exploration and production company. Our operations are located entirely within the United States, mainly in Texas, New Mexico, and Oklahoma. The accompanying unaudited financial statements have been prepared pursuant to rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain disclosures required by accounting principles generally accepted in the United States and normally included in Annual Reports on Form 10-K have been omitted. Although management believes that our disclosures in these interim financial statements are adequate, they should be read in conjunction with the financial statements, summary of significant accounting policies, and footnotes included in our Annual Report on Form 10-K for the year ended December 31, 2020. In the opinion of management, the accompanying financial statements reflect all adjustments necessary to fairly present our financial position, results of operations, and cash flows for the periods and as of the dates shown. The accounts of Cimarex and its subsidiaries are presented in the accompanying financial statements, with intercompany balances and transactions eliminated in consolidation. Certain amounts in the prior year financial statements have been reclassified to conform to the 2021 financial statement presentation.
Use of Estimates	Use of EstimatesAreas of significance requiring the use of management’s judgments include the estimation of proved oil and gas reserves used in calculating depletion, the estimation of future net revenues used in computing ceiling test limitations, and the estimation of future abandonment obligations used in recording asset retirement obligations. Estimates and judgments also are required in determining allowances for credit losses, impairments of unproved properties and other assets, valuation of deferred tax assets, fair value measurements, lease liabilities, and contingencies. We analyze our estimates and base them on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Actual results may differ from these estimates under different assumptions or conditions.
Oil and Gas Well Equipment and Supplies and Oil and Gas Properties	Oil and Gas Well Equipment and Supplies Our oil and gas well equipment and supplies are valued at the lower of cost and net realizable value, where net realizable value is based on estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. Declines in the price of oil and gas well equipment and supplies in future periods could cause us to recognize impairments on these assets. An impairment would not affect cash flow from operating activities, but would adversely affect our net income and stockholders’ equity. Oil and Gas Properties We use the full cost method of accounting for our oil and gas operations. All costs associated with property acquisition, exploration, and development activities are capitalized. Under the full cost method of accounting, we are required to perform a quarterly ceiling test calculation to test our oil and gas properties for possible impairment. If the net capitalized cost of our oil and gas properties, as adjusted for income taxes, exceeds the ceiling limitation, the excess is charged to expense. The ceiling limitation is equal to the sum of: (i) the present value discounted at 10% of estimated future net revenues from proved reserves, (ii) the cost of properties not being amortized, and (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized, as adjusted for income taxes. We currently do not have any unproven properties that are being amortized. Estimated future net revenues are determined based on trailing twelve-month average commodity prices and estimated proved reserve quantities, operating costs, and capital expenditures.
Goodwill	GoodwillGoodwill represents the excess of the purchase price of business combinations over the fair value of the net assets acquired and is tested for impairment at least annually. During the three months ended March 31, 2020, the company’s market capitalization declined significantly, caused by macroeconomic and geopolitical conditions including the collapse of oil prices driven by surplus supply and decreased demand caused by the COVID-19 pandemic. In addition, the uncertainty related to oil demand significantly impacted our investment and operating decisions at the time. As a result of these events and circumstances, we performed an interim quantitative impairment test for goodwill as of March 31, 2020,
Revenue Recognition	Revenue Recognition Oil, Gas, and NGL Sales Revenue is recognized from the sales of oil, gas, and NGLs when the customer obtains control of the product, when we have no further obligations to perform related to the sale, and when collectability is probable. All of our sales of oil, gas, and NGLs are made under contracts with customers, which typically include variable consideration based on monthly pricing tied to local indices and monthly volumes delivered. The nature of our contracts with customers does not require us to constrain that variable consideration or to estimate the amount of transaction price attributable to future performance obligations for accounting purposes. As of March 31, 2021, we had open contracts with customers with terms of one month to multiple years, as well as “evergreen” contracts that renew on a periodic basis if not canceled by us or the customer. Performance obligations under our contracts with customers are typically satisfied at a point-in-time through monthly delivery of oil, gas, and/or NGLs. Our contracts with customers typically require payment within one month of delivery. Our gas is sold under various contracts. Under these contracts the gas and its components, including residue gas and NGLs, may be sold to a single purchaser or separate purchasers. Regardless of the contract, we are compensated for the value of the residue gas and NGLs at current market prices for each product. Depending on the specific contract terms, certain gathering, treating, transportation, processing, and other charges may be deducted against the prices we receive for the products. Our oil typically is sold at specific delivery points under contract terms that are common in our industry. Gas Gathering When we transport, process, and/or market third-party gas associated with our equity gas, we recognize revenue for the fees charged to third-parties for such services. Gas Marketing When we market and sell gas for other working interest owners, we act as agent under short-term sales and supply agreements and may earn a fee for such services. Revenues from such services are recognized as gas is delivered. Gas Imbalances Revenue from the sale of gas is recorded on the basis of gas actually sold by or for us. If our aggregate sales volumes for a well are greater (or less) than our proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented.

BASIS OF PRESENTATION (Tables)

BASIS OF PRESENTATION (Tables)	3 Months Ended
	Mar. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Changes in Carrying Amount of Goodwill	The following table reflects components of the change in the carrying amount of goodwill for the three months ended March 31, 2020 (subsequent to March 31, 2020 through March 31, 2021 we have not recognized any additional goodwill balance): (in thousands) Three Months Ended Goodwill balance at January 1, 2020 $ 716,865 Business combination purchase price adjustments (2,418) Impairment (714,447) Goodwill balance at March 31, 2020 $ —

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	3 Months Ended
	Mar. 31, 2021
Long-term Debt, Unclassified [Abstract]
Schedule of Long-Term Debt	Long-term debt at March 31, 2021 and December 31, 2020 consisted of the following: March 31, 2021 December 31, 2020 (in thousands) Principal Unamortized Debt Issuance Costs and Discounts (1) Long-term Principal Unamortized Debt Issuance Costs and Discounts (1) Long-term 4.375% Notes due 2024 $ 750,000 $ (2,462) $ 747,538 $ 750,000 $ (2,672) $ 747,328 3.90% Notes due 2027 750,000 (5,350) 744,650 750,000 (5,541) 744,459 4.375% Notes due 2029 500,000 (4,374) 495,626 500,000 (4,488) 495,512 $ 2,000,000 $ (12,186) $ 1,987,814 $ 2,000,000 $ (12,701) $ 1,987,299 ________________________________________

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	3 Months Ended
	Mar. 31, 2021
Derivative Instruments and Hedges, Assets [Abstract]
Schedule of Outstanding Derivative Contracts	The following tables summarize our outstanding derivative contracts as of March 31, 2021: Oil Collars First Second Third Fourth Total 2021: WTI (1) Volume (Bbls) — 3,094,000 3,680,000 3,680,000 10,454,000 Weighted Avg Price - Floor $ — $ 34.62 $ 34.65 $ 34.65 $ 34.64 Weighted Avg Price - Ceiling $ — $ 43.28 $ 44.37 $ 44.37 $ 44.05 2022: WTI (1) Volume (Bbls) 2,340,000 1,729,000 920,000 — 4,989,000 Weighted Avg Price - Floor $ 37.31 $ 38.16 $ 40.00 $ — $ 38.10 Weighted Avg Price - Ceiling $ 48.41 $ 49.56 $ 49.19 $ — $ 48.95 ________________________________________ (1) The index price for these collars is West Texas Intermediate (“WTI”) as quoted on the New York Mercantile Exchange (“NYMEX”). Gas Collars First Second Third Fourth Total 2021: PEPL (1) Volume (MMBtu) — 9,100,000 8,280,000 8,280,000 25,660,000 Weighted Avg Price - Floor $ — $ 1.89 $ 2.00 $ 2.00 $ 1.96 Weighted Avg Price - Ceiling $ — $ 2.28 $ 2.42 $ 2.42 $ 2.37 Perm EP (2) Volume (MMBtu) — 7,280,000 6,440,000 6,440,000 20,160,000 Weighted Avg Price - Floor $ — $ 1.62 $ 1.86 $ 1.86 $ 1.77 Weighted Avg Price - Ceiling $ — $ 1.92 $ 2.22 $ 2.22 $ 2.11 Waha (3) Volume (MMBtu) — 9,100,000 8,280,000 8,280,000 25,660,000 Weighted Avg Price - Floor $ — $ 1.61 $ 1.82 $ 1.82 $ 1.74 Weighted Avg Price - Ceiling $ — $ 1.93 $ 2.17 $ 2.17 $ 2.09 2022: PEPL (1) Volume (MMBtu) 5,400,000 1,820,000 — — 7,220,000 Weighted Avg Price - Floor $ 2.13 $ 2.40 $ — $ — $ 2.20 Weighted Avg Price - Ceiling $ 2.55 $ 2.86 $ — $ — $ 2.63 Perm EP (2) Volume (MMBtu) 3,600,000 1,820,000 — — 5,420,000 Weighted Avg Price - Floor $ 2.13 $ 2.40 $ — $ — $ 2.22 Weighted Avg Price - Ceiling $ 2.53 $ 2.88 $ — $ — $ 2.65 Waha (3) Volume (MMBtu) 5,400,000 1,820,000 — — 7,220,000 Weighted Avg Price - Floor $ 1.98 $ 2.40 $ — $ — $ 2.09 Weighted Avg Price - Ceiling $ 2.39 $ 2.86 $ — $ — $ 2.50 ________________________________________ (1) The index price for these collars is Panhandle Eastern Pipe Line, Tex/OK Mid-Continent Index (“PEPL”) as quoted in Platt’s Inside FERC. (2) The index price for these collars is El Paso Natural Gas Company, Permian Basin Index (“Perm EP”) as quoted in Platt’s Inside FERC. (3) The index price for these collars is Waha West Texas Natural Gas Index (“Waha”) as quoted in Platt’s Inside FERC. Oil Basis Swaps First Second Third Fourth Total 2021: WTI Midland (1) Volume (Bbls) — 3,003,000 3,220,000 3,220,000 9,443,000 Weighted Avg Differential (2) $ — $ (0.02) $ (0.08) $ (0.08) $ (0.06) 2022: WTI Midland (1) Volume (Bbls) 1,980,000 1,365,000 644,000 — 3,989,000 Weighted Avg Differential (2) $ 0.25 $ 0.31 $ 0.38 $ — $ 0.29 ________________________________________ (1) The index price we pay under these basis swaps is WTI Midland as quoted by Argus Americas Crude. (2) The index price we receive under these basis swaps is WTI as quoted on the NYMEX plus or minus, as applicable, the weighted average differential shown in the table. Oil Roll Differential Swaps First Second Third Fourth Total 2021: WTI (1) Volume (Bbls) — 1,001,000 1,656,000 1,656,000 4,313,000 Weighted Avg Price $ — $ (0.22) $ (0.10) $ (0.10) $ (0.13) 2022: WTI (1) Volume (Bbls) 1,620,000 1,001,000 644,000 — 3,265,000 Weighted Avg Price $ (0.10) $ (0.01) $ 0.10 $ — $ (0.03) ________________________________________ (1) The index price used to determine the settlement “roll” is WTI as quoted on the NYMEX.
Schedule of Derivative Contracts Entered into Subsequent to Balance Sheet Date	The following table summarizes our derivative contracts entered into subsequent to March 31, 2021 through April 30, 2021: Gas Collars First Second Third Fourth Total 2021: Waha (1) Volume (MMBtu) — — 920,000 920,000 1,840,000 Weighted Avg Price - Floor $ — $ — $ 2.40 $ 2.40 $ 2.40 Weighted Avg Price - Ceiling $ — $ — $ 2.77 $ 2.77 $ 2.77 2022: Waha (1) Volume (MMBtu) 900,000 910,000 920,000 — 2,730,000 Weighted Avg Price - Floor $ 2.40 $ 2.40 $ 2.40 $ — $ 2.40 Weighted Avg Price - Ceiling $ 2.77 $ 2.77 $ 2.77 $ — $ 2.77 ________________________________________ (1) The index price for these collars is Waha as quoted in Platt’s Inside FERC.
Schedule of Net (Gains) Losses from Settlements and Changes of Derivative Contracts	The following table presents the components of “Loss (gain) on derivative instruments, net” for the periods indicated. Three Months Ended (in thousands) 2021 2020 Decrease (increase) in fair value of derivative instruments, net: Gas contracts $ (447) $ 12,493 Oil contracts 99,848 (196,319) 99,401 (183,826) Cash payments (receipts) on derivative instruments, net: Gas contracts 15,265 (11,719) Oil contracts 47,269 (31,395) 62,534 (43,114) Loss (gain) on derivative instruments, net $ 161,935 $ (226,940)
Schedule of Derivative Assets and Liabilities	The following tables present the amounts and classifications of our derivative assets and liabilities as of March 31, 2021 and December 31, 2020, as well as the potential effect of netting arrangements on our recognized derivative asset and liability amounts. March 31, 2021 (in thousands) Balance Sheet Location Asset Liability Oil contracts Current assets — Derivative instruments $ 173 $ — Gas contracts Non-current assets — Derivative instruments 2,376 — Oil contracts Current liabilities — Derivative instruments — 191,019 Gas contracts Current liabilities — Derivative instruments — 42,277 Oil contracts Non-current liabilities — Derivative instruments — 22,611 Total gross amounts presented in the balance sheet 2,549 255,907 Less: gross amounts not offset in the balance sheet (2,549) (2,549) Net amount $ — $ 253,358 December 31, 2020 (in thousands) Balance Sheet Location Asset Liability Oil contracts Current assets — Derivative instruments $ 5,425 $ — Gas contracts Current assets — Derivative instruments 1,423 — Gas contracts Non-current assets — Derivative instruments 2,342 — Oil contracts Current liabilities — Derivative instruments — 106,507 Gas contracts Current liabilities — Derivative instruments — 38,891 Oil contracts Non-current liabilities — Derivative instruments — 12,526 Gas contracts Non-current liabilities — Derivative instruments — 5,223 Total gross amounts presented in the balance sheet 9,190 163,147 Less: gross amounts not offset in the balance sheet (8,863) (8,863) Net amount $ 327 $ 154,284

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	3 Months Ended
	Mar. 31, 2021
Fair Value Disclosures [Abstract]
Schedule of Fair Value Measurement Information for Certain Assets and Liabilities	The following table provides fair value measurement information for certain assets and liabilities as of March 31, 2021 and December 31, 2020: March 31, 2021 December 31, 2020 (in thousands) Book Fair Book Fair Financial Assets (Liabilities): 4.375% Notes due 2024 $ (750,000) $ (815,625) $ (750,000) $ (818,025) 3.90% Notes due 2027 $ (750,000) $ (816,075) $ (750,000) $ (826,575) 4.375% Notes due 2029 $ (500,000) $ (553,050) $ (500,000) $ (567,250) Derivative instruments — assets $ 2,549 $ 2,549 $ 9,190 $ 9,190 Derivative instruments — liabilities $ (255,907) $ (255,907) $ (163,147) $ (163,147)

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	3 Months Ended
	Mar. 31, 2021
Retirement Benefits [Abstract]
Schedule of Recognition of Non-Cash Stock-Based Compensation Costs	We have recognized stock-based compensation cost as shown below for the periods indicated. Three Months Ended (in thousands) 2021 2020 Restricted stock awards: Performance stock awards $ 3,282 $ 4,060 Service-based stock awards 8,299 7,377 11,581 11,437 Stock option awards 474 498 Total stock-based compensation cost 12,055 11,935 Less amounts capitalized to oil and gas properties (3,506) (5,541) Stock-based compensation expense $ 8,549 $ 6,394

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	3 Months Ended
	Mar. 31, 2021
Asset Retirement Obligation [Abstract]
Schedule of Asset Retirement Obligations	The following table reflects the components of the change in the carrying amount of the asset retirement obligation for the three months ended March 31, 2021: (in thousands) Three Months Ended Asset retirement obligation at January 1, 2021 $ 177,867 Liabilities incurred 363 Liability settlements and disposals (2,173) Accretion expense 1,866 Asset retirement obligation at March 31, 2021 177,923 Less current obligation (11,381) Long-term asset retirement obligation $ 166,542

EARNINGS (LOSS) PER SHARE (Tabl

EARNINGS (LOSS) PER SHARE (Tables)	3 Months Ended
	Mar. 31, 2021
Earnings Per Share [Abstract]
Schedule of Calculations of Basic and Diluted Net Earnings (Loss) per Common Share	The calculations of basic and diluted net earnings (loss) per common share under the two-class method are presented below for the periods indicated. Earnings (loss) per share are based on whole numbers rather than the rounded numbers presented. Three Months Ended March 31, 2021 2020 (in thousands, except per share information) Income (Numerator) Shares (Denominator) Per-Share Amount Income (Numerator) Shares (Denominator) Per-Share Amount Net income (loss) $ 128,082 $ (774,282) Less: dividends and net income attributable to participating securities (1) (2,779) (550) Less: redeemable preferred stock dividends (572) (1,269) Basic earnings (loss) per share Income (loss) available to common stockholders 124,731 100,126 $ 1.25 (776,101) 99,842 $ (7.77) Effects of dilutive securities Dilutive securities (2) 1 37 — — Diluted earnings (loss) per share Income (loss) available to common stockholders and assumed conversions $ 124,732 100,163 $ 1.25 $ (776,101) 99,842 $ (7.77) ________________________________________ (1) Participating securities do not have a contractual obligation to share in the losses of the entity, therefore, net losses are not attributable to participating securities. (2) Inclusion of certain potential common shares would have an anti-dilutive effect, therefore, these shares were excluded from the calculations of diluted earnings (loss) per share. Excluded from the calculation for the three months ended March 31, 2021 were 496.1 thousand potential common shares from the assumed exercise of employee stock options and 237.3 thousand potential common shares from the assumed conversion of the Preferred Stock. Excluded from the calculation for the three months ended March 31, 2020 were 474.5 thousand potential common shares from the assumed exercise of employee stock options, 511.1 thousand potential common shares from the assumed conversion of the Preferred Stock, and 8.8 thousand potential common shares from the assumed vesting of incremental shares of unvested restricted stock units.

INCOME TAXES (Tables)

INCOME TAXES (Tables)	3 Months Ended
	Mar. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Components of the Provision for Income Taxes	The components of our provision for income taxes and our combined federal and state effective income tax rates were as follows: Three Months Ended (in thousands) 2021 2020 Current tax benefit $ — $ (198) Deferred tax expense (benefit) 40,170 (16,357) $ 40,170 $ (16,555) Combined federal and state effective income tax rate 23.9 % 2.1 %

SUPPLEMENTAL CASH FLOW INFORM_2

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	3 Months Ended
	Mar. 31, 2021
Supplemental Cash Flow Elements [Abstract]
Schedule of Supplemental Cash Flow Information	Three Months Ended (in thousands) 2021 2020 Cash paid during the period for: Interest (net of capitalized amounts of $6,013, and $7,328, respectively) $ 5,985 $ 5,559 Income taxes $ 30 $ — Cash received for income tax refunds $ 266 $ 204

BASIS OF PRESENTATION - Narrati

BASIS OF PRESENTATION - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Oil and Gas, Delivery Commitment [Line Items]
Discount rate for calculating present value of estimated future net revenues from proved reserves (as a percent)	10.00%
Impairment of oil and gas properties	$ 0	$ 333,651
Minimum
Oil and Gas, Delivery Commitment [Line Items]
Oil and gas delivery commitments and contracts, period	1 month

BASIS OF PRESENTATION - Changes

BASIS OF PRESENTATION - Changes in Carrying Amount of Goodwill (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Goodwill [Roll Forward]
Goodwill balance at beginning of period		$ 716,865
Business combination purchase price adjustments		(2,418)
Impairment	$ 0	(714,447)
Goodwill balance at end of period		$ 0

LONG-TERM DEBT - Long-Term Debt

LONG-TERM DEBT - Long-Term Debt Outstanding (Details) - USD ($)	Mar. 31, 2021	Dec. 31, 2020	Mar. 08, 2019	Apr. 30, 2017	Jun. 30, 2014
Debt Instrument
Long-term debt principal	$ 2,000,000,000	$ 2,000,000,000
Unamortized debt issuance costs and discount	12,186,000	12,701,000
Long-term Debt, net	1,987,814,000	1,987,299,000
4.375% Notes due 2024
Debt Instrument
Long-term debt principal	750,000,000	750,000,000
Unamortized debt issuance costs and discount	2,462,000	2,672,000
Long-term Debt, net	$ 747,538,000	747,328,000
4.375% Notes due 2024 | Senior Notes
Debt Instrument
Stated interest rate of debt instrument (as a percent)	4.375%				4.375%
Long-term debt principal					$ 750,000,000
3.90% Notes due 2027
Debt Instrument
Long-term debt principal	$ 750,000,000	750,000,000
Unamortized debt issuance costs and discount	5,350,000	5,541,000
Long-term Debt, net	$ 744,650,000	744,459,000
3.90% Notes due 2027 | Senior Notes
Debt Instrument
Stated interest rate of debt instrument (as a percent)	3.90%			3.90%
Long-term debt principal				$ 750,000,000
Unamortized debt issuance costs	$ 4,100,000	4,300,000
Unamortized discount	1,200,000	1,300,000
4.375% Notes due 2029
Debt Instrument
Long-term debt principal	500,000,000	500,000,000
Unamortized debt issuance costs and discount	4,374,000	4,488,000
Long-term Debt, net	$ 495,626,000	495,512,000
4.375% Notes due 2029 | Senior Notes
Debt Instrument
Stated interest rate of debt instrument (as a percent)	4.375%
Long-term debt principal			$ 500,000,000
Unamortized debt issuance costs	$ 3,800,000	3,900,000
Unamortized discount	$ 600,000	$ 600,000

LONG-TERM DEBT - Bank Debt Narr

LONG-TERM DEBT - Bank Debt Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Feb. 05, 2019
Line of Credit Facility [Line Items]
Unamortized debt issuance costs and discount	$ 12,186,000	$ 12,701,000
Revolving Credit Facility
Line of Credit Facility [Line Items]
Aggregate commitments under credit facility			$ 1,250,000,000
Maximum borrowing capacity including accordion feature			$ 1,500,000,000
Maximum additional non-cash impairment charge add-backs	3,500,000,000
Consolidated cash threshold	$ 175,000,000
Property lien debt basket (as a percent)	15.00%
Consolidated net tangible assets cap	$ 50,000,000
Borrowings outstanding	0
Unused borrowing availability	$ 1,248,000,000
Debt-to-capital ratio (as a percent)	65.00%
Unamortized debt issuance costs and discount	$ 4,000,000	$ 4,300,000
Letter of Credit
Line of Credit Facility [Line Items]
Borrowings outstanding	$ 2,500,000
Minimum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Commitment fee rate (as a percent)	0.125%
Maximum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Commitment fee rate (as a percent)	0.35%
London Interbank Offered Rate (LIBOR) | Minimum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Interest rate margin (as a percent)	1.125%
London Interbank Offered Rate (LIBOR) | Maximum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Interest rate margin (as a percent)	2.00%
Base Rate | Minimum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Interest rate margin (as a percent)	0.125%
Base Rate | Maximum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Interest rate margin (as a percent)	1.00%

LONG-TERM DEBT - Senior Notes N

LONG-TERM DEBT - Senior Notes Narrative (Details) - USD ($)	Mar. 08, 2019	Apr. 30, 2017	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Jun. 30, 2014
Debt Instrument
Principal amount			$ 2,000,000,000		$ 2,000,000,000
Proceeds from issuance of long-term debt			0	$ 101,000,000
4.375% Notes due 2029
Debt Instrument
Principal amount			500,000,000		500,000,000
3.90% Notes due 2027
Debt Instrument
Principal amount			750,000,000		750,000,000
4.375% Notes due 2024
Debt Instrument
Principal amount			$ 750,000,000		$ 750,000,000
Senior Notes | 4.375% Notes due 2029
Debt Instrument
Principal amount	$ 500,000,000
Stated interest rate of debt instrument (as a percent)			4.375%
Issuance price relative to par value (as a percent)	99.862%
Effective rate (as a percent)	4.392%		4.50%
Senior Notes | 3.90% Notes due 2027
Debt Instrument
Principal amount		$ 750,000,000
Stated interest rate of debt instrument (as a percent)		3.90%	3.90%
Issuance price relative to par value (as a percent)		99.748%
Effective rate (as a percent)		3.93%	4.01%
Senior Notes | 4.375% Notes due 2024
Debt Instrument
Principal amount						$ 750,000,000
Stated interest rate of debt instrument (as a percent)			4.375%			4.375%
Effective rate (as a percent)			4.50%

DERIVATIVE INSTRUMENTS - Deriva

DERIVATIVE INSTRUMENTS - Derivative Contracts (Details)	3 Months Ended
	Mar. 31, 2021MMBTU$ / bbl$ / MMBTUbbl
Oil Collar WTI Index | 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	10,454,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	34.64
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	44.05
Oil Collar WTI Index | Second Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,094,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	34.62
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	43.28
Oil Collar WTI Index | Third Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,680,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	34.65
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	44.37
Oil Collar WTI Index | Fourth Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,680,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	34.65
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	44.37
Oil Collar WTI Index | 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	4,989,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	38.10
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	48.95
Oil Collar WTI Index | First Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	2,340,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	37.31
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	48.41
Oil Collar WTI Index | Second Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,729,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	38.16
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	49.56
Oil Collar WTI Index | Third Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	920,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	40
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	49.19
Oil Collar WTI Index | Fourth Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit) | $ / bbl	0
Weighted Avg Price - Ceiling (USD per unit) | $ / bbl	0
Gas Collar PEPL Index | 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	25,660,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.96
Weighted Avg Price - Ceiling (USD per unit)	2.37
Gas Collar PEPL Index | Second Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	9,100,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.89
Weighted Avg Price - Ceiling (USD per unit)	2.28
Gas Collar PEPL Index | Third Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	8,280,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2
Weighted Avg Price - Ceiling (USD per unit)	2.42
Gas Collar PEPL Index | Fourth Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	8,280,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2
Weighted Avg Price - Ceiling (USD per unit)	2.42
Gas Collar PEPL Index | 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	7,220,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.20
Weighted Avg Price - Ceiling (USD per unit)	2.63
Gas Collar PEPL Index | First Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	5,400,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.13
Weighted Avg Price - Ceiling (USD per unit)	2.55
Gas Collar PEPL Index | Second Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	1,820,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.86
Gas Collar PEPL Index | Third Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar PEPL Index | Fourth Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar Perm EP | 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	20,160,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.77
Weighted Avg Price - Ceiling (USD per unit)	2.11
Gas Collar Perm EP | Second Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	7,280,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.62
Weighted Avg Price - Ceiling (USD per unit)	1.92
Gas Collar Perm EP | Third Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	6,440,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.86
Weighted Avg Price - Ceiling (USD per unit)	2.22
Gas Collar Perm EP | Fourth Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	6,440,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.86
Weighted Avg Price - Ceiling (USD per unit)	2.22
Gas Collar Perm EP | 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	5,420,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.22
Weighted Avg Price - Ceiling (USD per unit)	2.65
Gas Collar Perm EP | First Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	3,600,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.13
Weighted Avg Price - Ceiling (USD per unit)	2.53
Gas Collar Perm EP | Second Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	1,820,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.88
Gas Collar Perm EP | Third Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar Perm EP | Fourth Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar Waha | 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	25,660,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.74
Weighted Avg Price - Ceiling (USD per unit)	2.09
Gas Collar Waha | 2021 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	1,840,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | Second Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	9,100,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.61
Weighted Avg Price - Ceiling (USD per unit)	1.93
Gas Collar Waha | Second Quarter - 2021 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar Waha | Third Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	8,280,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.82
Weighted Avg Price - Ceiling (USD per unit)	2.17
Gas Collar Waha | Third Quarter - 2021 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	920,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | Fourth Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	8,280,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.82
Weighted Avg Price - Ceiling (USD per unit)	2.17
Gas Collar Waha | Fourth Quarter - 2021 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	920,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	7,220,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.09
Weighted Avg Price - Ceiling (USD per unit)	2.50
Gas Collar Waha | 2022 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	2,730,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | First Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	5,400,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	1.98
Weighted Avg Price - Ceiling (USD per unit)	2.39
Gas Collar Waha | First Quarter - 2022 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	900,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | Second Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	1,820,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.86
Gas Collar Waha | Second Quarter - 2022 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	910,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | Third Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar Waha | Third Quarter - 2022 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	920,000
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	2.40
Weighted Avg Price - Ceiling (USD per unit)	2.77
Gas Collar Waha | Fourth Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Gas Collar Waha | Fourth Quarter - 2022 | Subsequent at end of period
Fair values of derivative assets and liabilities
Volume (MMBtu) | MMBTU	0
Weighted Average Price
Weighted Avg Price - Floor (USD per unit)	0
Weighted Avg Price - Ceiling (USD per unit)	0
Oil Basis Swaps WTI Midland Index | 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	9,443,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	(0.06)
Oil Basis Swaps WTI Midland Index | Second Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,003,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	(0.02)
Oil Basis Swaps WTI Midland Index | Third Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,220,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	(0.08)
Oil Basis Swaps WTI Midland Index | Fourth Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,220,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	(0.08)
Oil Basis Swaps WTI Midland Index | 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,989,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	0.29
Oil Basis Swaps WTI Midland Index | First Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,980,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	0.25
Oil Basis Swaps WTI Midland Index | Second Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,365,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	0.31
Oil Basis Swaps WTI Midland Index | Third Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	644,000
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	0.38
Oil Basis Swaps WTI Midland Index | Fourth Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	0
Weighted Average Price
Weighted Avg Differential (USD per Bbl) | $ / bbl	0
Oil Roll Differential Swaps WTI Index | 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	4,313,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.13)
Oil Roll Differential Swaps WTI Index | Second Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,001,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.22)
Oil Roll Differential Swaps WTI Index | Third Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,656,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.10)
Oil Roll Differential Swaps WTI Index | Fourth Quarter - 2021 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,656,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.10)
Oil Roll Differential Swaps WTI Index | 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	3,265,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.03)
Oil Roll Differential Swaps WTI Index | First Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,620,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.10)
Oil Roll Differential Swaps WTI Index | Second Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	1,001,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	(0.01)
Oil Roll Differential Swaps WTI Index | Third Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	644,000
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	0.10
Oil Roll Differential Swaps WTI Index | Fourth Quarter - 2022 | Outstanding at end of period
Fair values of derivative assets and liabilities
Volume (Bbls) | bbl	0
Weighted Average Price
Weighted Avg Price (USD per unit) | $ / bbl	0

DERIVATIVE INSTRUMENTS - (Gain)

DERIVATIVE INSTRUMENTS - (Gain) Loss on Derivative Instruments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Derivative [Line Items]
Decrease (increase) in fair value of derivative instruments, net:	$ 99,401	$ (183,826)
Cash payments (receipts) on derivative instruments, net:	62,534	(43,114)
Loss (gain) on derivative instruments, net	161,935	(226,940)
Gas contracts
Derivative [Line Items]
Decrease (increase) in fair value of derivative instruments, net:	(447)	12,493
Cash payments (receipts) on derivative instruments, net:	15,265	(11,719)
Oil contracts
Derivative [Line Items]
Decrease (increase) in fair value of derivative instruments, net:	99,848	(196,319)
Cash payments (receipts) on derivative instruments, net:	$ 47,269	$ (31,395)

DERIVATIVE INSTRUMENTS - Deri_2

DERIVATIVE INSTRUMENTS - Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Asset
Total gross amounts presented in the balance sheet	$ 173	$ 6,848
Liability
Total gross amounts presented in the balance sheet	233,296	145,398
Not Designated as Hedging Instrument
Asset
Total gross amounts presented in the balance sheet	2,549	9,190
Less: gross amounts not offset in the balance sheet	(2,549)	(8,863)
Net amount	0	327
Liability
Total gross amounts presented in the balance sheet	255,907	163,147
Less: gross amounts not offset in the balance sheet	(2,549)	(8,863)
Net amount	253,358	154,284
Current assets — Derivative instruments | Not Designated as Hedging Instrument | Oil contracts
Asset
Total gross amounts presented in the balance sheet	173	5,425
Current assets — Derivative instruments | Not Designated as Hedging Instrument | Gas contracts
Asset
Total gross amounts presented in the balance sheet		1,423
Non-current assets — Derivative instruments | Not Designated as Hedging Instrument | Gas contracts
Asset
Total gross amounts presented in the balance sheet	2,376	2,342
Current liabilities — Derivative instruments | Not Designated as Hedging Instrument | Oil contracts
Liability
Total gross amounts presented in the balance sheet	191,019	106,507
Current liabilities — Derivative instruments | Not Designated as Hedging Instrument | Gas contracts
Liability
Total gross amounts presented in the balance sheet	42,277	38,891
Non-current liabilities — Derivative instruments | Not Designated as Hedging Instrument | Oil contracts
Liability
Total gross amounts presented in the balance sheet	$ 22,611	12,526
Non-current liabilities — Derivative instruments | Not Designated as Hedging Instrument | Gas contracts
Liability
Total gross amounts presented in the balance sheet		$ 5,223

FAIR VALUE MEASUREMENTS - Summa

FAIR VALUE MEASUREMENTS - Summary (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020	Apr. 30, 2017	Jun. 30, 2014
Financial Assets (Liabilities):
Derivative instruments — assets	$ 173	$ 6,848
Derivative instruments — liabilities	$ (233,296)	(145,398)
4.375% Notes due 2024 | Senior Notes
Financial Assets (Liabilities):
Stated interest rate of debt instrument (as a percent)	4.375%			4.375%
3.90% Notes due 2027 | Senior Notes
Financial Assets (Liabilities):
Stated interest rate of debt instrument (as a percent)	3.90%		3.90%
4.375% Notes due 2029 | Senior Notes
Financial Assets (Liabilities):
Stated interest rate of debt instrument (as a percent)	4.375%
Book Value
Financial Assets (Liabilities):
Derivative instruments — assets	$ 2,549	9,190
Derivative instruments — liabilities	(255,907)	(163,147)
Book Value | 4.375% Notes due 2024
Financial Assets (Liabilities):
Long-term debt	(750,000)	(750,000)
Book Value | 3.90% Notes due 2027
Financial Assets (Liabilities):
Long-term debt	(750,000)	(750,000)
Book Value | 4.375% Notes due 2029
Financial Assets (Liabilities):
Long-term debt	(500,000)	(500,000)
Fair Value
Financial Assets (Liabilities):
Derivative instruments — assets	2,549	9,190
Derivative instruments — liabilities	(255,907)	(163,147)
Fair Value | 4.375% Notes due 2024
Financial Assets (Liabilities):
Long-term debt	(815,625)	(818,025)
Fair Value | 3.90% Notes due 2027
Financial Assets (Liabilities):
Long-term debt	(816,075)	(826,575)
Fair Value | 4.375% Notes due 2029
Financial Assets (Liabilities):
Long-term debt	$ (553,050)	$ (567,250)

FAIR VALUE MEASUREMENTS - Narra

FAIR VALUE MEASUREMENTS - Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Other Financial Instruments
Accrued operating expenses	$ 74.1	$ 67.4
Accrued general and administrative costs		46.8
Accrued regular payroll-related costs		34.1
Accrued voluntary early retirement incentive program and involuntary reduction in workforce accruals	5	11.3
Allowance for Trade Receivables
Other Financial Instruments
Aggregate allowance for doubtful accounts	$ 2.6	$ 2.6

CAPITAL STOCK - Narrative (Deta

CAPITAL STOCK - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Feb. 28, 2021	Mar. 31, 2021	Dec. 31, 2020
Class of Stock [Line Items]
Common stock authorized (shares)		200,000,000	200,000,000
Preferred stock authorized (shares)		15,000,000
Common stock outstanding (shares)		102,800,000
Preferred stock dividend rate (as a percent)		8.125%	8.125%
Preferred stock liquidation preference per share (USD per share)		$ 1,000
Preferred stock, liquidation preference		$ 28.2
Price received per share upon conversion (USD per share)		$ 471.40
Stock issued upon conversion of preferred stock (shares)		8.42579
Dividends
Dividends declared per common share (USD per share)	$ 0.27
Dividends declared		$ 27.9
Dividends declared per preferred share (USD per share)	$ 20.3125
Preferred stock cash dividends	$ 0.6
Series A Preferred Stock
Class of Stock [Line Items]
Preferred stock authorized (shares)		28,200

STOCK-BASED COMPENSATION - Summ

STOCK-BASED COMPENSATION - Summary (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Options, Restricted Stock and Unit Awards
Stock compensation cost	$ 12,055	$ 11,935
Less amounts capitalized to oil and gas properties	(3,506)	(5,541)
Stock-based compensation expense	8,549	6,394
Restricted stock awards:
Options, Restricted Stock and Unit Awards
Stock compensation cost	11,581	11,437
Performance stock awards
Options, Restricted Stock and Unit Awards
Stock compensation cost	3,282	4,060
Service-based stock awards
Options, Restricted Stock and Unit Awards
Stock compensation cost	8,299	7,377
Stock option awards
Options, Restricted Stock and Unit Awards
Stock compensation cost	$ 474	$ 498

ASSET RETIREMENT OBLIGATIONS -

ASSET RETIREMENT OBLIGATIONS - Summary (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Asset Retirement Obligations
Balance at beginning of year	$ 177,867
Liabilities incurred	363
Liability settlements and disposals	(2,173)
Accretion expense	1,866
Balance at end of year	177,923
Less current obligation	(11,381)
Long-term asset retirement obligation	$ 166,542	$ 165,595

EARNINGS (LOSS) PER SHARE - Sum

EARNINGS (LOSS) PER SHARE - Summary (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Income (Numerator)
Net (loss) income	$ 128,082	$ (774,282)
Less: dividends and net income attributable to participating securities	(2,779)	(550)
Less: redeemable preferred stock dividends	(572)	(1,269)
Basic EPS - (Loss) income available to common stockholders	124,731	(776,101)
Dilutive Securities, Effect on Basic Earnings Per Share	1	0
Diluted EPS - (Loss) income available to common stockholders and assumed conversions	$ 124,732	$ (776,101)
Shares (Denominator)
Basic EPS - (Loss) income available to common stockholders (shares)	100,126,000	99,842,000
Effects of dilutive securities - options (shares)	37,000	0
Diluted EPS - (Loss) income available to common stockholders and assumed conversions (shares)	100,163,000	99,842,000
Per-Share Amount
Basic EPS - (Loss) income available to common stockholders (USD per share)	$ 1.25	$ (7.77)
Diluted EPS - (Loss) income available to common stockholders and assumed conversions (USD per share)	$ 1.25	$ (7.77)
Employee Stock Option
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Excluded antidilutive securities (shares)	496,100	474,500
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Excluded antidilutive securities (shares)	237,300	511,100
Restricted Stock Awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Excluded antidilutive securities (shares)		8,800

INCOME TAXES - Components of th

INCOME TAXES - Components of the Provision for Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Income Tax Expense (Benefit)
Current tax benefit	$ 0	$ (198)
Deferred tax expense (benefit)	40,170	(16,357)
Income tax expense (benefit)	$ 40,170	$ (16,555)
Combined federal and state effective income tax rate (as a percent)	23.90%	2.10%

INCOME TAXES - Narrative (Detai

INCOME TAXES - Narrative (Details) - USD ($)	Mar. 31, 2021	Dec. 31, 2020
Income Tax Contingency [Line Items]
U.S. net tax operating loss carryforward		$ 1,997,000,000
U.S. net tax operating loss carryforward subject to expiration		1,773,000,000
U.S. net tax operating loss carryforward not subject to expiration		224,400,000
Unrecognized tax benefits that would impact the entity's effective rate	$ 0
Provisions for interest or penalties related to uncertain tax positions	0
State Jurisdiction
Income Tax Contingency [Line Items]
Valuation allowance against net operating loss carryovers	$ 120,700,000
Oil Recovery and Marginal Well Credits
Income Tax Contingency [Line Items]
Tax credit carryforward		$ 4,200,000

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2021USD ($)Bcf
Construction, Drilling and Purchase Commitments
Maximum financial commitment resulting from inability to meet water delivery commitments	$ 62.5
Drilling Commitments
Construction, Drilling and Purchase Commitments
Commitments for purchases and other expenditures	282.1
Gathering System Construction
Construction, Drilling and Purchase Commitments
Commitments for purchases and other expenditures	$ 5.2
Natural Gas Sales Contracts
Construction, Drilling and Purchase Commitments
Oil and gas delivery commitments and contracts, remaining contractual volume (bcf) | Bcf	456.5
Oil and gas delivery commitments and contracts, period	10 years 3 months 18 days
Maximum financial commitment resulting from inability to meet gas delivery commitments	$ 913
Gas Gathering and Processing Agreements
Construction, Drilling and Purchase Commitments
Oil and gas delivery commitments and contracts, period	7 years 9 months 18 days
Maximum financial commitment resulting from inability to meet gas delivery commitments	$ 621.9
Minimum Volume Agreement
Construction, Drilling and Purchase Commitments
Maximum financial commitment resulting from inability to meet gas delivery commitments	108.8
Commitment liability	4.2
Other Transportation and Delivery Commitments and Facilities Commitments
Construction, Drilling and Purchase Commitments
Maximum financial commitment resulting from inability to meet gas delivery commitments	$ 14.5

SUPPLEMENTAL CASH FLOW INFORM_3

SUPPLEMENTAL CASH FLOW INFORMATION - Summary (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash paid during the period for:
Interest (net of capitalized amounts)	$ 5,985	$ 5,559
Income taxes	30	0
Cash received for income tax refunds	266	204
Capitalized interest	$ 6,013	$ 7,328

RELATED PARTY TRANSACTIONS - Na

RELATED PARTY TRANSACTIONS - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Helmerich & Payne
Related Party Transaction [Line Items]
Contract drilling service costs	$ 2,800,000	$ 15,600,000