Gulfport Energy (GPOR) 10-Q 9 Nov 20 2020 Q3 Quarterly report Financial data

COVER PAGE

COVER PAGE - shares	9 Months Ended
	Sep. 30, 2020	Nov. 05, 2020
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2020
Document Transition Report	false
Entity File Number	001-19514
Entity Registrant Name	Gulfport Energy Corp
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	73-1521290
Entity Address, Address Line One	3001 Quail Springs Parkway
Entity Address, City or Town	Oklahoma City,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73134
City Area Code	405
Local Phone Number	252-4600
Title of 12(b) Security	Common stock, par value $0.01 per share
Trading Symbol	GPOR
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		160,762,186
Amendment Flag	false
Entity Central Index Key	0000874499
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 51,043	$ 6,060
Accounts receivable—oil and natural gas sales	92,443	121,210
Accounts receivable—joint interest and other	15,421	47,975
Prepaid expenses and other current assets	51,187	4,431
Short-term derivative instruments	6,245	126,201
Current assets	216,339	305,877
Property and equipment:
Oil and natural gas properties, full-cost accounting, $1,526,941 and $1,686,666 excluded from amortization in 2020 and 2019, respectively	10,786,305	10,595,735
Other property and equipment	95,921	96,719
Accumulated depletion, depreciation, amortization and impairment	(8,779,704)	(7,228,660)
Property and equipment, net	2,102,522	3,463,794
Other assets:
Equity investments	16,560	32,044
Long-term derivative instruments	1,098	563
Deferred tax asset	0	7,563
Operating lease assets	2,012	14,168
Operating lease assets—related parties	0	43,270
Other assets	37,028	15,540
Total other assets	56,698	113,148
Total assets	2,375,559	3,882,819
Current liabilities:
Accounts payable and accrued liabilities	295,359	415,218
Short-term derivative instruments	24,164	303
Current portion of operating lease liabilities	1,757	13,826
Current portion of operating lease liabilities—related parties	0	21,220
Current maturities of long-term debt	656	631
Current liabilities	321,936	451,198
Long-term derivative instruments	63,803	53,135
Asset retirement obligation	62,935	60,355
Uncertain tax position liability	3,371	3,127
Non-current operating lease liabilities	255	342
Non-current operating lease liabilities—related parties	0	22,050
Long-term debt, net of current maturities	2,068,036	1,978,020
Total liabilities	2,520,336	2,568,227
Commitments and contingencies (Note 9)
Preferred stock - $0.01 par value; 5.0 million shares authorized (30 thousand authorized as redeemable 12% cumulative preferred stock, Series A), and none issued and outstanding	0	0
Stockholders’ equity:
Common stock - $0.01 par value, 200.0 million shares authorized, 160.8 million issued and outstanding at September 30, 2020 and 159.7 million at December 31, 2019	1,607	1,597
Paid-in capital	4,212,241	4,207,554
Accumulated other comprehensive loss	(51,330)	(46,833)
Accumulated deficit	(4,307,295)	(2,847,726)
Total stockholders’ equity	(144,777)	1,314,592
Total liabilities and stockholders’ equity	$ 2,375,559	$ 3,882,819

CONSOLIDATED BALANCE SHEETS (PA

CONSOLIDATED BALANCE SHEETS (PARENTHETICAL) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Capitalized costs of oil and natural gas properties excluded from amortization	$ 1,526,941	$ 1,686,666
Preferred stock, par value (in usd per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	5,000,000	5,000,000
Preferred stock, shares authorized (in shares)	30,000	30,000
Preferred stock, dividend rate	12.00%	12.00%
Preferred stock Series A, issued (in shares)	0	0
Preferred stock Series A, outstanding (in shares)	0	0
Common stock, par value (in usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	200,000,000	200,000,000
Common stock, shares, issued (in shares)	160,800,000	159,700,000
Common stock, shares, outstanding (in shares)	160,800,000	159,700,000

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
REVENUES:
Net (loss) gain on natural gas, oil and NGL derivatives	$ (53,823)	$ 27,074	$ 71,414	$ 178,169
Total Revenues	136,176	341,746	621,815	1,226,658
OPERATING EXPENSES:
Lease operating expenses	15,274	22,473	46,946	64,668
Production taxes	4,028	6,565	12,432	22,584
Midstream gathering and processing expenses	110,567	135,006	334,789	382,643
Depreciation, depletion and amortization	51,551	163,270	194,369	406,654
Impairment of oil and natural gas properties	270,874	571,442	1,357,099	571,442
General and administrative expenses	20,524	13,198	46,546	34,982
Restructuring and liability management	8,984	0	9,601	0
Accretion expense	774	747	2,270	3,173
Total Operating Expenses	482,576	912,701	2,004,052	1,486,146
LOSS FROM OPERATIONS	(346,400)	(570,955)	(1,382,237)	(259,488)
OTHER EXPENSE (INCOME):
Interest expense	34,321	35,556	99,677	107,595
Interest income	(52)	(338)	(282)	(649)
Gain on debt extinguishment	0	(23,600)	(49,579)	(23,600)
Loss from equity method investments, net	153	43,082	10,987	164,391
Other expense (income)	141	3,194	9,239	3,757
Total Other Expense	34,563	57,894	70,042	251,494
LOSS BEFORE INCOME TAXES	(380,963)	(628,849)	(1,452,279)	(510,982)
Income Tax (Benefit) Expense	0	(144,047)	7,290	(323,378)
NET LOSS	$ (380,963)	$ (484,802)	$ (1,459,569)	$ (187,604)
NET LOSS PER COMMON SHARE:
Basic (in usd per share)	$ (2.37)	$ (3.04)	$ (9.12)	$ (1.17)
Diluted (in usd per share)	$ (2.37)	$ (3.04)	$ (9.12)	$ (1.17)
Weighted average common shares outstanding - Basic (in shares)	160,682,629	159,548,477	160,053,093	160,553,796
Weighted average common shares outstanding - Diluted (in shares)	160,682,629	159,548,477	160,053,093	160,553,796
Natural gas sales
REVENUES:
Revenue from contract with customer	$ 155,163	$ 269,798	$ 456,859	$ 876,411
Oil and condensate sales
REVENUES:
Revenue from contract with customer	16,012	24,550	47,553	93,942
Natural gas liquid sales
REVENUES:
Revenue from contract with customer	$ 18,824	$ 20,324	$ 45,989	$ 78,136

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Statement of Comprehensive Income [Abstract]
Net loss	$ (380,963)	$ (561,068)	$ (517,538)	$ (484,802)	$ 234,956	$ 62,242	$ (1,459,569)	$ (187,604)
Foreign currency translation adjustment	3,661			(2,064)			(4,497)	5,347
Other Comprehensive Loss	3,661	$ 6,872	$ (15,030)	(2,064)	$ 3,610	$ 3,801	(4,497)	5,347
Comprehensive loss	$ (377,302)			$ (486,866)			$ (1,464,066)	$ (182,257)

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common Stock	Paid-in Capital	Accumulated Other Comprehensive (Loss) Income	Accumulated Deficit
Beginning balance (in shares) at Dec. 31, 2018		162,986,000
Beginning balance at Dec. 31, 2018	$ 3,327,768	$ 1,630	$ 4,227,532	$ (56,026)	$ (845,368)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	62,242				62,242
Other Comprehensive Income (Loss)	3,801			3,801
Stock Compensation	2,785		2,785
Shares Repurchased (in shares)		(3,619,000)
Shares Repurchased	(28,330)	$ (37)	(28,293)
Issuance of Restricted Stock (in shares)		55,000
Issuance of Restricted Stock	0	$ 1	(1)
Ending balance (in shares) at Mar. 31, 2019		159,422,000
Ending balance at Mar. 31, 2019	3,368,266	$ 1,594	4,202,023	(52,225)	(783,126)
Beginning balance (in shares) at Dec. 31, 2018		162,986,000
Beginning balance at Dec. 31, 2018	3,327,768	$ 1,630	4,227,532	(56,026)	(845,368)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(187,604)
Other Comprehensive Income (Loss)	5,347
Ending balance (in shares) at Sep. 30, 2019		159,709,000
Ending balance at Sep. 30, 2019	3,123,104	$ 1,597	4,205,158	(50,679)	(1,032,972)
Beginning balance (in shares) at Mar. 31, 2019		159,422,000
Beginning balance at Mar. 31, 2019	3,368,266	$ 1,594	4,202,023	(52,225)	(783,126)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	234,956				234,956
Other Comprehensive Income (Loss)	3,610			3,610
Stock Compensation	2,846		2,846
Shares Repurchased (in shares)		(297,000)
Shares Repurchased	(2,270)	$ (3)	(2,267)
Issuance of Restricted Stock (in shares)		271,000
Issuance of Restricted Stock	0	$ 3	(3)
Ending balance (in shares) at Jun. 30, 2019		159,396,000
Ending balance at Jun. 30, 2019	3,607,408	$ 1,594	4,202,599	(48,615)	(548,170)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(484,802)				(484,802)
Other Comprehensive Income (Loss)	(2,064)			(2,064)
Stock Compensation	2,651		2,651
Shares Repurchased (in shares)		(36,000)
Shares Repurchased	(89)		(89)
Issuance of Restricted Stock (in shares)		349,000
Issuance of Restricted Stock	0	$ 3	(3)
Ending balance (in shares) at Sep. 30, 2019		159,709,000
Ending balance at Sep. 30, 2019	$ 3,123,104	$ 1,597	4,205,158	(50,679)	(1,032,972)
Beginning balance (in shares) at Dec. 31, 2019	159,700,000	159,711,000
Beginning balance at Dec. 31, 2019	$ 1,314,592	$ 1,597	4,207,554	(46,833)	(2,847,726)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(517,538)				(517,538)
Other Comprehensive Income (Loss)	(15,030)			(15,030)
Stock Compensation	2,104		2,104
Shares Repurchased (in shares)		(80,000)
Shares Repurchased	(79)	$ (1)	(78)
Issuance of Restricted Stock (in shares)		211,000
Issuance of Restricted Stock	0	$ 2	(2)
Ending balance (in shares) at Mar. 31, 2020		159,842,000
Ending balance at Mar. 31, 2020	$ 784,049	$ 1,598	4,209,578	(61,863)	(3,365,264)
Beginning balance (in shares) at Dec. 31, 2019	159,700,000	159,711,000
Beginning balance at Dec. 31, 2019	$ 1,314,592	$ 1,597	4,207,554	(46,833)	(2,847,726)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(1,459,569)
Other Comprehensive Income (Loss)	$ (4,497)
Ending balance (in shares) at Sep. 30, 2020	160,800,000	160,762,000
Ending balance at Sep. 30, 2020	$ (144,777)	$ 1,607	4,212,241	(51,330)	(4,307,295)
Beginning balance (in shares) at Mar. 31, 2020		159,842,000
Beginning balance at Mar. 31, 2020	784,049	$ 1,598	4,209,578	(61,863)	(3,365,264)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(561,068)				(561,068)
Other Comprehensive Income (Loss)	6,872			6,872
Stock Compensation	1,515		1,515
Shares Repurchased (in shares)		(27,000)
Shares Repurchased	(28)		(28)
Issuance of Restricted Stock (in shares)		301,000
Issuance of Restricted Stock	0	$ 3	(3)
Ending balance (in shares) at Jun. 30, 2020		160,116,000
Ending balance at Jun. 30, 2020	231,340	$ 1,601	4,211,062	(54,991)	(3,926,332)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(380,963)				(380,963)
Other Comprehensive Income (Loss)	3,661			3,661
Stock Compensation	1,314		1,314
Shares Repurchased (in shares)		(136,000)
Shares Repurchased	(129)	$ (2)	(127)
Issuance of Restricted Stock (in shares)		782,000
Issuance of Restricted Stock	$ 0	$ 8	(8)
Ending balance (in shares) at Sep. 30, 2020	160,800,000	160,762,000
Ending balance at Sep. 30, 2020	$ (144,777)	$ 1,607	$ 4,212,241	$ (51,330)	$ (4,307,295)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Cash flows from operating activities:
Net loss	$ (1,459,569)	$ (187,604)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation and amortization	194,369	406,654
Impairment of oil and natural gas properties	1,357,099	571,442
Loss from equity investments	10,987	164,532
Gain on debt extinguishment	(49,579)	(23,600)
Net gain on derivative instruments	(71,414)	(178,169)
Net cash receipts on settled derivative instruments	225,364	80,744
Deferred income tax expense (benefit)	7,290	(323,378)
Other, net	12,753	15,242
Changes in operating assets and liabilities:
Decrease in accounts receivable—oil and natural gas sales	28,767	97,543
Decrease (increase) in accounts receivable—joint interest and other	32,827	(18,830)
(Increase) decrease in prepaid expenses and other current assets	(45,620)	4,359
(Decrease) increase in accounts payable and accrued liabilities	(40,552)	8,567
Other, net	(2,721)	(147)
Net cash provided by operating activities	200,001	617,355
Cash flows from investing activities:
Additions to oil and natural gas properties	(337,979)	(646,535)
Proceeds from sale of oil and natural gas properties	46,932	10,864
Additions to other property and equipment	(591)	(4,694)
Proceeds from sale of other property and equipment	942	204
Contributions to equity method investments	0	(432)
Distributions from equity method investments	0	1,945
Net cash used in investing activities	(290,696)	(638,648)
Cash flows from financing activities:
Principal payments on borrowings	(372,484)	(550,500)
Borrowings on line of credit	531,857	640,000
Repurchases of senior notes	(22,827)	(79,480)
Payments for repurchases of stock under approved stock repurchase program	0	(30,000)
Other, net	(868)	(900)
Net cash provided by (used in) financing activities	135,678	(20,880)
Net increase (decrease) in cash, cash equivalents and restricted cash	44,983	(42,173)
Cash, cash equivalents and restricted cash at beginning of period	6,060	52,297
Cash, cash equivalents and restricted cash at end of period	51,043	10,124
Supplemental disclosure of cash flow information:
Interest payments	73,979	85,272
Income tax receipts	0	(1,794)
Supplemental disclosure of non-cash transactions:
Capitalized stock-based compensation	2,189	3,313
Asset retirement obligation capitalized	2,343	6,846
Asset retirement obligation removed due to divestiture	(2,033)	(30,035)
Interest capitalized	907	2,782
Fair value of contingent consideration asset on date of divestiture	23,090	1,137
Foreign currency translation (loss) gain on equity method investments	$ (4,497)	$ 5,347

BASIS OF PRESENTATION, SUMMARY

BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN	BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN Basis of Presentation The accompanying unaudited consolidated financial statements have been prepared by Gulfport Energy Corporation (the “Company” or “Gulfport”) pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”), and reflect all adjustments that, in the opinion of management, are necessary for a fair presentation of the results for the interim periods reported in all material respects, on a basis consistent with the annual audited consolidated financial statements. All such adjustments are of a normal, recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles ("GAAP") have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. The consolidated financial statements should be read in conjunction with the consolidated financial statements and the summary of significant accounting policies and notes included in the Company’s most recent annual report on Form 10-K. Results for the three and nine months ended September 30, 2020 are not necessarily indicative of the results expected for the full year. Certain reclassifications have been made to prior period financial statements and related disclosures to conform to current period presentation. These reclassifications have no impact on previous reported total assets, total liabilities, net loss or total operating cash flows. COVID-19 I n March 2020, the World Health Organization classified the outbreak of COVID-19 as a pandemic and recommended containment and mitigation measures worldwide. The measures have led to worldwide shutdowns and halting of commercial and interpersonal activity, as governments around the world have imposed regulations in efforts to control the spread of COVID-19 such as shelter-in-place orders, quarantines, executive orders and similar restrictions. Gulfport remains focused on protecting the health and well-being of its employees and the communities in which it operates while assuring the continuity of its business operations. The Company implemented preventative measures and developed corporate and field response plans to minimize unnecessary risk of exposure and prevent infection. Additionally, the Company has a crisis management team for health, safety and environmental matters and personnel issues, and has established a COVID-19 Response Team to address various impacts of the situation, as they have been developing. Gulfport has modified certain business practices (including remote working for its corporate employees and restricted employee business travel) to conform to government restrictions and best practices encouraged by the Centers for Disease Control and Prevention, the World Health Organization and other governmental and regulatory authorities. In May 2020, the Company began its phased transition back to the office for its corporate employees. As part of this transition, the Company put into place preventative measures to focus on social distancing and minimizing unnecessary risk of exposure. As of the date of this filing, Gulfport has transitioned the vast majority of its employees back to the corporate office; however, the Company continues to provide a balanced work schedule that allows for a significant portion of the work week to be performed remotely. The Company will continue to monitor trends and governmental guidelines and may adjust its return to office plans accordingly to ensure the health and safety of its employees. As a result of its business continuity measures, the Company has not experienced significant disruptions in executing its business operations in 2020. On March 27, 2020, the U.S. government enacted the Coronavirus Aid, Relief, and Economic Security Act (“CARES Act”). The CARES Act did not have a material impact on the Company’s consolidated financial statements. Gulfport is closely monitoring the impact of COVID-19 on all aspects of its business and the current commodity price environment and is unable to predict the impact it will have on its future financial position or operating results. Industry Conditions, Liquidity, Management's Plans and Going Concern Decreased demand for oil and natural gas as a result of the COVID-19 pandemic has put further downward pressure on commodity pricing. In the current depressed commodity price environment and period of economic uncertainty, the Company has taken the following operational and financial measures in 2020 to improve its balance sheet and preserve liquidity: • Reduced 2020 capital spending by more than 50% as compared to 2019 • Focused on operational efficiencies to reduce operating costs; including significant improvements in development and completion costs per lateral foot • Repurchased $73.3 million of unsecured notes at a discount • Evaluated economics across our portfolio and shut-in certain non-economical production in the second quarter of 2020 • Reduced corporate general and administrative costs significantly through pay reductions, furloughs and reductions in force. Although management’s actions listed above have helped to improve the Company's liquidity and leverage profile, continued macro headwinds including the depressed state of energy capital markets and the extraordinarily low commodity price environments present significant risks to the Company's ability to fund its operations going forward. Additionally, subsequent to September 30, 2020, on October 8, 2020, the Company's borrowing base under its revolving credit facility was reduced for the second time during 2020. The October redetermination reduced the Company's borrowing base from $700 million to $580 million, thereby significantly reducing available liquidity. Considering the factors above, there is substantial doubt about the Company’s ability to maintain, repay, refinance or restructure its $2.1 billion of long-term debt. The Company elected not to make an interest payment of $17.4 million due October 15, 2020 on its 6.000% senior unsecured notes maturing 2024 (the “2024 Notes”). The Company elected not to make an interest payment of $10.8 million due November 2, 2020 on its 6.625% senior unsecured notes maturing 2023 (the "2023 Notes"). The elections to defer the interest payments do not constitute an “Event of Default” as defined under the indentures governing the 2024 Notes and 2023 Notes (the “Indentures”) if the interest payments are made within 30 days of the due date. If the Company does not make such interest payments within such 30-day period, there will be an event of default under the Indentures upon expiration of the grace period and there can be no assurance that it will have sufficient funds to pay such interest payments prior to such time. Additionally, on October 15, 2020, the Company entered into the First Forbearance Agreement and Amendment to the Amended and Restated Credit Agreement (the "First Forbearance Agreement"). Pursuant to the First Forbearance Agreement, the lender parties have agreed to (i) temporarily waive any default in connection with the non-payment of interest on the 2024 Notes within 30 days of becoming due (the “Specified Default”) prior to its occurrence without any further action and (ii) forbear from exercising certain of their default-related rights and remedies against the Company and the other loan parties with respect to any default in connection with the Specified Default, in each case, until the earlier of October 29, 2020 or another event that would trigger the end of the forbearance period. On October 26, 2020, the Company entered into the Second Forbearance Agreement and Amendment to Amended and Restated Credit Agreement (the "Second Forbearance Agreement"), which extends the First Forbearance Agreement. Pursuant to the Second Forbearance Agreement, the lender parties have agreed to (i) temporarily waive any default in connection with the Specified Default prior to its occurrence without any further action, (ii) expand the definition of "Specified Default" to include the failure to make the interest payment on the 2023 Notes within 30 days of becoming due and (iii) extend the agreement to forbear from exercising certain of their default-related rights and remedies against the Company and the other loan parties with respect to any default in connection with the Specified Default, in each case, until the earlier of November 13, 2020 or another event that would trigger the end of the forbearance period. Moreover, the Company's existing revolving credit facility matures in December 2021 and therefore will become a current liability at year end 2020 unless the Company is able to refinance the credit facility with a new credit facility or other financing. Considering the current state of the first lien market and the Company's elevated leverage profile, there is substantial risk that a refinancing will not be available to the Company on reasonable terms. A current liability under the revolving credit facility at year end 2020 may result in a qualified audit opinion which could result in a default under the terms of the current revolving credit facility. Failure to meet the Company's obligations under its existing indebtedness or failure to comply with any of its covenants, if not waived, would result in an event of default under such indebtedness and result in the potential acceleration of outstanding indebtedness thereunder and, with respect to the revolving credit facility, the potential foreclosure on the collateral securing such debt, and could cause a cross-default under its other outstanding indebtedness. As a result of these uncertainties and other factors, management has concluded that there is substantial doubt about the Company's ability to continue as a going concern over the next twelve months from the issuance of these financial statements. The Company has engaged financial and legal advisors to assist with the evaluation of a range of liability management alternatives. Additionally, the Company maintains an active dialogue with its senior lenders and bondholders regarding liability management alternatives to improve its balance sheet. There can be no assurances that the Company will be able to successfully complete a liability management transaction that materially improves the Company’s leverage profile or liquidity position. The consolidated financial statements (i) have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities and other commitments in the normal course of business and (ii) do not include any adjustments to reflect the possible future effects of the uncertainty on the recoverability or classification of recorded asset amounts or the amounts or classifications of liabilities. Impact on Previously Reported Results During the third quarter of 2020, the Company identified that certain transportation activities during the three and nine months ended September 30, 2019 were misclassified between "natural gas sales" and "midstream gathering and processing expenses" on its consolidated statements of operations. The Company assessed the materiality of this presentation on prior periods’ consolidated financial statements in accordance with the SEC Staff Accounting Bulletin No. 99, “Materiality”, codified in Accounting Standards Codification (“ASC”) Topic 250, “Accounting Changes and Error Corrections.” Based on this assessment, the Company concluded that the correction is not material to any previously issued financial statements. The correction had no impact on its consolidated balance sheets, consolidated statements of comprehensive income, consolidated statements of stockholders' equity or consolidated statements of cash flows. Additionally, the error had no impact on net loss or net loss per share. The Company will conform presentation of previously reported consolidated statements of operations and condensed consolidating statements of operations in future filings. The following tables present the effect of the correction on all affected line items of our previously issued consolidated financial statements of operations for the three and nine months ended September 30, 2019. Three months ended September 30, 2019 As Reported Adjustments As Revised (In thousands) Natural gas sales $ 213,227 $ 56,571 $ 269,798 Total Revenues $ 285,175 $ 56,571 $ 341,746 Midstream gathering and processing expenses $ 78,435 $ 56,571 $ 135,006 Total Operating Expenses (1) $ 856,130 $ 56,571 $ 912,701 Nine months ended September 30, 2019 As Reported Adjustments As Revised (In thousands) Natural gas sales $ 714,500 $ 161,911 $ 876,411 Total Revenues $ 1,064,747 $ 161,911 $ 1,226,658 Midstream gathering and processing expenses $ 220,732 $ 161,911 $ 382,643 Total Operating Expenses (1) $ 1,324,235 $ 161,911 $ 1,486,146 (1) Reflects additional immaterial presentation change made in the fourth quarter of 2019. Recently Adopted Accounting Standards On January 1, 2020, the Company adopted ASU No. 2016-13, Financial Instruments-Credit Losses: Measurement of Credit Losses on Financial Instruments , which replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions and reasonable and supportable forecasts that affect the collectability of the reported amount. The Company adopted the new standard using the prospective transition method, and it did not have a material impact on the Company's consolidated financial statements and related disclosures.

PROPERTY AND EQUIPMENT

PROPERTY AND EQUIPMENT	9 Months Ended
	Sep. 30, 2020
Property, Plant and Equipment [Abstract]
PROPERTY AND EQUIPMENT	PROPERTY AND EQUIPMENT The major categories of property and equipment and related accumulated depletion, depreciation, amortization ("DD&A") and impairment as of September 30, 2020 and December 31, 2019 are as follows: September 30, 2020 December 31, 2019 (In thousands) Oil and natural gas properties $ 10,786,305 $ 10,595,735 Accumulated DD&A and impairment (8,735,750) (7,191,957) Oil and natural gas properties, net 2,050,555 3,403,778 Other depreciable property and equipment 91,101 91,198 Land 4,820 5,521 Accumulated DD&A (43,954) (36,703) Other property and equipment, net 51,967 60,016 Property and equipment, net $ 2,102,522 $ 3,463,794 Under the full cost method of accounting, the Company is required to perform a ceiling test each quarter. The test determines a limit, or ceiling, on the book value of the Company's oil and natural gas properties. At September 30, 2020, the net book value of the Company's oil and gas properties was above the calculated ceiling primarily as a result of reduced commodity prices for the period leading up to September 30, 2020. As a result, the Company was required to record impairments of its oil and natural gas properties of $270.9 million and $1.4 billion for the three and nine months ended September 30, 2020, respectively. The Company was required to record impairments of its oil and natural gas properties of $571.4 million in each of the three and nine months ended September 30, 2019. Based on prices for the last nine months and the short-term pricing outlook for the fourth quarter of 2020, recognition of an additional full cost impairment in the fourth quarter of 2020 is possible. The amount of any future impairments is difficult to predict as it depends on future commodity prices, production rates, proved reserves, evaluation of costs excluded from amortization, future development costs and production costs. Any future full cost impairments are not expected to have an impact to the Company's future cash flows or liquidity. General and administrative costs capitalized to the full cost pool represent management’s estimate of costs incurred directly related to exploration and development activities such as geological and other costs associated with overseeing exploration and development activities. All general and administrative costs not directly associated with exploration and development activities are charged to expense as they are incurred. Capitalized general and administrative costs were approximately $6.2 million and $19.8 million for the three and nine months ended September 30, 2020, respectively, and $9.8 million and $26.3 million for the three and nine months ended September 30, 2019, respectively. The following table summarizes the Company’s unevaluated properties excluded from amortization by area at September 30, 2020: September 30, 2020 (In thousands) Utica $ 850,643 SCOOP 674,280 Other 2,018 $ 1,526,941 At December 31, 2019, approximately $1.7 billion of unevaluated properties were not subject to amortization. The Company evaluates the costs excluded from its amortization calculation at least annually. Individually insignificant unevaluated properties are grouped for evaluation and periodically transferred to evaluated properties over a timeframe consistent with their expected development schedule. Asset Retirement Obligation A reconciliation of the Company’s asset retirement obligation for the nine months ended September 30, 2020 and 2019 is as follows: September 30, 2020 September 30, 2019 (In thousands) Asset retirement obligation, beginning of period $ 60,355 $ 79,952 Liabilities incurred 2,343 5,769 Liabilities settled — (117) Liabilities removed due to divestitures (2,033) (30,035) Accretion expense 2,270 3,173 Revisions in estimated cash flows — 1,077 Asset retirement obligation as of end of period $ 62,935 $ 59,819

DIVESTITURES

DIVESTITURES	9 Months Ended
	Sep. 30, 2020
Discontinued Operations and Disposal Groups [Abstract]
DIVESTITURES	DIVESTITURESSale of Water Infrastructure Assets On January 2, 2020, the Company closed on the sale of its SCOOP water infrastructure assets to a third-party water service provider. The Company received $50.0 million in cash proceeds upon closing and has an opportunity to earn potential additional incentive payments over the next 15 years, subject to the Company's ability to meet certain thresholds which will be driven by, among other things, the Company's future development program and water production levels. The agreement contained no minimum volume commitments. The fair value of the contingent consideration as of the closing date was $23.1 million. The divested assets were included in the amortization base of the full cost pool and no gain or loss was recognized in the accompanying consolidated statements of operations as a result of the sale.

EQUITY INVESTMENTS

EQUITY INVESTMENTS	9 Months Ended
	Sep. 30, 2020
Equity Method Investments and Joint Ventures [Abstract]
EQUITY INVESTMENTS	EQUITY INVESTMENTS Investments accounted for by the equity method consist of the following as of September 30, 2020 and December 31, 2019: Carrying value (Loss) income from equity method investments Approximate ownership % September 30, 2020 December 31, 2019 Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Investment in Grizzly Oil Sands ULC 24.6 % $ 16,521 $ 21,000 $ (153) $ (41) $ (341) $ (380) Investment in Mammoth Energy Services, Inc. 21.5 % — 11,005 — (43,041) (10,646) (166,096) Investment in Windsor Midstream LLC 22.5 % 39 39 — — — Investment in Tatex Thailand II, LLC 23.5 % — — — — — 2,085 $ 16,560 $ 32,044 $ (153) $ (43,082) $ (10,987) $ (164,391) The tables below summarize financial information for the Company’s equity investments as of September 30, 2020 and December 31, 2019. Summarized balance sheet information: September 30, 2020 December 31, 2019 (In thousands) Current assets $ 463,853 $ 421,326 Noncurrent assets $ 1,086,150 $ 1,260,075 Current liabilities $ 115,976 $ 132,569 Noncurrent liabilities $ 161,183 $ 163,241 Summarized results of operations: Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Gross revenue $ 70,534 $ 113,417 $ 228,026 $ 557,375 Net (loss) income $ 2,808 $ (35,730) $ (97,145) $ (15,046) Grizzly Oil Sands ULC The Company, through its wholly owned subsidiary Grizzly Holdings Inc. (“Grizzly Holdings”), owns an approximate 24.6% interest in Grizzly Oil Sands ULC (“Grizzly”), a Canadian unlimited liability company. The remaining interest in Grizzly is owned by Grizzly Oil Sands Inc. As of September 30, 2020, Grizzly had approximately 830,000 acres under lease in the Athabasca, Peace River and Cold Lake oil sands regions of Alberta, Canada. The Company reviewed its investment in Grizzly for impairment at September 30, 2020 and 2019 and determined no impairment was required. The Company paid $0.4 million in cash calls during the nine months ended September 30, 2019 prior to its election to cease funding further capital calls. Grizzly’s functional currency is the Canadian dollar. The Company’s investment in Grizzly increased by $3.7 million as a result of a foreign currency translation gain and decreased by $4.1 million as a result of a foreign currency translation loss for the three and nine months ended September 30, 2020, respectively. The Company's investment in Grizzly was decreased by a $2.0 million foreign currency translation loss and increased by a $5.2 million foreign currency translation gain for the three and nine months ended September 30, 2019, respectively. Mammoth Energy Services, Inc. At September 30, 2020, the Company owned 9,829,548 shares, or approximately 21.5%, of the outstanding common stock of Mammoth Energy Services, Inc. ("Mammoth Energy"). The approximate fair value of the Company's investment in Mammoth Energy at September 30, 2020 was $15.7 million based on the quoted market price of Mammoth Energy's common stock. At March 31, 2020, the Company's share of net loss of Mammoth was in excess of the carrying value of its investment. As such, the Company's investment value was reduced to zero at March 31, 2020. During the third quarter of 2020, the Company's share of net loss of Mammoth continued to be in excess of the carrying value of its investment and, therefore, the Company's investment value remained at zero at September 30, 2020. The Company received no distributions from Mammoth Energy during the nine months ended September 30, 2020 and distributions of $2.5 million during the nine months ended September 30, 2019 as a result of $0.125 per share dividend in February 2019 and May 2019. The (loss) income from equity method investments presented in the table above reflects any intercompany profit eliminations. Windsor Midstream LLC At September 30, 2020, the Company held a 22.5% interest in Windsor Midstream LLC (“Midstream”), an entity controlled and managed by an unrelated third party. The Company received no distributions from Midstream during the nine months ended September 30, 2020. Tatex Thailand II, LLC

LONG-TERM DEBT

LONG-TERM DEBT	9 Months Ended
	Sep. 30, 2020
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT Long-term debt consisted of the following items as of September 30, 2020 and December 31, 2019: September 30, 2020 December 31, 2019 (In thousands) Revolving credit agreement (1) $ 279,857 $ 120,000 6.625% senior unsecured notes due 2023 324,583 329,467 6.000% senior unsecured notes due 2024 579,568 603,428 6.375% senior unsecured notes due 2025 507,870 529,525 6.375% senior unsecured notes due 2026 374,617 397,529 Net unamortized debt issuance costs (2) (19,772) (23,751) Construction loan 21,969 22,453 Less: current maturities of long term debt (656) (631) Debt reflected as long term $ 2,068,036 $ 1,978,020 (1) The Company has entered into a senior secured revolving credit facility, as amended (the "revolving credit facility"), with The Bank of Nova Scotia, as the lead arranger and administrative agent and other lenders. The credit agreement provides for a maximum facility of $1.5 billion and matures on December 13, 2021. On May 1, 2020, the Company entered into the fifteenth amendment to the Amended and Restated Credit Agreement. As part of the amendment, the Company's borrowing base and elected commitment were reduced from $1.2 billion and $1.0 billion, respectively, to $700.0 million. Additionally, the amendment added a requirement to maintain a ratio of Net Secured Debt to EBITDAX (as defined under the revolving credit agreement) not exceeding 2.00 to 1.00, deferred the requirement to maintain a ratio of Net Funded Debt to EBITDAX of 4.00 to 1.00 until September 30, 2021, and added a limitation on the repurchase of unsecured notes, among other amendments. On July 27, 2020, the Company entered into the sixteenth amendment to the Amended and Restated Credit Agreement. Among other changes, the Sixteenth Amendment amends the Credit Agreement to: (i) require that, in the event of any issuances of Senior Notes, including Second Lien Notes, after the effective date, the then effective borrowing base will be reduced by a variable amount prescribed in the Credit Agreement to the extent the proceeds are not used to satisfy previously issued senior notes within 90 days of such issuance; (ii) require that each Loan Notice specify the amount of the then effective Borrowing Base and Pro Forma Borrowing Base, the Aggregate Elected Commitment Amount, and the current Total Outstandings, both with and without regard to the requested Borrowing; (iii) permit the Borrower or any Restricted Subsidiary to enter into obligations in connection with a Permitted Bond Hedge Transaction or Permitted Warrant Transaction; (iv) permit the Borrower to make any payments of Senior Notes and Subordinated Obligation prior to their scheduled maturity, in any event not to exceed $750 million or, if lesser, the net cash proceeds of any Senior Notes issued within 90 days before such payment; (v) require that the Senior Notes have a stated maturity date of no earlier than March 13, 2024, as well as not require payment of principal prior to such date, in order for the Borrower to be permitted to secure indebtedness under the Senior Notes; (vi) permit certain additional liens securing obligations in respect of the incurrence or issuance of any Permitted Refinancing Notes (as such term is defined in the Credit Agreement) not to exceed $750 million, subject to the terms of an intercreditor agreement; and (vii) amend and restate the Applicable Rate Grid. As of September 30, 2020, $279.9 million was outstanding under the revolving credit facility and the total availability for future borrowings under this facility, after giving effect to an aggregate of $320.0 million letters of credit, was $100.1 million. The Company’s wholly owned subsidiaries have guaranteed the obligations of the Company under the revolving credit facility. At September 30, 2020, amounts borrowed under the revolving credit facility bore interest at a weighted average rate of 2.90%. The Company was in compliance with its financial covenants under the revolving credit facility at September 30, 2020. (2) Loan issuance costs related to the 2023 Notes, the 2024 Notes, the 6.375% Senior Notes due 2025 (the "2025 Notes") and the 6.375% Senior Notes due 2026 (the "2026 Notes") (collectively the “Notes”) have been presented as a reduction to the principal amount of the Notes. At September 30, 2020, total unamortized debt issuance costs were $2.6 million for the 2023 Notes, $5.7 million for the 2024 Notes, $8.1 million for the 2025 Notes and $3.3 million for the 2026 Notes. In addition, loan commitment fee costs for the Company's construction loan agreement were $0.1 million at September 30, 2020. The Company capitalized approximately $0.2 million and $0.9 million in interest expense to its unevaluated oil and natural gas properties during the three and nine months ended September 30, 2020, respectively. The Company capitalized approximately $1.0 million and $2.8 million in interest expense to its unevaluated oil and natural gas properties during the three and nine months ended September 30, 2019, respectively. Debt Repurchases In 2019, the Company's Board of Directors authorized $200 million of cash to be used to repurchase its senior notes in the open market at discounted values to par. The Company used borrowings under its revolving credit facility to repurchase in the open market $73.3 million aggregate principal amount of its outstanding Notes for $22.8 million during the nine months ended September 30, 2020. The Company recognized a $49.6 million gain on debt extinguishment, which included retirement of unamortized issuance costs and fees associated with the repurchased debt, during the nine months ended September 30, 2020. This gain is included in gain on debt extinguishment in the accompanying consolidated statements of operations. On May 1, 2020, further repurchases under this program were limited due to the agreements entered into under the fifteenth amendment to the Amended and Restated Credit Agreement of the Company's credit facility. As such, there were no repurchases during the three months ended September 30, 2020. Fair Value of Debt At September 30, 2020, the carrying value of the outstanding debt represented by the Notes was approximately $1.8 billion. Based on the quoted market prices (Level 1), the fair value of the Notes was determined to be approximately $1.1 billion at September 30, 2020. Subsequent Event On October 8, 2020, the Company's borrowing base under its revolving credit facility was reduced for the second time during 2020. The October redetermination reduced the Company's borrowing base from $700 million to $580 million, thereby significantly reducing available liquidity. Additionally, the Company elected not to make an interest payment of $17.4 million due October 15, 2020 on the 2024 Notes. The Company elected not to make an interest payment of $10.8 million due November 2, 2020 on the 2023 Notes. The elections to defer the interest payments do not constitute an “Event of Default” as defined under the Indentures if the interest payments are made within 30 days of the due date. If the Company does not make such interest payments within such 30-day period, there will be an event of default under the Indentures upon expiration of the grace period and there can be no assurance that it will have sufficient funds to pay such interest payments prior to such time. Additionally, on October 15, 2020, the Company entered into the First Forbearance Agreement. Pursuant to the First Forbearance Agreement, the lender parties have agreed to (i) temporarily waive any default in connection with the non-payment of interest on the 2024 Notes within 30 days of becoming due prior to its occurrence without any further action and (ii) forbear from exercising certain of their default-related rights and remedies against the Company and the other loan parties with respect to any default in connection with the Specified Default, in each case, until the earlier of October 29, 2020 or another event that would trigger the end of the forbearance period. On October 26, 2020, the Company entered into the Second Forbearance Agreement, which extends the First Forbearance Agreement. Pursuant to the Second Forbearance Agreement, the lender parties have agreed to (i) temporarily waive any default in connection with the Specified Default prior to its occurrence without any further action, (ii) expand the definition of "Specified Default" to include the failure to make the interest payment on the 2023 Notes within 30 days of becoming due and (iii) extend the agreement to forbear from exercising certain of their default-related rights and remedies against the Company and the other loan parties with respect to any default in connection with the Specified Default, in each case, until the earlier of November 13, 2020 or another event that would trigger the end of the forbearance period. As of November 5, 2020, $355.5 million was outstanding under the revolving credit facility, after giving effect to an aggregate of $243.7 million letters of credit outstanding, the Company had no availability under its revolver. As of November 5, 2020, the Company had $61.7 million in cash on hand to fund ongoing operations.

CHANGES IN CAPITALIZATION

CHANGES IN CAPITALIZATION	9 Months Ended
	Sep. 30, 2020
Equity [Abstract]
CHANGES IN CAPITALIZATION	CHANGES IN CAPITALIZATION Stock Repurchases In January 2019, the Company's Board of Directors approved a stock repurchase program to acquire a portion of the Company's outstanding common stock within a 24-month period. The program was suspended in the fourth quarter of 2019, and the May 1, 2020 amendment to the Company's revolving credit facility prohibits further stock repurchases. As a result, the Company did not repurchase any shares under the program during 2020, and repurchased approximately 3.8 million shares for a cost of approximat ely $30.0 million during the nine months ended September 30, 2019. Additionally, during the three and nine months ended September 30, 2020, the Company repurchased approximately 136,000 and 243,000 shares, respectively, for a cost of $0.1 million and $0.2 million, respectively, to satisfy tax withholding requirements incurred upon the vesting of restricted stock. During the three and nine months ended September 30, 2019, the Company repurchased approximately 36,000 and 123,000 shares, respectively, for a cost of approximately $0.1 million and $0.7 million, respectively, to satisfy tax withholding requirements incurred upon the vesting of restricted stock. All repurchased shares have been canceled and returned to the status of authorized but unissued shares.

STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2020
Share-based Payment Arrangement, Noncash Expense [Abstract]
STOCK-BASED COMPENSATION	STOCK-BASED COMPENSATIONThe Company has granted restricted stock units to employees and directors pursuant to the 2019 Amended and Restated Incentive Stock Plan ("2019 Plan"), as discussed below. In August 2020, all of the outstanding stock-based compensation issued to executives and the Board of Directors during 2020 was canceled and replaced with cash retention incentives, as discussed below. During the three and nine months ended September 30, 2020, the Company’s stock-based compensation cost was $8.9 million and $13.2 million, respectively, of which the Company capitalized $0.3 million and $2.2 million, respectively, relating to its exploration and development efforts. During the three and nine months ended September 30, 2019, the Company’s stock-based compensation cost was $2.7 million and $8.3 million, respectively, of which the Company capitalized $1.1 million and $3.3 million, respectively, relating to its exploration and development efforts. Stock compensation costs, net of the amounts capitalized, are included in general and administrative expenses in the accompanying consolidated statements of operations. The following table summarizes restricted stock unit activity for the nine months ended September 30, 2020: Number of Weighted Number of Weighted Unvested shares as of January 1, 2020 4,098,318 $ 4.73 1,783,660 $ 2.96 Granted 3,069,521 0.85 — — Vested (1,294,285) 5.73 — — Forfeited/canceled (4,166,493) 1.67 (943,065) 1.98 Unvested shares as of September 30, 2020 1,707,061 $ 4.73 840,595 $ 4.07 Restricted Stock Units Restricted stock units awarded under the 2019 Plan generally vest over a period of one year in the case of directors and three years in the case of employees and vesting is dependent upon the recipient meeting applicable service requirements. Stock-based compensation costs are recorded ratably over the service period. The grant date fair value of restricted stock units represents the closing market price of the Company's common stock on the date of grant. Unrecognized compensation expense as of September 30, 2020 related to restricted stock units was $6.4 million. The expense is expected to be recognized over a weighted average period of 1.52 years. Performance Vesting Restricted Stock Units The Company has awarded performance vesting units to certain of its executive officers under the 2019 Plan. The number of shares of common stock issued pursuant to the award will be based on relative total shareholder return ("RTSR"). RTSR is an incentive measure whereby participants will earn from 0% to 200% of the target award based on the Company’s RTSR ranking compared to the RTSR of the companies in the Company’s designated peer group at the end of the performance period. Awards will be earned and vested over a performance period measured from January 1, 2019 to December 31, 2021, subject to earlier termination of the performance period in the event of a change in control. Unrecognized compensation expense as of September 30, 2020 related to performance vesting restricted shares was $1.7 million. The expense is expected to be recognized over a weighted average period of 1.51 years. Cash Incentive Awards On March 16, 2020, the Board of Directors of the Company approved the Company's 2020 Incentive Plan (the "2020 Incentive Plan"). The 2020 Incentive Plan provided for incentive compensation opportunities ("Incentive Awards") for select employees of the Company that were tied to the achievement of one or more performance goals relating to certain financial and operational metrics over a period of time. During March 2020, the Company awarded Incentive Awards to certain of its executive officers under the 2020 Incentive Plan. The cash amount of each award to be ultimately received was based on the attainment of certain financial, operational and total shareholder return performance targets and was subject to the recipient's continuous employment. The Incentive Awards were considered liability awards as the ultimate amount of the award was based, at least in part, on the price of the Company's shares, and as such, were remeasured to fair value at the end of each reporting period. In August 2020 all previous unpaid amounts related to the Incentive Awards issued under the 2020 Incentive Plan were canceled and replaced with cash retention incentives, as discussed below. 2020 Compensation Adjustments On August 4, 2020, the Company's Board of Directors authorized a redesign of the incentive compensation program for the Company's workforce, including for its current named executive officers. In connection with a comprehensive review of the Company’s compensation programs and in consultation with its independent compensation consultant and legal advisors, the Board of Directors determined that significant changes were appropriate to retain and motivate the Company’s employees as a result of the ongoing uncertainty and unprecedented disruption in the oil and gas industry.

EARNINGS (LOSS) PER SHARE

EARNINGS (LOSS) PER SHARE	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
EARNINGS (LOSS) PER SHARE	EARNINGS (LOSS) PER SHARE Reconciliations of the components of basic and diluted net income per common share are presented in the tables below: Three months ended September 30, 2020 2019 Loss Shares Per Loss Shares Per (In thousands, except share data) Basic: Net loss $ (380,963) 160,682,629 $ (2.37) $ (484,802) 159,548,477 $ (3.04) Effect of dilutive securities: Stock awards — — — — Diluted: Net loss $ (380,963) 160,682,629 $ (2.37) $ (484,802) 159,548,477 $ (3.04) Nine months ended September 30, 2020 2019 Loss Shares Per Loss Shares Per (In thousands, except share data) Basic: Net loss $ (1,459,569) 160,053,093 $ (9.12) $ (187,604) 160,553,796 $ (1.17) Effect of dilutive securities: Stock options and awards — — — — Diluted: Net loss $ (1,459,569) 160,053,093 $ (9.12) $ (187,604) 160,553,796 $ (1.17) There were no potential shares of common stock that were considered anti-dilutive for the three and nine months ended September 30, 2020. There were 2,073,638 and 4,266,206 potential shares of common stock that were considered anti-dilutive for the three and nine months ended September 30, 2019, respectively.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Future Firm Sales Commitments The Company has entered into various firm sales contracts to deliver and sell natural gas. The Company expects to fulfill its delivery commitments primarily with production from proved developed reserves. The Company's proved reserves have generally been sufficient to satisfy its delivery commitments during the three most recent years, and it expects such reserves will continue to be the primary means of fulfilling its future commitments. However, where the Company's proved reserves are not sufficient to satisfy its delivery commitments, it can and may use spot market purchases to satisfy the commitments. A summary of these commitments at September 30, 2020 are set forth in the table below: (MMBtu per day) Remaining 2020 286,000 2021 183,000 2022 70,000 2023 17,000 Total 556,000 Future Firm Transportation Commitments The Company has contractual commitments with pipeline carriers for future transportation of natural gas from the Company's production areas to downstream markets. Commitments related to future firm transportation agreements are not recorded as obligations in the accompanying consolidated balance sheets; however, the costs associated with these commitments are reflected in the Company's estimates of proved reserves and future net revenues. Effective September 14, 2020, the Company entered into an amendment to the precedent agreement dated March 15, 2017 with Midship Pipeline Company, LLC ("Midship") to decrease firm transportation commitment volumes for the remainder of 2020 and 2021, requiring a prepayment for reservation charges and other covered obligations of $32.9 million. This prepayment is included in other assets in the accompanying consolidated balance sheets. A summary of these commitments at September 30, 2020 are set forth in the table below: Total MMBtu (In thousands) Remaining 2020 126,960,000 $ 67,458 2021 510,575,000 278,805 2022 535,414,000 288,135 2023 520,114,000 284,454 2024 493,841,000 267,077 Thereafter 3,791,093,000 2,220,685 Total 5,977,997,000 $ 3,406,614 As of September 30, 2020, the Company had entered into firm transportation contracts to deliver approximately 1,380,000 and 1,399,000 MMBtu per day for the remainder of 2020 and 2021, respectively. Under these firm transportation contracts, the Company is obligated to deliver minimum daily volumes or pay fees for any deficiencies in deliveries. As a result of the reduced production from the Company's Utica Shale or SCOOP acreage due to decreased developmental activities, taking into consideration the current low commodity price environment, the Company expects that its future production levels will be below the commitment amounts under the existing firm transportation contracts, resulting in excess firm transportation costs, which may be significant and may have a material adverse effect on its operations. Other Commitments Effective October 1, 2014, the Company entered into a Sand Supply Agreement with Muskie Proppant LLC (“Muskie”), a subsidiary of Mammoth Energy and a related party. Pursuant to this agreement, as amended effective August 3, 2018, the Company agreed to purchase annual and monthly amounts of proppant sand subject to exceptions specified in the agreement at agreed pricing plus agreed costs and expenses through 2021. Failure by either Muskie or the Company to deliver or accept the minimum monthly amount results in damages calculated per ton based on the difference between the monthly obligation amount and the amount actually delivered or accepted, as applicable. The Company incurred $1.9 million and $5.6 million in non-utilization fees under this agreement during the three and nine months ended September 30, 2020, respectively. The Company incurred $0.02 million and $0.4 million in non-utilization fees under this agreement during the three and nine months ended September 30, 2019, respectively. In August 2020, Muskie filed an action against the Company alleging that it breached its obligation to purchase a certain amount of proppant sand each month or make designated shortfall payments under the Sand Supply Agreement. See “ Litigation and Regulatory Proceedings ” below. Future minimum commitments under this agreement at September 30, 2020 are: (In thousands) Remaining 2020 $ 1,875 2021 7,500 Total $ 9,375 Litigation and Regulatory Proceedings The Company is involved in a number of litigation and regulatory proceedings including those described below. Many of these proceedings are in early stages, and many of them seek or may seek damages and penalties, the amount of which is indeterminate. The Company's total accrued liabilities in respect of litigation and regulatory proceedings is determined on a case-by-case basis and represents an estimate of probable losses after considering, among other factors, the progress of each case or proceeding, its experience and the experience of others in similar cases or proceedings, and the opinions and views of legal counsel. Significant judgment is required in making these estimates and their final liabilities may ultimately be materially different. The Company, along with a number of other oil and gas companies, has been named as a defendant in two separate complaints, one filed by the State of Louisiana and the Parish of Cameron in the 38th Judicial District Court for the Parish of Cameron on February 9, 2016 and the other filed by the State of Louisiana and the District Attorney for the 15th Judicial District of the State of Louisiana in the 15th Judicial District Court for the Parish of Vermilion on July 29, 2016 (together, the "Complaints"). The Complaints allege that certain of the defendants’ operations violated the State and Local Coastal Resources Management Act of 1978, as amended, and the rules, regulations, orders and ordinances adopted thereunder (the "CZM Laws") by causing substantial damage to land and waterbodies located in the coastal zone of the relevant Parish. The plaintiffs seek damages and other appropriate relief under the CZM Laws, including the payment of costs necessary to clear, re-vegetate, detoxify and otherwise restore the affected coastal zone of the relevant Parish to its original condition, actual restoration of such coastal zone to its original condition, and the payment of reasonable attorney fees and legal expenses and interest. The United States District Court for the Western District of Louisiana issued orders remanding the cases to their respective state court, and the defendants have appealed the remand orders to the 5th Circuit Court of Appeals. In July 2019, Pigeon Land Company, Inc., a successor in interest to certain of the Company’s legacy Louisiana properties, filed an action against the Company and many other oil and gas companies in the 16th Judicial District Court for the Parish of Iberia in Louisiana. The suit alleges negligence, strict liability and various violations of Louisiana statutes relating to property damage in connection with the historic development of the Company’s Louisiana properties and seeks unspecified damages (including punitive damages), an injunction to return the affected property to its original condition, and the payment of reasonable attorney fees and legal expenses and interest. In September 2019, a stockholder of Mammoth Energy filed a derivative action on behalf of Mammoth Energy against members of Mammoth Energy’s board of directors, including a director designated by the Company, and its significant stockholders, including the Company, in the United States District Court for the Western District of Oklahoma. The complaint alleges, among other things, that the members of Mammoth Energy’s board of directors breached their fiduciary duties and violated the Securities Exchange Act of 1934, as amended, in connection with Mammoth Energy’s activities in Puerto Rico following Hurricane Maria. The complaint seeks unspecified damages, the payment of reasonable attorney fees and legal expenses and interest and to force Mammoth Energy and its board of directors to make specified corporate governance reforms. In October 2019, Kelsie Wagner, in her capacity as trustee of various trusts and on behalf of the trusts and other similarly situated royalty owners, filed an action against the Company in the District Court of Grady County, Oklahoma. The suit alleges that the Company underpaid royalty owners and seeks unspecified damages for violations of the Oklahoma Production Revenue Standards Act and fraud. In March 2020, Robert F. Woodley, individually and on behalf of all others similarly situated, filed a federal securities class action against the Company, David M. Wood, Keri Crowell and Quentin R. Hicks in the United States District Court for the Southern District of New York. The complaint alleges that the Company made materially false and misleading statements regarding the Company’s business and operations in violation of the federal securities laws and seeks unspecified damages, the payment of reasonable attorneys’ fees, expert fees and other costs, pre-judgment and post-judgment interest, and such other and further relief that may be deemed just and proper. In June 2020, Sam L. Carter, derivatively on behalf of the Company, filed an action against certain of our current and former executive officers and directors in the United States District Court for the District of Delaware. The complaint alleged that the defendants breached their fiduciary duties to the Company in connection with certain alleged materially false and misleading statements regarding our business and operations in violation of the federal securities laws. The complaint sought to recover unspecified damages from the defendants, the implementation of specified corporate governance reforms, reasonable attorneys’ and experts’ fees, costs and expenses, and such other relief as may be deemed just and proper. The complaint was voluntarily dismissed without prejudice by the plaintiff in October 2020. In December 2019, the Company filed a lawsuit against Stingray Pressure Pumping LLC, a subsidiary of Mammoth Energy (“Stingray”), for breach of contract and to terminate the Master Services Agreement for pressure pumping services, effective as of October 1, 2014, as amended (the “Master Services Agreement”), between Stingray and the Company. In March 2020, Stingray filed a counterclaim against the Company in the Superior Court of the State of Delaware. The counterclaim alleges that the Company has breached the Master Services Agreement. The counterclaim seeks actual damages, which the complaint calculates to be approximately $37.0 million as of September 2020 (such amount to increase each month), the payment of reasonable attorney fees and legal expenses and pre- and post-judgment interest as allowed, and such other and further relief which it may be justly entitled. In April 2020, Bryon Lefort, individually and on behalf of similarly situated individuals, filed an action against the Company in the United States District Court for the Southern District of Ohio Eastern Division. The complaint alleges that the Company violated the Fair Labor Standards Act (“FLSA”), the Ohio Wage Act and the Ohio Prompt Pay Act by classifying the plaintiffs as independent contractors and paying them a daily rate with no overtime compensation for hours worked in excess of 40 hours per week. The complaint seeks to recover unpaid regular and overtime wages, liquidated damages in an amount equal to six of all unpaid overtime compensation, the payment of reasonable attorney fees and legal expenses and pre-judgment and post-judgment interest, and such other damages that may be owed to the workers. In August 2020, Muskie filed an action against the Company in the Superior Court of the State of Delaware for breach of contract. The complaint alleges that the Company breached its obligation to purchase a certain amount of proppant sand each month or make designated shortfall payments under the Sand Supply Agreement, effective October 1, 2014, as amended (the “Sand Supply Agreement”), between Muskie and the Company, and seeks payment of unpaid shortfall payments, which are estimated to be approximately $2.5 million as of September 2020, the payment of reasonable attorney’s fees and legal costs and expenses and pre- and post-judgment interest as allowed, and such other and further relief to which it may be justly entitled. These cases are still in their early stages. As a result, the Company has not had the opportunity to evaluate the allegations made in the plaintiffs' complaints and intends to vigorously defend the suits. SEC Investigation The SEC has commenced an investigation with respect to certain actions by former Company management, including alleged improper personal use of Company assets, and potential violations by former management and the Company of the Sarbanes-Oxley Act of 2002 in connection with such actions. The Company has fully cooperated and intends to continue to cooperate fully with the SEC’s investigation. Although it is not possible to predict the ultimate resolution or financial liability with respect to this matter, the Company believes that the outcome of this matter will not have a material effect on the Company’s business, financial condition or results of operations. Business Operations The Company is involved in various lawsuits and disputes incidental to its business operations, including commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions. Environmental Contingencies The nature of the oil and gas business carries with it certain environmental risks for Gulfport and its subsidiaries. Gulfport and its subsidiaries have implemented various policies, programs, procedures, training and audits to reduce and mitigate environmental risks. They conduct periodic reviews, on a company-wide basis, to assess changes in their environmental risk profile. Environmental reserves are established for environmental liabilities for which economic losses are probable and reasonably estimable. The Company manages its exposure to environmental liabilities in acquisitions by using an evaluation process that seeks to identify pre-existing contamination or compliance concerns and address the potential liability. Depending on the extent of an identified environmental concern, they may, among other things, exclude a property from the transaction, require the seller to remediate the property to their satisfaction in an acquisition or agree to assume liability for the remediation of the property. In October 2018, the company submitted a Voluntary Disclosure document to the Oklahoma Department of Environmental Quality (ODEQ) stemming from improper air permitting at several sites in Midcon between 2014 and 2017. The sites were permitted by Vitruvian prior to the Company's purchase of those assets. The sites were permitted utilizing the “permit by rule” regulation but actually required Title V air permits. The Company has agreed in a final Consent Order to obtain the proper permits and to pay the costs from not having the proper permits in place in the amount of $180,000 to the ODEQ. The Order received final approval at the ODEQ and was finalized in October 2020. Other Matters Based on management’s current assessment, they are of the opinion that no pending or threatened lawsuit or dispute relating to its business operations is likely to have a material adverse effect on their future consolidated financial position, results of operations or cash flows. The final resolution of such matters could exceed amounts accrued, however, and actual results could differ materially from management’s estimates.

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	9 Months Ended
	Sep. 30, 2020
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS Natural Gas, Oil and Natural Gas Liquids Derivative Instruments The Company seeks to reduce its exposure to unfavorable changes in natural gas, oil and natural gas liquids ("NGL") prices, which are subject to significant and often volatile fluctuation, by entering into over-the-counter fixed price swaps, basis swaps, costless collars and various types of option contracts. These contracts allow the Company to predict with greater certainty the effective natural gas, oil and NGL prices to be received for hedged production and benefit operating cash flows and earnings when market prices are less than the fixed prices provided in the contracts. However, the Company will not benefit from market prices that are higher than the fixed prices in the contracts for hedged production. Fixed price swaps are settled monthly based on differences between the fixed price specified in the contract and the referenced settlement price. When the referenced settlement price is less than the price specified in the contract, the Company receives an amount from the counterparty based on the price difference multiplied by the volume. Similarly, when the referenced settlement price exceeds the price specified in the contract, the Company pays the counterparty an amount based on the price difference multiplied by the volume. The prices contained in these fixed price swaps are based on the NYMEX Henry Hub for natural gas, the NYMEX West Texas Intermediate for oil and Mont Belvieu for propane, pentane and ethane. Below is a summary of the Company’s open fixed price swap positions as of September 30, 2020. Location Daily Volume Weighted Remaining 2020 NYMEX Henry Hub 500,000 $ 2.69 Location Daily Volume Weighted Remaining 2020 NYMEX WTI 3,000 $ 35.49 Location Daily Volume Weighted Remaining 2020 Mont Belvieu C3 1,500 $ 20.27 The Company sold call options in exchange for a premium, and used the associated premiums to enhance the fixed price for a portion of the fixed price natural gas swaps primarily for 2020 listed above. Each call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volumes. Location Daily Volume Weighted Average Price 2022 NYMEX Henry Hub 628,000 $ 2.90 2023 NYMEX Henry Hub 628,000 $ 2.90 The Company entered into costless collars based off the NYMEX Henry Hub natural gas index. Each two-way price collar has a set floor and ceiling price for the hedged production. If the applicable monthly price indices are outside of the ranges set by the floor and ceiling prices in the various collars, the Company will cash-settle the difference with the counterparty. Location Daily Volume (MMBtu/day) Weighted Average Floor Price Weighted Average Ceiling Price 2021 NYMEX Henry Hub 250,000 $ 2.46 $ 2.81 In addition, the Company entered into natural gas basis swap positions. As of September 30, 2020, the Company had the following natural gas basis swap positions open: Gulfport Pays Gulfport Receives Daily Volume Weighted Average Fixed Spread Remaining 2020 Transco Zone 4 NYMEX Plus Fixed Spread 60,000 $ (0.05) Remaining 2020 Fixed Spread ONEOK Minus NYMEX 10,000 $ (0.54) Subsequent Event In October 2020, the Company early terminated natural gas basis swaps which represented approximately 40,000 MMBtu of natural gas per day for the remainder of 2020. The early termination resulted in the Company receiving a cash settlement of $0.2 million. Additionally, in late October 2020 and early November 2020, the Company early terminated 475,000 MMBtu/day of 2022 sold calls with a strike price of $2.90. The early termination resulted in the Company incurring approximately $60.2 million of additional indebtedness on its revolving credit facility. Contingent Consideration Arrangement The Company sold its non-core assets located in the West Cote Blanche Bay and Hackberry fields of Louisiana in July 2019. The sale price included the potential for the Company to receive contingent payments based on commodity prices exceeding specified thresholds over the two years following the closing date. This contingent consideration arrangement was determined to be an embedded derivative. See below for threshold and potential payment amounts. Period Threshold (1) Payment to be received (2) July 2020 - June 2021 Greater than or equal to $60.65 $ 150,000 Between $52.62 - $60.65 Calculated Value (3) Less than or equal to $52.62 $ — (1) Based on the "WTI NYMEX + Argus LLS Differential," as published by Argus Media. (2) Payment will be assessed monthly from July 2020 through June 2021. If threshold is met, payment shall be received within five business days after the end of each calendar month. (3) If average daily price, as defined in (1), is greater than $52.62 but less than $60.65, payment received will be $150,000 multiplied by a fraction, the numerator of which is the amount determined by subtracting $52.62 from such average daily price, and the denominator of which is $8.03. Balance Sheet Presentation The Company reports the fair value of derivative instruments on the consolidated balance sheets as derivative instruments under current assets, noncurrent assets, current liabilities and noncurrent liabilities on a gross basis. The Company determines the current and noncurrent classification based on the timing of expected future cash flows of individual trades. The following table presents the fair value of the Company’s derivative instruments on a gross basis at September 30, 2020 and December 31, 2019: September 30, 2020 December 31, 2019 (In thousands) Commodity Contracts: Short-term derivative asset $ 6,245 $ 125,383 Long-term derivative asset 1,098 — Short-term derivative liability (24,164) (303) Long-term derivative liability (63,803) (53,135) Total commodity derivative position $ (80,624) $ 71,945 Contingent consideration arrangement: Short-term derivative asset $ — $ 818 Long-term derivative asset — 563 Total contingent consideration derivative position $ — $ 1,381 Total net (liability) asset derivative position $ (80,624) $ 73,326 Gains and Losses The following table presents the gain and loss recognized in net gain on natural gas, oil and NGL derivatives in the accompanying consolidated statements of operations for the three and nine months ended September 30, 2020 and 2019. Net (loss) gain on derivative instruments Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Natural gas derivatives $ (52,648) $ 11,731 $ 28,894 $ 147,774 Oil derivatives (782) 12,736 44,155 24,153 NGL derivatives (393) 3,641 (254) 7,276 Contingent consideration arrangement — (1,034) (1,381) (1,034) Total $ (53,823) $ 27,074 $ 71,414 $ 178,169 Offsetting of Derivative Assets and Liabilities As noted above, the Company records the fair value of derivative instruments on a gross basis. The following table presents the gross amounts of recognized derivative assets and liabilities in the consolidated balance sheets and the amounts that are subject to offsetting under master netting arrangements with counterparties, all at fair value. As of September 30, 2020 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount (In thousands) Derivative assets $ 7,343 $ (6,948) $ 395 Derivative liabilities $ (87,967) $ 6,948 $ (81,019) As of December 31, 2019 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount (In thousands) Derivative assets $ 126,764 $ (53,438) $ 73,326 Derivative liabilities $ (53,438) $ 53,438 $ — Concentration of Credit Risk By using derivative instruments that are not traded on an exchange, the Company is exposed to the credit risk of its counterparties. Credit risk is the risk of loss from counterparties not performing under the terms of the derivative instrument. When the fair value of a derivative instrument is positive, the counterparty is expected to owe the Company, which creates credit risk. To minimize the credit risk in derivative instruments, it is the Company’s policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. The Company’s derivative contracts are with multiple counterparties to lessen its exposure to any individual counterparty. Additionally, the Company uses master netting agreements to minimize credit risk exposure. The creditworthiness of the Company’s counterparties is subject to periodic review. None of the Company’s derivative instrument contracts contain credit-risk related contingent features. Other than as provided by the Company’s revolving credit facility, the Company is not required to provide credit support or collateral to any of its counterparties under its derivative instruments, nor are the counterparties required to provide credit support to the Company.

RESTRUCTURING AND LIABILITY MAN

RESTRUCTURING AND LIABILITY MANAGEMENT	9 Months Ended
	Sep. 30, 2020
Restructuring and Related Activities [Abstract]
RESTRUCTURING AND LIABILITY MANAGEMENT	RESTRUCTURING AND LIABILITY MANAGEMENT In the third quarter of 2020, the Company announced and completed a workforce reduction representing approximately 10% of its headcount. Charges related to the reduction in workforce primarily consisted of one-time employee-related termination benefits. Additionally, the Company incurred charges related to financial and legal advisors engaged to assist with the evaluation of a range of liability management alternatives. The Company expects to continue to incur charges related to liability management through the fourth quarter of 2020 and into 2021. The following table summarizes the costs incurred related to these for the three and nine months ended September 30, 2020. Three months ended September 30, 2020 Nine months ended September 30, 2020 (in thousands) Reduction in workforce $ 1,460 $ 1,460 Liability management 7,524 8,141 Total restructuring and liability management $ 8,984 $ 9,601

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS The Company records certain financial and non-financial assets and liabilities on the balance sheet at fair value. Fair value is the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. Market or observable inputs are the preferred sources of values, followed by assumptions based on hypothetical transactions in the absence of market inputs. Fair value measurements are classified and disclosed in one of the following categories: Level 1 – Quoted prices in active markets for identical assets and liabilities. Level 2 – Quoted prices in active markets for similar assets and liabilities, quoted prices for identical or similar instruments in markets that are not active and model-derived valuations whose inputs are observable or whose significant value drivers are observable. Level 3 – Significant inputs to the valuation model are unobservable. Valuation techniques that maximize the use of observable inputs are favored. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy. Reclassifications of fair value between Level 1, Level 2 and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. The following tables summarize the Company’s financial and non-financial assets and liabilities by valuation level as of September 30, 2020 and December 31, 2019: September 30, 2020 Level 1 Level 2 Level 3 (In thousands) Assets: Derivative Instruments $ — $ 7,343 $ — Liabilities: Derivative Instruments $ — $ 87,967 $ — December 31, 2019 Level 1 Level 2 Level 3 (In thousands) Assets: Derivative Instruments $ — $ 126,764 $ — Liabilities: Derivative Instruments $ — $ 53,438 $ — The Company estimates the fair value of all derivative instruments using industry-standard models that consider various assumptions, including current market and contractual prices for the underlying instruments, implied volatility, time value, nonperformance risk, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be supported by observable data. As discussed in Note 3 , the water infrastructure sale included a contingent consideration arrangement. As of September 30, 2020, the fair value of the contingent consideration was $19.7 million, of which $1.0 million is included in prepaid expenses and other assets and $18.7 million is included in other assets in the accompanying consolidated balance sheets. The fair value of the contingent consideration arrangement is calculated using discounted cash flow techniques and is based on internal estimates of the Company's future development program and water production levels. Given the unobservable nature of the inputs, the fair value measurement of the contingent consideration arrangement is deemed to use Level 3 inputs. The Company has elected the fair value option for this contingent consideration arrangement and, therefore, records changes in fair value in earnings. The Company recognized a loss of $0.2 million and $3.1 million on changes in fair value of the contingent consideration during the three and nine months ended September 30, 2020, respectively, which is included in other expense (income) in the accompanying consolidated statements of operations. Settlements under the contingent consideration arrangement totaled $0.3 million during the nine months ended September 30, 2020. The initial measurement of asset retirement obligations at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with oil and gas properties. Given the unobservable nature of the inputs, including plugging costs and reserve lives, the initial measurement of the asset retirement obligation liability is deemed to use Level 3 inputs. See Note 2 for further discussion of the Company’s asset retirement obligations. Asset retirement obligations incurred during the nine months ended September 30, 2020 were approximately $2.3 million. Fair value of financial instruments

REVENUE FROM CONTRACTS WITH CUS

REVENUE FROM CONTRACTS WITH CUSTOMERS	9 Months Ended
	Sep. 30, 2020
Revenue from Contract with Customer [Abstract]
REVENUE FROM CONTRACTS WITH CUSTOMERS	REVENUE FROM CONTRACTS WITH CUSTOMERS Revenue Recognition The Company’s revenues are primarily derived from the sale of natural gas, oil and condensate and NGL. Sales of natural gas, oil and condensate and NGL are recognized in the period that the performance obligations are satisfied. The Company generally considers the delivery of each unit (MMBtu or Bbl) to be separately identifiable and represents a distinct performance obligation that is satisfied at the time control of the product is transferred to the customer. Revenue is measured based on consideration specified in the contract with the customer, and excludes any amounts collected on behalf of third parties. These contracts typically include variable consideration that is based on pricing tied to market indices and volumes delivered in the current month. As such, this market pricing may be constrained (i.e., not estimable) at the inception of the contract but will be recognized based on the applicable market pricing, which will be known upon transfer of the goods to the customer. The payment date is usually within 30 days of the end of the calendar month in which the commodity is delivered. Gathering, processing and compression fees attributable to gas processing, as well as any transportation fees, including firm transportation fees, incurred to deliver the product to the purchaser, are presented as midstream, gathering and processing expense in the accompanying consolidated statements of operations. Transaction Price Allocated to Remaining Performance Obligations A significant number of the Company's product sales are short-term in nature generally through evergreen contracts with contract terms of one year or less. These contracts typically automatically renew under the same provisions. For those contracts, the Company has utilized the practical expedient allowed in the new revenue accounting standard that exempts the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For product sales that have a contract term greater than one year, the Company has utilized the practical expedient that exempts the Company from disclosure of the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. Currently, the Company's product sales that have a contractual term greater than one year have no long-term fixed consideration. Contract Balances Receivables from contracts with customers are recorded when the right to consideration becomes unconditional, generally when control of the product has been transferred to the customer. Receivables from contracts with customers were $92.4 million and $121.2 million as of September 30, 2020 and December 31, 2019, respectively, and are reported in accounts receivable - oil and natural gas sales on the consolidated balance sheets. The Company currently has no assets or liabilities related to its revenue contracts, including no upfront or rights to deficiency payments. Prior-Period Performance Obligations The Company records revenue in the month production is delivered to the purchaser. However, settlement statements for certain sales may be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product. The differences between the estimates and the actual amounts for product sales is recorded in the month that payment is received from the purchaser. For the nine months ended September 30, 2020, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.

LEASES

LEASES	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
LEASES	LEASES Nature of Leases The Company has operating leases associated with drilling rig commitments, field offices and other equipment with remaining lease terms with contractual durations in excess of one year. Short-term leases that have an initial term of one year or less are not capitalized. The Company has entered into a contract for a drilling rig with a third party to ensure rig availability. The Company has concluded its drilling rig contracts are operating leases as the assets are identifiable and the evaluation that the Company has the right to control the identified assets. The Company's drilling rig commitments are typically structured with an initial term of one Effective October 1, 2014, the Company entered into an Amended and Restated Master Services Agreement for pressure pumping services with Stingray, a subsidiary of Mammoth Energy and a related party. Pursuant to this agreement, as amended effective July 1, 2018, Stingray has agreed to provide hydraulic fracturing, stimulation and related completion and rework services to the Company through 2021 and the Company has agreed to pay Stingray a monthly service fee plus the associated costs of the services provided. As discussed further in Note 9 , the Company has terminated the Master Services Agreement for pressure pumping with Stingray. As a result, in the first quarter of 2020, Gulfport has removed the related right of use assets and lease liabilities associated with the terminated contract. The Company rents office space for its field locations and certain other equipment from third parties, which expire at various dates through 2024. These agreements are typically structured with non-cancelable terms of one Discount Rate As most of the Company's leases do not provide an implicit rate, the Company uses its incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. The Company's incremental borrowing rate reflects the estimated rate of interest that it would pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. Maturities of operating lease liabilities as of September 30, 2020 were as follows: (In thousands) Remaining 2020 $ 1,664 2021 142 2022 115 2023 90 2024 30 Total lease payments $ 2,041 Less: Imputed interest (29) Total $ 2,012 Lease cost for the three and nine months ended September 30, 2020 and 2019 consisted of the following: Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Operating lease cost $ 1,692 $ 4,551 $ 7,970 $ 20,835 Operating lease cost—related party — 5,610 — 16,830 Variable lease cost 245 105 705 1,065 Variable lease cost—related party — 5,357 — 64,968 Short-term lease cost 2,259 224 7,698 407 Total lease cost (1) $ 4,196 $ 15,847 $ 16,373 $ 104,105 (1) The majority of the Company's total lease cost was capitalized to the full cost pool, and the remainder was included in general and administrative expenses in the accompanying consolidated statements of operations. Supplemental cash flow information for the nine months ended September 30, 2020 and 2019 related to leases was as follows: Nine months ended September 30, 2020 2019 Cash paid for amounts included in the measurement of lease liabilities (In thousands) Operating cash flows from operating leases $ 109 $ 146 Investing cash flow from operating leases $ 9,786 $ 18,998 Investing cash flow from operating leases—related party $ 6,800 $ 78,518

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The Company records its quarterly tax provision based on an estimate of the annual effective tax rate expected to apply to continuing operations for the various jurisdictions in which it operates. The tax effects of certain items, such as tax rate changes, significant unusual or infrequent items, and certain changes in the assessment of the realizability of deferred taxes, are recognized as discrete items in the period in which they occur and are excluded from the estimated annual effective tax rate. For the three and nine months ended September 30, 2020, the Company's estimated annual effective tax rate before discrete items remained near zero as a result of the valuation allowance on its deferred tax assets. During the first quarter of 2020, the Company recognized $7.3 million of income tax expense discretely in the quarter as a result of the sale of assets and a corresponding adjustment to the valuation allowance on remaining state net operating loss carryforwards. The Company anticipates remaining in a net deferred tax asset position based on the analysis performed for three and nine months ended September 30, 2020. The Company expects a full valuation allowance against its deferred tax assets based on its conclusion, considering all available evidence (both positive and negative), that it was more likely than not that the deferred tax assets would not be realized. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax assets will not be realized. To assess that likelihood, the Company uses estimates and judgment regarding future taxable income, and considers the tax laws in the jurisdiction where such taxable income is generated, to determine whether a valuation allowance is required. Such evidence can include current financial position, results of operations, both actual and forecasted, the reversal of deferred tax liabilities and tax planning strategies as well as the current and forecasted business economics of the oil and gas industry. On March 27, 2020, the CARES Act was enacted in response to the COVID-19 pandemic. The Act includes several significant provisions for corporations including allowing companies to carryback certain NOLs, increasing the amount of NOLs that corporations can use to offset income, and increasing the amount of deductible interest under section 163(j). The Company does not expect to be materially impacted by the CARES Act provision and does not anticipate the CARES Act to have a material effect on its ability to realized deferred tax assets. The Company’s ability to utilize NOL carryforwards and other tax attributes to reduce future federal taxable income is subject to potential limitations under Internal Revenue Code Section 382 (“Section 382”) and its related tax regulations. The utilization of these attributes may be limited if certain ownership changes by 5% stockholders (as defined in Treasury regulations pursuant to Section 382) and the effects of stock issuances by the Company during any three-year period result in a cumulative change of more than 50% in the beneficial ownership of Gulfport. The Company updates its Section 382 analysis to determine if an ownership change has occurred at each reporting period. If it is determined that an ownership change has occurred under these rules, the Company would generally be subject to an annual limitation on the use of pre-ownership change NOL carryforwards and certain other losses and/or credits. In addition, certain future transactions regarding the Company's equity, including the cumulative effects of small transactions as well as transactions beyond the Company’s control, could cause an ownership change and therefore a potential limitation on the annual utilization of its deferred tax assets. On April 30, 2020, the board of directors of the Company adopted a tax benefits preservation plan in order to protect against a possible limitation on the Company’s ability to use its tax net operating losses and certain other tax benefits to reduce potential future U.S. federal income tax obligations. The Tax Benefits Preservation Plan is intended to prevent against such an ownership change by deterring any person or group from acquiring beneficial ownership of 4.9% or more of the Company’s securities.

CONDENSED CONSOLIDATING FINANCI

CONDENSED CONSOLIDATING FINANCIAL INFORMATION	9 Months Ended
	Sep. 30, 2020
Condensed Financial Information Disclosure [Abstract]
CONDENSED CONSOLIDATING FINANCIAL INFORMATION	CONDENSED CONSOLIDATING FINANCIAL INFORMATION The 2023 Notes, the 2024 Notes, the 2025 Notes and the 2026 Notes are guaranteed on a senior unsecured basis by all existing consolidated subsidiaries that guarantee the Company’s secured revolving credit facility or certain other debt (the “Guarantors”). The Notes are not guaranteed by Grizzly Holdings or Mule Sky LLC ("Mule Sky") (the “Non-Guarantors”). The Guarantors are 100% owned by Gulfport (the “Parent”), and the guarantees are full, unconditional, joint and several. There are no significant restrictions on the ability of the Parent or the Guarantors to obtain funds from each other in the form of a dividend or loan. Effective June 1, 2019, the Parent contributed interests in certain oil and gas assets and related liabilities to certain of the Guarantors. The following condensed consolidating balance sheets, statements of operations, statements of comprehensive income and statements of cash flows are provided for the Parent, the Guarantors and the Non-Guarantors and include the consolidating adjustments and eliminations necessary to arrive at the information for the Company on a condensed consolidated basis. The information has been presented using the equity method of accounting for the Parent’s ownership of the Guarantors and the Non-Guarantors. CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 43,774 $ 2,197 $ 5,072 $ — $ 51,043 Accounts receivable - oil and natural gas sales 861 91,582 — — 92,443 Accounts receivable - joint interest and other 428 14,993 — — 15,421 Accounts receivable - intercompany 332,011 73,885 — (405,896) — Prepaid expenses and other current assets 18,192 32,919 76 — 51,187 Short-term derivative instruments 6,245 — — — 6,245 Total current assets 401,511 215,576 5,148 (405,896) 216,339 Property and equipment: Oil and natural gas properties, full-cost accounting 1,248,836 9,531,593 6,606 (730) 10,786,305 Other property and equipment 92,551 51 3,319 — 95,921 Accumulated depletion, depreciation, amortization and impairment (1,425,619) (7,352,069) (2,016) — (8,779,704) Property and equipment, net (84,232) 2,179,575 7,909 (730) 2,102,522 Other assets: Equity investments and investments in subsidiaries 1,802,762 6,333 16,521 (1,809,056) 16,560 Long-term derivative instruments 1,098 — — — 1,098 Operating lease assets 2,012 — — — 2,012 Other assets 28,390 8,638 — — 37,028 Total other assets 1,834,262 14,971 16,521 (1,809,056) 56,698 Total assets $ 2,151,541 $ 2,410,122 $ 29,578 $ (2,215,682) $ 2,375,559 Liabilities and Stockholders ’ Equity Current liabilities: Accounts payable and accrued liabilities $ 59,543 $ 235,778 $ 38 $ — $ 295,359 Accounts payable - intercompany 74,733 321,373 9,789 (405,895) — Short-term derivative instruments 24,164 — — — 24,164 Current portion of operating lease liabilities 1,757 — — — 1,757 Current maturities of long-term debt 656 — — — 656 Total current liabilities 160,853 557,151 9,827 (405,895) 321,936 Long-term derivative instruments 63,803 — — — 63,803 Asset retirement obligation - long-term — 62,935 — — 62,935 Uncertain tax position liability 3,371 — — — 3,371 Non-current operating lease liabilities 255 — — — 255 Long-term debt, net of current maturities 2,068,036 — — — 2,068,036 Total liabilities 2,296,318 620,086 9,827 (405,895) 2,520,336 Stockholders’ equity: Common stock 1,607 — — — 1,607 Paid-in capital 4,212,241 4,291,981 267,560 (4,559,541) 4,212,241 Accumulated other comprehensive loss (51,329) 3 (48,902) 48,898 (51,330) Accumulated deficit (4,307,296) (2,501,948) (198,907) 2,700,856 (4,307,295) Total stockholders’ equity (144,777) 1,790,036 19,751 (1,809,787) (144,777) Total liabilities and stockholders ’ equity $ 2,151,541 $ 2,410,122 $ 29,578 $ (2,215,682) $ 2,375,559 CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) December 31, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 2,768 $ 3,097 $ 195 $ — $ 6,060 Accounts receivable - oil and natural gas sales 859 120,351 — — 121,210 Accounts receivable - joint interest and other 5,279 42,696 — — 47,975 Accounts receivable - intercompany 1,065,593 843,223 — (1,908,816) — Prepaid expenses and other current assets 4,047 308 76 — 4,431 Short-term derivative instruments 126,201 — — — 126,201 Total current assets 1,204,747 1,009,675 271 (1,908,816) 305,877 Property and equipment: Oil and natural gas properties, full-cost accounting, 1,314,933 9,273,681 7,850 (729) 10,595,735 Other property and equipment 92,650 50 4,019 — 96,719 Accumulated depletion, depreciation, amortization and impairment (1,418,888) (5,808,254) (1,518) — (7,228,660) Property and equipment, net (11,305) 3,465,477 10,351 (729) 3,463,794 Other assets: Equity investments and investments in subsidiaries 3,064,503 6,332 21,000 (3,059,791) 32,044 Long-term derivative instruments 563 — — — 563 Deferred tax asset 7,563 — — — 7,563 Operating lease assets 14,168 — — — 14,168 Operating lease assets - related parties 43,270 — — — 43,270 Other assets 10,026 5,514 — — 15,540 Total other assets 3,140,093 11,846 21,000 (3,059,791) 113,148 Total assets $ 4,333,535 $ 4,486,998 $ 31,622 $ (4,969,336) $ 3,882,819 Liabilities and Stockholders ’ Equity Current liabilities: Accounts payable and accrued liabilities $ 48,006 $ 367,088 $ 124 $ — $ 415,218 Accounts payable - intercompany 878,283 1,026,249 4,285 (1,908,817) — Short-term derivative instruments 303 — — — 303 Current portion of operating lease liabilities 13,826 — — — 13,826 Current portion of operating lease liabilities - related parties 21,220 — — — 21,220 Current maturities of long-term debt 631 — — — 631 Total current liabilities 962,269 1,393,337 4,409 (1,908,817) 451,198 Long-term derivative instruments 53,135 — — — 53,135 Asset retirement obligation - long-term — 58,322 2,033 — 60,355 Uncertain tax position liability 3,127 — — — 3,127 Non-current operating lease liabilities 342 — — — 342 Non-current operating lease liabilities - related parties 22,050 — — — 22,050 Long-term debt, net of current maturities 1,978,020 — — — 1,978,020 Total liabilities 3,018,943 1,451,659 6,442 (1,908,817) 2,568,227 Stockholders’ equity: Common stock 1,597 — — — 1,597 Paid-in capital 4,207,554 4,171,408 267,557 (4,438,965) 4,207,554 Accumulated other comprehensive loss (46,833) — (44,763) 44,763 (46,833) Accumulated deficit (2,847,726) (1,136,069) (197,614) 1,333,683 (2,847,726) Total stockholders’ equity 1,314,592 3,035,339 25,180 (3,060,519) 1,314,592 Total liabilities and stockholders ’ equity $ 4,333,535 $ 4,486,998 $ 31,622 $ (4,969,336) $ 3,882,819 CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Total revenues $ (53,823) $ 189,999 $ — $ — $ 136,176 Costs and expenses: Lease operating expenses (157) 15,431 — — 15,274 Production taxes — 4,028 — — 4,028 Midstream gathering and processing expenses — 110,567 — — 110,567 Depreciation, depletion and amortization 2,265 49,120 166 — 51,551 Impairment of oil and natural gas properties — 270,874 — — 270,874 General and administrative expenses 29,454 (9,098) 168 — 20,524 Restructuring and liability management 8,984 — — — 8,984 Accretion expense — 774 — — 774 Total Operating Expenses 40,546 441,696 334 — 482,576 LOSS FROM OPERATIONS (94,369) (251,697) (334) — (346,400) OTHER EXPENSE (INCOME): Interest expense 34,488 (167) — — 34,321 Interest income (16) (36) — — (52) Loss from equity method investments and investments in subsidiaries 251,951 — 153 (251,951) 153 Other expense (income) 172 (31) — — 141 Total Other Expense (Income) 286,595 (234) 153 (251,951) 34,563 LOSS BEFORE INCOME TAXES (380,964) (251,463) (487) 251,951 (380,963) INCOME TAX EXPENSE — — — — — NET LOSS $ (380,964) $ (251,463) $ (487) $ 251,951 $ (380,963) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 27,358 $ 314,388 $ — $ — $ 341,746 Costs and expenses: Lease operating expenses (231) 22,704 — — 22,473 Production taxes 36 6,529 — — 6,565 Midstream gathering and processing expenses — 135,006 — — 135,006 Depreciation, depletion and amortization 2,686 160,418 166 — 163,270 Impairment of oil and natural gas properties — 571,442 — — 571,442 General and administrative expenses 25,757 (12,675) 116 — 13,198 Accretion expense — 747 — — 747 Total Operating Expenses 28,248 884,171 282 — 912,701 LOSS FROM OPERATIONS (890) (569,783) (282) — (570,955) OTHER EXPENSE (INCOME): Interest expense 36,566 (1,010) — — 35,556 Interest income (187) (151) — — (338) Gain on debt extinguishment (23,600) — — — (23,600) Loss from equity method investments and investments in subsidiaries 616,348 — 40 (573,306) 43,082 Other (income) expense (1,168) 3,362 — 1,000 3,194 Total Other Expense 627,959 2,201 40 (572,306) 57,894 LOSS BEFORE INCOME TAXES (628,849) (571,984) (322) 572,306 (628,849) INCOME TAX BENEFIT (144,047) — — — (144,047) NET LOSS $ (484,802) $ (571,984) $ (322) $ 572,306 $ (484,802) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Nine months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Total revenues $ 71,415 $ 550,400 $ — $ — $ 621,815 Costs and expenses: Lease operating expenses (157) 47,103 — — 46,946 Production taxes — 12,432 — — 12,432 Midstream gathering and processing expenses — 334,789 — — 334,789 Depreciation, depletion, and amortization 7,155 186,716 498 — 194,369 Impairment of oil and gas properties — 1,357,099 — — 1,357,099 General and administrative expenses 75,214 (29,122) 454 — 46,546 Restructuring and liability management 9,601 — — — 9,601 Accretion expense — 2,270 — — 2,270 Total Operating Expenses 91,813 1,911,287 952 — 2,004,052 LOSS FROM OPERATIONS (20,398) (1,360,887) (952) — (1,382,237) OTHER EXPENSE (INCOME): Interest expense 100,490 (813) — — 99,677 Interest income (103) (179) — — (282) Gain on debt extinguishment (49,579) — — — (49,579) Loss from equity method investments and investments in subsidiaries 1,377,819 — 341 (1,367,173) 10,987 Other expense 3,255 5,984 — — 9,239 Total Other Expense 1,431,882 4,992 341 (1,367,173) 70,042 LOSS BEFORE INCOME TAXES (1,452,280) (1,365,879) (1,293) 1,367,173 (1,452,279) INCOME TAX EXPENSE 7,290 — — — 7,290 NET LOSS $ (1,459,570) $ (1,365,879) $ (1,293) $ 1,367,173 $ (1,459,569) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Nine months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 493,895 $ 732,763 $ — $ — $ 1,226,658 Costs and expenses: Lease operating expenses 26,918 37,750 — — 64,668 Production taxes 6,117 16,467 — — 22,584 Midstream gathering and processing expenses 71,420 311,223 — — 382,643 Depreciation, depletion, and amortization 201,250 205,183 221 — 406,654 Impairment of oil and natural gas properties — 571,442 — — 571,442 General and administrative expenses 51,695 (16,933) 220 — 34,982 Accretion expense 1,389 1,784 — — 3,173 Total Operating Expenses 358,789 1,126,916 441 — 1,486,146 INCOME (LOSS) FROM OPERATIONS 135,106 (394,153) (441) — (259,488) OTHER EXPENSE (INCOME): Interest expense 109,864 (2,269) — — 107,595 Interest income (454) (195) — — (649) Gain on debt extinguishment (23,600) — — — (23,600) Loss from equity method investments and investments in subsidiaries 560,883 — 379 (396,871) 164,391 Other (income) expense (605) 3,362 — 1,000 3,757 Total Other Expense 646,088 898 379 (395,871) 251,494 LOSS BEFORE INCOME TAXES (510,982) (395,051) (820) 395,871 (510,982) INCOME TAX BENEFIT (323,378) — — — (323,378) NET LOSS $ (187,604) $ (395,051) $ (820) $ 395,871 $ (187,604) Three months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Net loss $ (380,964) $ (251,463) $ (487) $ 251,951 $ (380,963) Foreign currency translation adjustment 3,661 — 3,661 (3,661) 3,661 Other comprehensive loss 3,661 — 3,661 (3,661) 3,661 Comprehensive loss $ (377,303) $ (251,463) $ 3,174 $ 248,290 $ (377,302) Three months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Net loss $ (484,802) $ (571,984) $ (322) $ 572,306 $ (484,802) Foreign currency translation adjustment (2,064) (43) (2,021) 2,064 (2,064) Other comprehensive income (2,064) (43) (2,021) 2,064 (2,064) Comprehensive loss $ (486,866) $ (572,027) $ (2,343) $ 574,370 $ (486,866) Nine months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Net loss $ (1,459,570) $ (1,365,879) $ (1,293) $ 1,367,173 $ (1,459,569) Foreign currency translation adjustment (4,497) (360) (4,137) 4,497 (4,497) Other comprehensive loss (4,497) (360) (4,137) 4,497 (4,497) Comprehensive loss $ (1,464,067) $ (1,366,239) $ (5,430) $ 1,371,670 $ (1,464,066) Nine months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Net loss $ (187,604) $ (395,051) $ (820) $ 395,871 $ (187,604) Foreign currency translation adjustment 5,347 112 5,235 (5,347) 5,347 Other comprehensive income 5,347 112 5,235 (5,347) 5,347 Comprehensive (loss) income $ (182,257) $ (394,939) $ 4,415 $ 390,524 $ (182,257) CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS (Amounts in thousands) Nine months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ (95,023) $ 290,147 $ 4,442 $ 435 $ 200,001 Net cash used in investing activities 351 (291,047) — — (290,696) Net cash (used in) provided by financing activities 135,678 — 435 (435) 135,678 Net (decrease) increase in cash, cash equivalents and restricted cash 41,006 (900) 4,877 — 44,983 Cash, cash equivalents and restricted cash at beginning of period 2,768 3,097 195 — 6,060 Cash, cash equivalents and restricted cash at end of period $ 43,774 $ 2,197 $ 5,072 $ — $ 51,043 Nine months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Net cash (used in) provided by operating activities $ (7,604) $ 621,511 $ 3,445 $ 3 $ 617,355 Net cash provided by (used in) investing activities 9,178 (644,507) (3,751) 432 (638,648) Net cash (used in) provided by financing activities (20,880) — 435 (435) (20,880) Net (decrease) increase in cash, cash equivalents and restricted cash (19,306) (22,996) 129 — (42,173) Cash, cash equivalents and restricted cash at beginning of period 25,585 26,711 1 — 52,297 Cash, cash equivalents and restricted cash at end of period $ 6,279 $ 3,715 $ 130 $ — $ 10,124

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2020
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS The Company elected not to make an interest payment of $17.4 million due October 15, 2020 on the 2024 Notes. The Company elected not to make an interest payment of $10.8 million due November 2, 2020 on the 2023 Notes. The elections to defer the interest payments do not constitute an “Event of Default” as defined under the Indentures if the interest payments are made within 30 days of the due date. If the Company does not make such interest payments within the 30-day period, there will be an event of default under the Indentures upon expiration of the grace period and there can be no assurance that it will have sufficient funds to pay such interest payments prior to such time. Additionally, on October 15, 2020, the Company entered into the First Forbearance Agreement. Pursuant to the First Forbearance Agreement, the lender parties have agreed to (i) temporarily waive any default in connection with the non-payment of interest on the 2024 Notes within 30 days of becoming due prior to its occurrence without any further action and (ii) forbear from exercising certain of their default-related rights and remedies against the Company and the other loan parties with respect to any default in connection with the Specified Default, in each case, until the earlier of October 29, 2020 or another event that would trigger the end of the forbearance period. On October 26, 2020, the Company entered into the Second Forbearance Agreement, which extends the First Forbearance Agreement. Pursuant to the Second Forbearance Agreement, the lender parties have agreed to (i) temporarily waive any default in connection with the Specified Default prior to its occurrence without any further action, (ii) expand the definition of "Specified Default" to include the failure to make the interest payment on the 2023 Notes within 30 days of becoming due and (iii) extend the agreement to forbear from exercising certain of their default-related rights and remedies against the Company and the other loan parties with respect to any default in connection with the Specified Default, in each case, until the earlier of November 13, 2020 or another event that would trigger the end of the forbearance period. Moreover, the Company's existing revolving credit facility matures in December 2021 and therefore will become a current liability at year end 2020 unless the Company is able to refinance the credit facility with a new credit facility or other financing. Considering the current state of the first lien market and the Company's elevated leverage profile, there is substantial risk that a refinancing will not be available to the Company on reasonable terms. A current liability under the revolving credit facility at year end 2020 may result in a qualified audit opinion which could result in a default under the terms of the current revolving credit facility. Failure to meet the Company's obligations under its existing indebtedness or failure to comply with any of its covenants, if not waived, would result in an event of default under such indebtedness and result in the potential acceleration of outstanding indebtedness thereunder and, with respect to the revolving credit facility, the potential foreclosure on the collateral securing such debt, and could cause a cross-default under its other outstanding indebtedness. As a result of these uncertainties and other factors, management has concluded that there is substantial doubt about the Company's ability to continue as a going concern over the next twelve months from the issuance of these financial statements. The Company has engaged financial and legal advisors to assist with the evaluation of a range of liability management alternatives. Additionally, the Company maintains an active dialogue with its senior lenders and bondholders regarding liability management alternatives to improve its balance sheet. There can be no assurances that the Company will be able to successfully complete a liability management transaction that materially improves the Company’s leverage profile or liquidity position. The consolidated financial statements (i) have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities and other commitments in the normal course of business and (ii) do not include any adjustments to reflect the possible future effects of the uncertainty on the recoverability or classification of recorded asset amounts or the amounts or classifications of liabilities.

BASIS OF PRESENTATION, SUMMAR_2

BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN (Policies)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying unaudited consolidated financial statements have been prepared by Gulfport Energy Corporation (the “Company” or “Gulfport”) pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”), and reflect all adjustments that, in the opinion of management, are necessary for a fair presentation of the results for the interim periods reported in all material respects, on a basis consistent with the annual audited consolidated financial statements. All such adjustments are of a normal, recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles ("GAAP") have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading.
Recently Adopted Accounting Standards	Recently Adopted Accounting Standards On January 1, 2020, the Company adopted ASU No. 2016-13, Financial Instruments-Credit Losses: Measurement of Credit Losses on Financial Instruments , which replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions and reasonable and supportable forecasts that affect the collectability of the reported amount. The Company adopted the new standard using the prospective transition method, and it did not have a material impact on the Company's consolidated financial statements and related disclosures.

BASIS OF PRESENTATION, SUMMAR_3

BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN (Tables)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Schedule of Error Corrections and Prior Period Adjustments	The following tables present the effect of the correction on all affected line items of our previously issued consolidated financial statements of operations for the three and nine months ended September 30, 2019. Three months ended September 30, 2019 As Reported Adjustments As Revised (In thousands) Natural gas sales $ 213,227 $ 56,571 $ 269,798 Total Revenues $ 285,175 $ 56,571 $ 341,746 Midstream gathering and processing expenses $ 78,435 $ 56,571 $ 135,006 Total Operating Expenses (1) $ 856,130 $ 56,571 $ 912,701 Nine months ended September 30, 2019 As Reported Adjustments As Revised (In thousands) Natural gas sales $ 714,500 $ 161,911 $ 876,411 Total Revenues $ 1,064,747 $ 161,911 $ 1,226,658 Midstream gathering and processing expenses $ 220,732 $ 161,911 $ 382,643 Total Operating Expenses (1) $ 1,324,235 $ 161,911 $ 1,486,146 (1) Reflects additional immaterial presentation change made in the fourth quarter of 2019.

PROPERTY AND EQUIPMENT (Tables)

PROPERTY AND EQUIPMENT (Tables)	9 Months Ended
	Sep. 30, 2020
Property, Plant and Equipment [Abstract]
Schedule of Property and Equipment	The major categories of property and equipment and related accumulated depletion, depreciation, amortization ("DD&A") and impairment as of September 30, 2020 and December 31, 2019 are as follows: September 30, 2020 December 31, 2019 (In thousands) Oil and natural gas properties $ 10,786,305 $ 10,595,735 Accumulated DD&A and impairment (8,735,750) (7,191,957) Oil and natural gas properties, net 2,050,555 3,403,778 Other depreciable property and equipment 91,101 91,198 Land 4,820 5,521 Accumulated DD&A (43,954) (36,703) Other property and equipment, net 51,967 60,016 Property and equipment, net $ 2,102,522 $ 3,463,794
Schedule of Non-Producing Properties Excluded from Amortization by Area	The following table summarizes the Company’s unevaluated properties excluded from amortization by area at September 30, 2020: September 30, 2020 (In thousands) Utica $ 850,643 SCOOP 674,280 Other 2,018 $ 1,526,941
Schedule of Asset Retirement Obligation	A reconciliation of the Company’s asset retirement obligation for the nine months ended September 30, 2020 and 2019 is as follows: September 30, 2020 September 30, 2019 (In thousands) Asset retirement obligation, beginning of period $ 60,355 $ 79,952 Liabilities incurred 2,343 5,769 Liabilities settled — (117) Liabilities removed due to divestitures (2,033) (30,035) Accretion expense 2,270 3,173 Revisions in estimated cash flows — 1,077 Asset retirement obligation as of end of period $ 62,935 $ 59,819

EQUITY INVESTMENTS (Tables)

EQUITY INVESTMENTS (Tables)	9 Months Ended
	Sep. 30, 2020
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Investments accounted for by the equity method consist of the following as of September 30, 2020 and December 31, 2019: Carrying value (Loss) income from equity method investments Approximate ownership % September 30, 2020 December 31, 2019 Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Investment in Grizzly Oil Sands ULC 24.6 % $ 16,521 $ 21,000 $ (153) $ (41) $ (341) $ (380) Investment in Mammoth Energy Services, Inc. 21.5 % — 11,005 — (43,041) (10,646) (166,096) Investment in Windsor Midstream LLC 22.5 % 39 39 — — — Investment in Tatex Thailand II, LLC 23.5 % — — — — — 2,085 $ 16,560 $ 32,044 $ (153) $ (43,082) $ (10,987) $ (164,391)
Schedule of Equity Investments - Balance Sheet	The tables below summarize financial information for the Company’s equity investments as of September 30, 2020 and December 31, 2019. Summarized balance sheet information: September 30, 2020 December 31, 2019 (In thousands) Current assets $ 463,853 $ 421,326 Noncurrent assets $ 1,086,150 $ 1,260,075 Current liabilities $ 115,976 $ 132,569 Noncurrent liabilities $ 161,183 $ 163,241
Schedule of Equity Investments - Income Statement	Summarized results of operations: Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Gross revenue $ 70,534 $ 113,417 $ 228,026 $ 557,375 Net (loss) income $ 2,808 $ (35,730) $ (97,145) $ (15,046)

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	9 Months Ended
	Sep. 30, 2020
Long-term Debt, Unclassified [Abstract]
Schedule of Long-Term Debt	Long-term debt consisted of the following items as of September 30, 2020 and December 31, 2019: September 30, 2020 December 31, 2019 (In thousands) Revolving credit agreement (1) $ 279,857 $ 120,000 6.625% senior unsecured notes due 2023 324,583 329,467 6.000% senior unsecured notes due 2024 579,568 603,428 6.375% senior unsecured notes due 2025 507,870 529,525 6.375% senior unsecured notes due 2026 374,617 397,529 Net unamortized debt issuance costs (2) (19,772) (23,751) Construction loan 21,969 22,453 Less: current maturities of long term debt (656) (631) Debt reflected as long term $ 2,068,036 $ 1,978,020 (1) The Company has entered into a senior secured revolving credit facility, as amended (the "revolving credit facility"), with The Bank of Nova Scotia, as the lead arranger and administrative agent and other lenders. The credit agreement provides for a maximum facility of $1.5 billion and matures on December 13, 2021. On May 1, 2020, the Company entered into the fifteenth amendment to the Amended and Restated Credit Agreement. As part of the amendment, the Company's borrowing base and elected commitment were reduced from $1.2 billion and $1.0 billion, respectively, to $700.0 million. Additionally, the amendment added a requirement to maintain a ratio of Net Secured Debt to EBITDAX (as defined under the revolving credit agreement) not exceeding 2.00 to 1.00, deferred the requirement to maintain a ratio of Net Funded Debt to EBITDAX of 4.00 to 1.00 until September 30, 2021, and added a limitation on the repurchase of unsecured notes, among other amendments. On July 27, 2020, the Company entered into the sixteenth amendment to the Amended and Restated Credit Agreement. Among other changes, the Sixteenth Amendment amends the Credit Agreement to: (i) require that, in the event of any issuances of Senior Notes, including Second Lien Notes, after the effective date, the then effective borrowing base will be reduced by a variable amount prescribed in the Credit Agreement to the extent the proceeds are not used to satisfy previously issued senior notes within 90 days of such issuance; (ii) require that each Loan Notice specify the amount of the then effective Borrowing Base and Pro Forma Borrowing Base, the Aggregate Elected Commitment Amount, and the current Total Outstandings, both with and without regard to the requested Borrowing; (iii) permit the Borrower or any Restricted Subsidiary to enter into obligations in connection with a Permitted Bond Hedge Transaction or Permitted Warrant Transaction; (iv) permit the Borrower to make any payments of Senior Notes and Subordinated Obligation prior to their scheduled maturity, in any event not to exceed $750 million or, if lesser, the net cash proceeds of any Senior Notes issued within 90 days before such payment; (v) require that the Senior Notes have a stated maturity date of no earlier than March 13, 2024, as well as not require payment of principal prior to such date, in order for the Borrower to be permitted to secure indebtedness under the Senior Notes; (vi) permit certain additional liens securing obligations in respect of the incurrence or issuance of any Permitted Refinancing Notes (as such term is defined in the Credit Agreement) not to exceed $750 million, subject to the terms of an intercreditor agreement; and (vii) amend and restate the Applicable Rate Grid. As of September 30, 2020, $279.9 million was outstanding under the revolving credit facility and the total availability for future borrowings under this facility, after giving effect to an aggregate of $320.0 million letters of credit, was $100.1 million. The Company’s wholly owned subsidiaries have guaranteed the obligations of the Company under the revolving credit facility. At September 30, 2020, amounts borrowed under the revolving credit facility bore interest at a weighted average rate of 2.90%. The Company was in compliance with its financial covenants under the revolving credit facility at September 30, 2020. (2) Loan issuance costs related to the 2023 Notes, the 2024 Notes, the 6.375% Senior Notes due 2025 (the "2025 Notes") and the 6.375% Senior Notes due 2026 (the "2026 Notes") (collectively the “Notes”) have been presented as a reduction to the principal amount of the Notes. At September 30, 2020, total unamortized debt issuance costs were $2.6 million for the 2023 Notes, $5.7 million for the 2024 Notes, $8.1 million for the 2025 Notes and $3.3 million for the 2026 Notes. In addition, loan commitment fee costs for the Company's construction loan agreement were $0.1 million at September 30, 2020.

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	9 Months Ended
	Sep. 30, 2020
Share-based Payment Arrangement, Noncash Expense [Abstract]
Schedule of Restricted Stock Activity	The following table summarizes restricted stock unit activity for the nine months ended September 30, 2020: Number of Weighted Number of Weighted Unvested shares as of January 1, 2020 4,098,318 $ 4.73 1,783,660 $ 2.96 Granted 3,069,521 0.85 — — Vested (1,294,285) 5.73 — — Forfeited/canceled (4,166,493) 1.67 (943,065) 1.98 Unvested shares as of September 30, 2020 1,707,061 $ 4.73 840,595 $ 4.07

EARNINGS (LOSS) PER SHARE (Tabl

EARNINGS (LOSS) PER SHARE (Tables)	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
Schedule of Earnings Per Share	Reconciliations of the components of basic and diluted net income per common share are presented in the tables below: Three months ended September 30, 2020 2019 Loss Shares Per Loss Shares Per (In thousands, except share data) Basic: Net loss $ (380,963) 160,682,629 $ (2.37) $ (484,802) 159,548,477 $ (3.04) Effect of dilutive securities: Stock awards — — — — Diluted: Net loss $ (380,963) 160,682,629 $ (2.37) $ (484,802) 159,548,477 $ (3.04) Nine months ended September 30, 2020 2019 Loss Shares Per Loss Shares Per (In thousands, except share data) Basic: Net loss $ (1,459,569) 160,053,093 $ (9.12) $ (187,604) 160,553,796 $ (1.17) Effect of dilutive securities: Stock options and awards — — — — Diluted: Net loss $ (1,459,569) 160,053,093 $ (9.12) $ (187,604) 160,553,796 $ (1.17)

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	9 Months Ended
	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Schedule of Firm Transportation Commitments	A summary of these commitments at September 30, 2020 are set forth in the table below: (MMBtu per day) Remaining 2020 286,000 2021 183,000 2022 70,000 2023 17,000 Total 556,000
Schedule of Other Commitments	A summary of these commitments at September 30, 2020 are set forth in the table below: Total MMBtu (In thousands) Remaining 2020 126,960,000 $ 67,458 2021 510,575,000 278,805 2022 535,414,000 288,135 2023 520,114,000 284,454 2024 493,841,000 267,077 Thereafter 3,791,093,000 2,220,685 Total 5,977,997,000 $ 3,406,614 Future minimum commitments under this agreement at September 30, 2020 are: (In thousands) Remaining 2020 $ 1,875 2021 7,500 Total $ 9,375

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2020
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Schedule of Open Fixed Price Swap Positions and Natural Gas Basis Swap Positions	Below is a summary of the Company’s open fixed price swap positions as of September 30, 2020. Location Daily Volume Weighted Remaining 2020 NYMEX Henry Hub 500,000 $ 2.69 Location Daily Volume Weighted Remaining 2020 NYMEX WTI 3,000 $ 35.49 Location Daily Volume Weighted Remaining 2020 Mont Belvieu C3 1,500 $ 20.27 The Company sold call options in exchange for a premium, and used the associated premiums to enhance the fixed price for a portion of the fixed price natural gas swaps primarily for 2020 listed above. Each call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volumes. Location Daily Volume Weighted Average Price 2022 NYMEX Henry Hub 628,000 $ 2.90 2023 NYMEX Henry Hub 628,000 $ 2.90 Location Daily Volume (MMBtu/day) Weighted Average Floor Price Weighted Average Ceiling Price 2021 NYMEX Henry Hub 250,000 $ 2.46 $ 2.81 Gulfport Pays Gulfport Receives Daily Volume Weighted Average Fixed Spread Remaining 2020 Transco Zone 4 NYMEX Plus Fixed Spread 60,000 $ (0.05) Remaining 2020 Fixed Spread ONEOK Minus NYMEX 10,000 $ (0.54)
Schedule of Purchase and Sale Agreement for Sale of the Company's Non-Core Assets	See below for threshold and potential payment amounts. Period Threshold (1) Payment to be received (2) July 2020 - June 2021 Greater than or equal to $60.65 $ 150,000 Between $52.62 - $60.65 Calculated Value (3) Less than or equal to $52.62 $ — (1) Based on the "WTI NYMEX + Argus LLS Differential," as published by Argus Media. (2) Payment will be assessed monthly from July 2020 through June 2021. If threshold is met, payment shall be received within five business days after the end of each calendar month. (3) If average daily price, as defined in (1), is greater than $52.62 but less than $60.65, payment received will be $150,000 multiplied by a fraction, the numerator of which is the amount determined by subtracting $52.62 from such average daily price, and the denominator of which is $8.03.
Schedule of Derivative Instruments in Balance Sheet	The following table presents the fair value of the Company’s derivative instruments on a gross basis at September 30, 2020 and December 31, 2019: September 30, 2020 December 31, 2019 (In thousands) Commodity Contracts: Short-term derivative asset $ 6,245 $ 125,383 Long-term derivative asset 1,098 — Short-term derivative liability (24,164) (303) Long-term derivative liability (63,803) (53,135) Total commodity derivative position $ (80,624) $ 71,945 Contingent consideration arrangement: Short-term derivative asset $ — $ 818 Long-term derivative asset — 563 Total contingent consideration derivative position $ — $ 1,381 Total net (liability) asset derivative position $ (80,624) $ 73,326
Schedule of Net Gain (Loss) on Derivatives	The following table presents the gain and loss recognized in net gain on natural gas, oil and NGL derivatives in the accompanying consolidated statements of operations for the three and nine months ended September 30, 2020 and 2019. Net (loss) gain on derivative instruments Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Natural gas derivatives $ (52,648) $ 11,731 $ 28,894 $ 147,774 Oil derivatives (782) 12,736 44,155 24,153 NGL derivatives (393) 3,641 (254) 7,276 Contingent consideration arrangement — (1,034) (1,381) (1,034) Total $ (53,823) $ 27,074 $ 71,414 $ 178,169
Schedule of Recognized Derivative Assets	The following table presents the gross amounts of recognized derivative assets and liabilities in the consolidated balance sheets and the amounts that are subject to offsetting under master netting arrangements with counterparties, all at fair value. As of September 30, 2020 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount (In thousands) Derivative assets $ 7,343 $ (6,948) $ 395 Derivative liabilities $ (87,967) $ 6,948 $ (81,019) As of December 31, 2019 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount (In thousands) Derivative assets $ 126,764 $ (53,438) $ 73,326 Derivative liabilities $ (53,438) $ 53,438 $ —
Schedule of Recognized Derivative Liabilities	The following table presents the gross amounts of recognized derivative assets and liabilities in the consolidated balance sheets and the amounts that are subject to offsetting under master netting arrangements with counterparties, all at fair value. As of September 30, 2020 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount (In thousands) Derivative assets $ 7,343 $ (6,948) $ 395 Derivative liabilities $ (87,967) $ 6,948 $ (81,019) As of December 31, 2019 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount (In thousands) Derivative assets $ 126,764 $ (53,438) $ 73,326 Derivative liabilities $ (53,438) $ 53,438 $ —

RESTRUCTURING AND LIABILITY M_2

RESTRUCTURING AND LIABILITY MANAGEMENT (Tables)	9 Months Ended
	Sep. 30, 2020
Restructuring and Related Activities [Abstract]
Summary of Cost Incurred	The following table summarizes the costs incurred related to these for the three and nine months ended September 30, 2020. Three months ended September 30, 2020 Nine months ended September 30, 2020 (in thousands) Reduction in workforce $ 1,460 $ 1,460 Liability management 7,524 8,141 Total restructuring and liability management $ 8,984 $ 9,601

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Schedule of Financial and Non-Financial Assets and Liabilities by Valuation Level	The following tables summarize the Company’s financial and non-financial assets and liabilities by valuation level as of September 30, 2020 and December 31, 2019: September 30, 2020 Level 1 Level 2 Level 3 (In thousands) Assets: Derivative Instruments $ — $ 7,343 $ — Liabilities: Derivative Instruments $ — $ 87,967 $ — December 31, 2019 Level 1 Level 2 Level 3 (In thousands) Assets: Derivative Instruments $ — $ 126,764 $ — Liabilities: Derivative Instruments $ — $ 53,438 $ —

LEASES (Tables)

LEASES (Tables)	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Schedule of Operating Lease Liability	Maturities of operating lease liabilities as of September 30, 2020 were as follows: (In thousands) Remaining 2020 $ 1,664 2021 142 2022 115 2023 90 2024 30 Total lease payments $ 2,041 Less: Imputed interest (29) Total $ 2,012
Schedule of Lease Cost	Lease cost for the three and nine months ended September 30, 2020 and 2019 consisted of the following: Three months ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Operating lease cost $ 1,692 $ 4,551 $ 7,970 $ 20,835 Operating lease cost—related party — 5,610 — 16,830 Variable lease cost 245 105 705 1,065 Variable lease cost—related party — 5,357 — 64,968 Short-term lease cost 2,259 224 7,698 407 Total lease cost (1) $ 4,196 $ 15,847 $ 16,373 $ 104,105 (1) The majority of the Company's total lease cost was capitalized to the full cost pool, and the remainder was included in general and administrative expenses in the accompanying consolidated statements of operations. Supplemental cash flow information for the nine months ended September 30, 2020 and 2019 related to leases was as follows: Nine months ended September 30, 2020 2019 Cash paid for amounts included in the measurement of lease liabilities (In thousands) Operating cash flows from operating leases $ 109 $ 146 Investing cash flow from operating leases $ 9,786 $ 18,998 Investing cash flow from operating leases—related party $ 6,800 $ 78,518

CONDENSED CONSOLIDATING FINAN_2

CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2020
Condensed Financial Information Disclosure [Abstract]
CONDENSED CONSOLIDATING BALANCE SHEETS	CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 43,774 $ 2,197 $ 5,072 $ — $ 51,043 Accounts receivable - oil and natural gas sales 861 91,582 — — 92,443 Accounts receivable - joint interest and other 428 14,993 — — 15,421 Accounts receivable - intercompany 332,011 73,885 — (405,896) — Prepaid expenses and other current assets 18,192 32,919 76 — 51,187 Short-term derivative instruments 6,245 — — — 6,245 Total current assets 401,511 215,576 5,148 (405,896) 216,339 Property and equipment: Oil and natural gas properties, full-cost accounting 1,248,836 9,531,593 6,606 (730) 10,786,305 Other property and equipment 92,551 51 3,319 — 95,921 Accumulated depletion, depreciation, amortization and impairment (1,425,619) (7,352,069) (2,016) — (8,779,704) Property and equipment, net (84,232) 2,179,575 7,909 (730) 2,102,522 Other assets: Equity investments and investments in subsidiaries 1,802,762 6,333 16,521 (1,809,056) 16,560 Long-term derivative instruments 1,098 — — — 1,098 Operating lease assets 2,012 — — — 2,012 Other assets 28,390 8,638 — — 37,028 Total other assets 1,834,262 14,971 16,521 (1,809,056) 56,698 Total assets $ 2,151,541 $ 2,410,122 $ 29,578 $ (2,215,682) $ 2,375,559 Liabilities and Stockholders ’ Equity Current liabilities: Accounts payable and accrued liabilities $ 59,543 $ 235,778 $ 38 $ — $ 295,359 Accounts payable - intercompany 74,733 321,373 9,789 (405,895) — Short-term derivative instruments 24,164 — — — 24,164 Current portion of operating lease liabilities 1,757 — — — 1,757 Current maturities of long-term debt 656 — — — 656 Total current liabilities 160,853 557,151 9,827 (405,895) 321,936 Long-term derivative instruments 63,803 — — — 63,803 Asset retirement obligation - long-term — 62,935 — — 62,935 Uncertain tax position liability 3,371 — — — 3,371 Non-current operating lease liabilities 255 — — — 255 Long-term debt, net of current maturities 2,068,036 — — — 2,068,036 Total liabilities 2,296,318 620,086 9,827 (405,895) 2,520,336 Stockholders’ equity: Common stock 1,607 — — — 1,607 Paid-in capital 4,212,241 4,291,981 267,560 (4,559,541) 4,212,241 Accumulated other comprehensive loss (51,329) 3 (48,902) 48,898 (51,330) Accumulated deficit (4,307,296) (2,501,948) (198,907) 2,700,856 (4,307,295) Total stockholders’ equity (144,777) 1,790,036 19,751 (1,809,787) (144,777) Total liabilities and stockholders ’ equity $ 2,151,541 $ 2,410,122 $ 29,578 $ (2,215,682) $ 2,375,559 CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) December 31, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 2,768 $ 3,097 $ 195 $ — $ 6,060 Accounts receivable - oil and natural gas sales 859 120,351 — — 121,210 Accounts receivable - joint interest and other 5,279 42,696 — — 47,975 Accounts receivable - intercompany 1,065,593 843,223 — (1,908,816) — Prepaid expenses and other current assets 4,047 308 76 — 4,431 Short-term derivative instruments 126,201 — — — 126,201 Total current assets 1,204,747 1,009,675 271 (1,908,816) 305,877 Property and equipment: Oil and natural gas properties, full-cost accounting, 1,314,933 9,273,681 7,850 (729) 10,595,735 Other property and equipment 92,650 50 4,019 — 96,719 Accumulated depletion, depreciation, amortization and impairment (1,418,888) (5,808,254) (1,518) — (7,228,660) Property and equipment, net (11,305) 3,465,477 10,351 (729) 3,463,794 Other assets: Equity investments and investments in subsidiaries 3,064,503 6,332 21,000 (3,059,791) 32,044 Long-term derivative instruments 563 — — — 563 Deferred tax asset 7,563 — — — 7,563 Operating lease assets 14,168 — — — 14,168 Operating lease assets - related parties 43,270 — — — 43,270 Other assets 10,026 5,514 — — 15,540 Total other assets 3,140,093 11,846 21,000 (3,059,791) 113,148 Total assets $ 4,333,535 $ 4,486,998 $ 31,622 $ (4,969,336) $ 3,882,819 Liabilities and Stockholders ’ Equity Current liabilities: Accounts payable and accrued liabilities $ 48,006 $ 367,088 $ 124 $ — $ 415,218 Accounts payable - intercompany 878,283 1,026,249 4,285 (1,908,817) — Short-term derivative instruments 303 — — — 303 Current portion of operating lease liabilities 13,826 — — — 13,826 Current portion of operating lease liabilities - related parties 21,220 — — — 21,220 Current maturities of long-term debt 631 — — — 631 Total current liabilities 962,269 1,393,337 4,409 (1,908,817) 451,198 Long-term derivative instruments 53,135 — — — 53,135 Asset retirement obligation - long-term — 58,322 2,033 — 60,355 Uncertain tax position liability 3,127 — — — 3,127 Non-current operating lease liabilities 342 — — — 342 Non-current operating lease liabilities - related parties 22,050 — — — 22,050 Long-term debt, net of current maturities 1,978,020 — — — 1,978,020 Total liabilities 3,018,943 1,451,659 6,442 (1,908,817) 2,568,227 Stockholders’ equity: Common stock 1,597 — — — 1,597 Paid-in capital 4,207,554 4,171,408 267,557 (4,438,965) 4,207,554 Accumulated other comprehensive loss (46,833) — (44,763) 44,763 (46,833) Accumulated deficit (2,847,726) (1,136,069) (197,614) 1,333,683 (2,847,726) Total stockholders’ equity 1,314,592 3,035,339 25,180 (3,060,519) 1,314,592 Total liabilities and stockholders ’ equity $ 4,333,535 $ 4,486,998 $ 31,622 $ (4,969,336) $ 3,882,819
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Total revenues $ (53,823) $ 189,999 $ — $ — $ 136,176 Costs and expenses: Lease operating expenses (157) 15,431 — — 15,274 Production taxes — 4,028 — — 4,028 Midstream gathering and processing expenses — 110,567 — — 110,567 Depreciation, depletion and amortization 2,265 49,120 166 — 51,551 Impairment of oil and natural gas properties — 270,874 — — 270,874 General and administrative expenses 29,454 (9,098) 168 — 20,524 Restructuring and liability management 8,984 — — — 8,984 Accretion expense — 774 — — 774 Total Operating Expenses 40,546 441,696 334 — 482,576 LOSS FROM OPERATIONS (94,369) (251,697) (334) — (346,400) OTHER EXPENSE (INCOME): Interest expense 34,488 (167) — — 34,321 Interest income (16) (36) — — (52) Loss from equity method investments and investments in subsidiaries 251,951 — 153 (251,951) 153 Other expense (income) 172 (31) — — 141 Total Other Expense (Income) 286,595 (234) 153 (251,951) 34,563 LOSS BEFORE INCOME TAXES (380,964) (251,463) (487) 251,951 (380,963) INCOME TAX EXPENSE — — — — — NET LOSS $ (380,964) $ (251,463) $ (487) $ 251,951 $ (380,963) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 27,358 $ 314,388 $ — $ — $ 341,746 Costs and expenses: Lease operating expenses (231) 22,704 — — 22,473 Production taxes 36 6,529 — — 6,565 Midstream gathering and processing expenses — 135,006 — — 135,006 Depreciation, depletion and amortization 2,686 160,418 166 — 163,270 Impairment of oil and natural gas properties — 571,442 — — 571,442 General and administrative expenses 25,757 (12,675) 116 — 13,198 Accretion expense — 747 — — 747 Total Operating Expenses 28,248 884,171 282 — 912,701 LOSS FROM OPERATIONS (890) (569,783) (282) — (570,955) OTHER EXPENSE (INCOME): Interest expense 36,566 (1,010) — — 35,556 Interest income (187) (151) — — (338) Gain on debt extinguishment (23,600) — — — (23,600) Loss from equity method investments and investments in subsidiaries 616,348 — 40 (573,306) 43,082 Other (income) expense (1,168) 3,362 — 1,000 3,194 Total Other Expense 627,959 2,201 40 (572,306) 57,894 LOSS BEFORE INCOME TAXES (628,849) (571,984) (322) 572,306 (628,849) INCOME TAX BENEFIT (144,047) — — — (144,047) NET LOSS $ (484,802) $ (571,984) $ (322) $ 572,306 $ (484,802) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Nine months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Total revenues $ 71,415 $ 550,400 $ — $ — $ 621,815 Costs and expenses: Lease operating expenses (157) 47,103 — — 46,946 Production taxes — 12,432 — — 12,432 Midstream gathering and processing expenses — 334,789 — — 334,789 Depreciation, depletion, and amortization 7,155 186,716 498 — 194,369 Impairment of oil and gas properties — 1,357,099 — — 1,357,099 General and administrative expenses 75,214 (29,122) 454 — 46,546 Restructuring and liability management 9,601 — — — 9,601 Accretion expense — 2,270 — — 2,270 Total Operating Expenses 91,813 1,911,287 952 — 2,004,052 LOSS FROM OPERATIONS (20,398) (1,360,887) (952) — (1,382,237) OTHER EXPENSE (INCOME): Interest expense 100,490 (813) — — 99,677 Interest income (103) (179) — — (282) Gain on debt extinguishment (49,579) — — — (49,579) Loss from equity method investments and investments in subsidiaries 1,377,819 — 341 (1,367,173) 10,987 Other expense 3,255 5,984 — — 9,239 Total Other Expense 1,431,882 4,992 341 (1,367,173) 70,042 LOSS BEFORE INCOME TAXES (1,452,280) (1,365,879) (1,293) 1,367,173 (1,452,279) INCOME TAX EXPENSE 7,290 — — — 7,290 NET LOSS $ (1,459,570) $ (1,365,879) $ (1,293) $ 1,367,173 $ (1,459,569) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Nine months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 493,895 $ 732,763 $ — $ — $ 1,226,658 Costs and expenses: Lease operating expenses 26,918 37,750 — — 64,668 Production taxes 6,117 16,467 — — 22,584 Midstream gathering and processing expenses 71,420 311,223 — — 382,643 Depreciation, depletion, and amortization 201,250 205,183 221 — 406,654 Impairment of oil and natural gas properties — 571,442 — — 571,442 General and administrative expenses 51,695 (16,933) 220 — 34,982 Accretion expense 1,389 1,784 — — 3,173 Total Operating Expenses 358,789 1,126,916 441 — 1,486,146 INCOME (LOSS) FROM OPERATIONS 135,106 (394,153) (441) — (259,488) OTHER EXPENSE (INCOME): Interest expense 109,864 (2,269) — — 107,595 Interest income (454) (195) — — (649) Gain on debt extinguishment (23,600) — — — (23,600) Loss from equity method investments and investments in subsidiaries 560,883 — 379 (396,871) 164,391 Other (income) expense (605) 3,362 — 1,000 3,757 Total Other Expense 646,088 898 379 (395,871) 251,494 LOSS BEFORE INCOME TAXES (510,982) (395,051) (820) 395,871 (510,982) INCOME TAX BENEFIT (323,378) — — — (323,378) NET LOSS $ (187,604) $ (395,051) $ (820) $ 395,871 $ (187,604)
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)	Three months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Net loss $ (380,964) $ (251,463) $ (487) $ 251,951 $ (380,963) Foreign currency translation adjustment 3,661 — 3,661 (3,661) 3,661 Other comprehensive loss 3,661 — 3,661 (3,661) 3,661 Comprehensive loss $ (377,303) $ (251,463) $ 3,174 $ 248,290 $ (377,302) Three months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Net loss $ (484,802) $ (571,984) $ (322) $ 572,306 $ (484,802) Foreign currency translation adjustment (2,064) (43) (2,021) 2,064 (2,064) Other comprehensive income (2,064) (43) (2,021) 2,064 (2,064) Comprehensive loss $ (486,866) $ (572,027) $ (2,343) $ 574,370 $ (486,866) Nine months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Net loss $ (1,459,570) $ (1,365,879) $ (1,293) $ 1,367,173 $ (1,459,569) Foreign currency translation adjustment (4,497) (360) (4,137) 4,497 (4,497) Other comprehensive loss (4,497) (360) (4,137) 4,497 (4,497) Comprehensive loss $ (1,464,067) $ (1,366,239) $ (5,430) $ 1,371,670 $ (1,464,066) Nine months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Net loss $ (187,604) $ (395,051) $ (820) $ 395,871 $ (187,604) Foreign currency translation adjustment 5,347 112 5,235 (5,347) 5,347 Other comprehensive income 5,347 112 5,235 (5,347) 5,347 Comprehensive (loss) income $ (182,257) $ (394,939) $ 4,415 $ 390,524 $ (182,257)
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS (Amounts in thousands) Nine months ended September 30, 2020 Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ (95,023) $ 290,147 $ 4,442 $ 435 $ 200,001 Net cash used in investing activities 351 (291,047) — — (290,696) Net cash (used in) provided by financing activities 135,678 — 435 (435) 135,678 Net (decrease) increase in cash, cash equivalents and restricted cash 41,006 (900) 4,877 — 44,983 Cash, cash equivalents and restricted cash at beginning of period 2,768 3,097 195 — 6,060 Cash, cash equivalents and restricted cash at end of period $ 43,774 $ 2,197 $ 5,072 $ — $ 51,043 Nine months ended September 30, 2019 Parent Guarantors Non-Guarantor Eliminations Consolidated Net cash (used in) provided by operating activities $ (7,604) $ 621,511 $ 3,445 $ 3 $ 617,355 Net cash provided by (used in) investing activities 9,178 (644,507) (3,751) 432 (638,648) Net cash (used in) provided by financing activities (20,880) — 435 (435) (20,880) Net (decrease) increase in cash, cash equivalents and restricted cash (19,306) (22,996) 129 — (42,173) Cash, cash equivalents and restricted cash at beginning of period 25,585 26,711 1 — 52,297 Cash, cash equivalents and restricted cash at end of period $ 6,279 $ 3,715 $ 130 $ — $ 10,124

BASIS OF PRESENTATION, SUMMAR_4

BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN (Narrative) (Details) - USD ($)	Nov. 02, 2020	Oct. 15, 2020	Sep. 30, 2020	Oct. 08, 2020	Dec. 31, 2019
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Percentage decrease in capital spending (more than)			50.00%
Unsecured notes repurchased					$ 200,000,000
Long-term debt			$ 2,100,000,000
Revolving Credit Agreement | Revolving Credit Agreement
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Borrowing base			700,000,000
Unsecured Debt
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Unsecured notes repurchased			$ 73,300,000
Senior Notes | 6.000% senior unsecured notes due 2024
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Stated interest rate, percent			6.00%
Senior Notes | 6.625% senior unsecured notes due 2023
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Stated interest rate, percent			6.625%
Subsequent Event | Revolving Credit Agreement | Revolving Credit Agreement
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Borrowing base				$ 580,000,000
Subsequent Event | Senior Notes | 6.000% senior unsecured notes due 2024
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Debt instrument, interest		$ 17,400,000
Stated interest rate, percent		6.00%
Subsequent Event | Senior Notes | 6.625% senior unsecured notes due 2023
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Debt instrument, interest	$ 10,800,000
Stated interest rate, percent	6.625%

BASIS OF PRESENTATION, SUMMAR_5

BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN (Schedule of Error Corrections and Prior Period Adjustments) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Total revenues	$ 136,176	$ 341,746	$ 621,815	$ 1,226,658
Midstream gathering and processing expenses	110,567	135,006	334,789	382,643
Total Operating Expenses	482,576	912,701	2,004,052	1,486,146
Natural gas sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue	$ 155,163	269,798	$ 456,859	876,411
As Reported
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Total revenues		285,175		1,064,747
Midstream gathering and processing expenses		78,435		220,732
Total Operating Expenses		856,130		1,324,235
As Reported | Natural gas sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue		213,227		714,500
Adjustments
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Total revenues		56,571		161,911
Midstream gathering and processing expenses		56,571		161,911
Total Operating Expenses		56,571		161,911
Adjustments | Natural gas sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue		$ 56,571		$ 161,911

PROPERTY AND EQUIPMENT (Schedul

PROPERTY AND EQUIPMENT (Schedule of Property and Equipment) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Oil and natural gas properties	$ 10,786,305	$ 10,595,735
Accumulated DD&A and impairment	(8,735,750)	(7,191,957)
Oil and natural gas properties, net	2,050,555	3,403,778
Other depreciable property and equipment	91,101	91,198
Land	4,820	5,521
Accumulated DD&A	(43,954)	(36,703)
Other property and equipment, net	51,967	60,016
Property and equipment, net	$ 2,102,522	$ 3,463,794

PROPERTY AND EQUIPMENT (Narrati

PROPERTY AND EQUIPMENT (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Impairment of oil and natural gas properties	$ 270,874	$ 571,442	$ 1,357,099	$ 571,442
Capitalized general and administrative costs	6,200	$ 9,800	19,800	$ 26,300
Non-producing leasehold costs	$ 1,526,941		$ 1,526,941		$ 1,686,666

PROPERTY AND EQUIPMENT (Summary

PROPERTY AND EQUIPMENT (Summary of Non-producing Properties Excluded from Amortization by Area) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total non-producing properties not subject to amortization	$ 1,526,941	$ 1,686,666
Utica
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total non-producing properties not subject to amortization	850,643
SCOOP
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total non-producing properties not subject to amortization	674,280
Other
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total non-producing properties not subject to amortization	$ 2,018

PROPERTY AND EQUIPMENT (Sched_2

PROPERTY AND EQUIPMENT (Schedule of Asset Retirement Obligation) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning of period			$ 60,355	$ 79,952
Liabilities incurred			2,343	5,769
Liabilities settled			0	(117)
Liabilities removed due to divestitures			(2,033)	(30,035)
Accretion expense	$ 774	$ 747	2,270	3,173
Revisions in estimated cash flows			0	1,077
Asset retirement obligation as of end of period	$ 62,935	$ 59,819	$ 62,935	$ 59,819

DIVESTITURES (Details)

DIVESTITURES (Details) - USD ($)	Jan. 02, 2020	Sep. 30, 2020
Discontinued Operations and Disposal Groups [Abstract]
Proceeds from sale of assets	$ 50,000,000
Sale of asset, incentive payments, term	15 years
Fair value of contingent consideration asset	$ 23,100,000	$ 19,700,000
Gain (loss) on sale		$ 0

EQUITY INVESTMENTS (Investments

EQUITY INVESTMENTS (Investments Accounted for by the Equity Method) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Mar. 31, 2020	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Equity investments and investments in subsidiaries	$ 16,560,000		$ 16,560,000			$ 32,044,000
Loss from equity method investments, net	$ (153,000)	$ (43,082,000)	$ (10,987,000)	$ (164,391,000)
Investment in Grizzly Oil Sands ULC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	24.60%		24.60%
Equity investments and investments in subsidiaries	$ 16,521,000		$ 16,521,000			21,000,000
Loss from equity method investments, net	$ (153,000)	(41,000)	$ (341,000)	(380,000)
Investment in Mammoth Energy Services, Inc.
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	21.50%		21.50%
Equity investments and investments in subsidiaries	$ 0		$ 0		$ 0	11,005,000
Loss from equity method investments, net	$ 0	(43,041,000)	$ (10,646,000)	(166,096,000)
Investment in Windsor Midstream LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	22.50%		22.50%
Equity investments and investments in subsidiaries	$ 39,000		$ 39,000			39,000
Loss from equity method investments, net	$ 0	0		0
Investment in Tatex Thailand II, LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	23.50%		23.50%
Equity investments and investments in subsidiaries	$ 0		$ 0			$ 0
Loss from equity method investments, net	$ 0	$ 0	$ 0	$ 2,085,000

EQUITY INVESTMENTS (Equity Inve

EQUITY INVESTMENTS (Equity Investments Balance Sheet Disclosure) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Current assets	$ 216,339	$ 305,877
Current liabilities	321,936	451,198
Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Current assets	463,853	421,326
Noncurrent assets	1,086,150	1,260,075
Current liabilities	115,976	132,569
Noncurrent liabilities	$ 161,183	$ 163,241

EQUITY INVESTMENTS (Equity In_2

EQUITY INVESTMENTS (Equity Investment Income Statement Disclosure) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Schedule of Equity Method Investments [Line Items]
Gross revenue	$ 136,176	$ 341,746	$ 621,815	$ 1,226,658
Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Gross revenue	70,534	113,417	228,026	557,375
Net (loss) income	$ 2,808	$ (35,730)	$ (97,145)	$ (15,046)

EQUITY INVESTMENTS (Narrative)

EQUITY INVESTMENTS (Narrative) (Details) $ / shares in Units, a in Thousands	1 Months Ended		3 Months Ended		9 Months Ended
	May 31, 2019$ / shares	Feb. 28, 2019$ / shares	Sep. 30, 2020USD ($)shares	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)ashares	Sep. 30, 2019USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Schedule of Equity Method Investments [Line Items]
Equity investments			$ 16,560,000		$ 16,560,000			$ 32,044,000
Investment in Mammoth Energy Services, Inc.
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership (in shares) | shares			9,829,548		9,829,548
Approximate fair value, quoted market price			$ 15,700,000		$ 15,700,000
Share dividend (in usd per share) | $ / shares	$ 0.125	$ 0.125
Investment in Grizzly Oil Sands ULC
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership interest, percent			24.60%		24.60%
Equity method investment, impairment					$ 0	$ 0
Equity method investment, amount of cash calls, based on proportionate ownership interest						400,000
Equity Method Investments, Increase (Decrease) Due To Foreign Currency Translation Adjustment			$ (3,700,000)	$ 2,000,000	4,100,000	(5,200,000)
Equity investments			$ 16,521,000		$ 16,521,000			21,000,000
Investment in Mammoth Energy Services, Inc.
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership interest, percent			21.50%		21.50%
Equity investments			$ 0		$ 0		$ 0	11,005,000
Distributions from equity method investments					$ 0	2,500,000
Windsor Midstream LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership interest, percent			22.50%		22.50%
Equity investments			$ 39,000		$ 39,000			39,000
Distributions from equity method investments					$ 0
Tatex Thailand II, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership interest, percent			23.50%		23.50%
Equity investments			$ 0		$ 0			$ 0
Distributions from equity method investments					$ 0	$ 2,100,000
Athabasca, Peace River And Cold Lake Oil Sands Regions | Investment in Grizzly Oil Sands ULC
Schedule of Equity Method Investments [Line Items]
Gas and oil area, reserve (in acres) | a					830
Phu Horm Field | Apico Llc
Schedule of Equity Method Investments [Line Items]
Gas and oil area, reserve (in acres) | a					108
Apico Llc | Tatex Thailand II, LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	8.50%

LONG-TERM DEBT (Break-Down of L

LONG-TERM DEBT (Break-Down of Long-Term Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Net unamortized debt issuance costs	$ (19,772)	$ (23,751)
Less: current maturities of long term debt	(656)	(631)
Debt reflected as long term	2,068,036	1,978,020
Construction Loan
Debt Instrument [Line Items]
Net unamortized debt issuance costs	(100)
6.625% senior unsecured notes due 2023 | Senior Notes
Debt Instrument [Line Items]
Long-term debt	324,583	329,467
Net unamortized debt issuance costs	$ (2,600)
Stated interest rate, percent	6.625%
6.000% senior unsecured notes due 2024 | Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 579,568	603,428
Net unamortized debt issuance costs	$ (5,700)
Stated interest rate, percent	6.00%
6.375% senior unsecured notes due 2025 | Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 507,870	529,525
Net unamortized debt issuance costs	$ (8,100)
Stated interest rate, percent	6.375%
6.375% senior unsecured notes due 2026 | Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 374,617	397,529
Net unamortized debt issuance costs	$ (3,300)
Stated interest rate, percent	6.375%
Nova Scotia, Amegy, KeyBank | Revolving Credit Agreement | Revolving Credit Agreement
Debt Instrument [Line Items]
Long-term debt	$ 279,857	120,000
InterBank | Letter of Credit | Construction Loan
Debt Instrument [Line Items]
Long-term debt	$ 21,969	$ 22,453

LONG-TERM DEBT (Narrative) (Det

LONG-TERM DEBT (Narrative) (Details)	Sep. 30, 2021	Nov. 02, 2020USD ($)	Oct. 15, 2020USD ($)	May 01, 2020USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Nov. 05, 2020USD ($)	Oct. 08, 2020USD ($)	Jul. 27, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Nov. 25, 2019USD ($)
Debt Instrument [Line Items]
Debt issuance costs, net					$ 19,772,000		$ 19,772,000						$ 23,751,000
Capitalized interest expense, undeveloped properties					200,000	$ 1,000,000	900,000	$ 2,800,000
Amount of debt to be repurchased													200,000,000
Repayments of debt							372,484,000	550,500,000
Gain on debt extinguishment					0	$ 23,600,000	49,579,000	$ 23,600,000
Subsequent Event
Debt Instrument [Line Items]
cash on hand									$ 61,700,000
Senior Notes | Carry Value
Debt Instrument [Line Items]
Carrying value of notes					1,800,000,000		1,800,000,000
Senior Notes | Fair Value | Level 1
Debt Instrument [Line Items]
Carrying value of notes					1,100,000,000		1,100,000,000
Construction Loan
Debt Instrument [Line Items]
Debt issuance costs, net					100,000		100,000
Revolving Credit Facility
Debt Instrument [Line Items]
Amount of principal repurchased					0		73,300,000
Repayments of debt							22,800,000
Gain on debt extinguishment							49,600,000
6.625% senior unsecured notes due 2023 | Senior Notes
Debt Instrument [Line Items]
Long-term debt					$ 324,583,000		$ 324,583,000						329,467,000
Stated interest rate, percent					6.625%		6.625%
Debt issuance costs, net					$ 2,600,000		$ 2,600,000
6.625% senior unsecured notes due 2023 | Senior Notes | Subsequent Event
Debt Instrument [Line Items]
Stated interest rate, percent		6.625%
Debt instrument, interest		$ 10,800,000
6.000% senior unsecured notes due 2024 | Senior Notes
Debt Instrument [Line Items]
Long-term debt					$ 579,568,000		$ 579,568,000						603,428,000
Stated interest rate, percent					6.00%		6.00%
Debt issuance costs, net					$ 5,700,000		$ 5,700,000
6.000% senior unsecured notes due 2024 | Senior Notes | Subsequent Event
Debt Instrument [Line Items]
Stated interest rate, percent			6.00%
Debt instrument, interest			$ 17,400,000
6.375% senior unsecured notes due 2025 | Senior Notes
Debt Instrument [Line Items]
Long-term debt					$ 507,870,000		$ 507,870,000						529,525,000
Stated interest rate, percent					6.375%		6.375%
Debt issuance costs, net					$ 8,100,000		$ 8,100,000
6.375% senior unsecured notes due 2026 | Senior Notes
Debt Instrument [Line Items]
Long-term debt					$ 374,617,000		$ 374,617,000						397,529,000
Stated interest rate, percent					6.375%		6.375%
Debt issuance costs, net					$ 3,300,000		$ 3,300,000
Revolving Credit Agreement | Revolving Credit Agreement
Debt Instrument [Line Items]
Elected commitment amount					700,000,000		700,000,000
Maximum repayment amount											$ 750,000,000
Revolving Credit Agreement | Revolving Credit Agreement | Subsequent Event
Debt Instrument [Line Items]
Elected commitment amount										$ 580,000,000
Nova Scotia, Amegy, KeyBank | Revolving Credit Agreement | Revolving Credit Agreement
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity					1,500,000,000		1,500,000,000
Elected commitment amount				$ 700,000,000								$ 1,000,000,000		$ 1,200,000,000
Maximum net secured debt to EBITDAX ratio				2
Long-term debt					279,857,000		279,857,000						$ 120,000,000
Remaining borrowing capacity					100,100,000		$ 100,100,000
Nova Scotia, Amegy, KeyBank | Revolving Credit Agreement | Revolving Credit Agreement | Subsequent Event
Debt Instrument [Line Items]
Long-term debt									355,500,000
Remaining borrowing capacity									0
Nova Scotia, Amegy, KeyBank | Revolving Credit Agreement | Revolving Credit Agreement | Forecast
Debt Instrument [Line Items]
Net funded debt to EBITDAX ratio	4
Nova Scotia, Amegy, KeyBank | Letter of Credit
Debt Instrument [Line Items]
Credit facility interest rate at the eurodollar rate							2.90%
Nova Scotia, Amegy, KeyBank | Letter of Credit | Revolving Credit Agreement
Debt Instrument [Line Items]
Credit facility outstanding					$ 320,000,000		$ 320,000,000
Nova Scotia, Amegy, KeyBank | Letter of Credit | Revolving Credit Agreement | Subsequent Event
Debt Instrument [Line Items]
Credit facility outstanding									$ 243,700,000

CHANGES IN CAPITALIZATION (Deta

CHANGES IN CAPITALIZATION (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended						9 Months Ended
	Jan. 31, 2019	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Class of Stock [Line Items]
Stock repurchase program, period in force	24 months
Value of shares repurchased		$ 129	$ 28	$ 79	$ 89	$ 2,270	$ 28,330
Share purchased to satisfy tax withholding requirements (in shares)		136,000			36,000			243,000	123,000
Shares repurchased to satisfy tax withholding requirements		$ 100			$ 100			$ 200	$ 700
Common Stock
Class of Stock [Line Items]
Shares repurchased (in shares)		136,000	27,000	80,000	36,000	297,000	3,619,000
Value of shares repurchased		$ 2		$ 1		$ 3	$ 37
Share Repurchase Program | Common Stock
Class of Stock [Line Items]
Shares repurchased (in shares)								0	3,800,000
Value of shares repurchased									$ 30,000

STOCK-BASED COMPENSATION (Narra

STOCK-BASED COMPENSATION (Narrative) (Details) - USD ($) $ in Millions	Aug. 04, 2020	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Aug. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation cost		$ 8.9	$ 2.7	$ 13.2	$ 8.3
Capitalized stock-based compensation cost		0.3	$ 1.1	$ 2.2	$ 3.3
Percent of target based award, minimum				0.00%
Percent of target based award, maximum				200.00%
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		6.4		$ 6.4
Weighted average period of expense recognition period				1 year 6 months 7 days
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		1.7		$ 1.7
Weighted average period of expense recognition period				1 year 6 months 3 days
Incentive Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation cost				$ 1.5
Percentage of cash retention incentives clawed back	50.00%
Percentage of cash retention incentives repaid	50.00%
Cash retention						$ 13.5
Cash incentives net		5.2		5.2
Prepaid cash incentives		$ 4.8		$ 4.8
Minimum | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period				1 year
Maximum | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period				3 years

STOCK-BASED COMPENSATION (Restr

STOCK-BASED COMPENSATION (Restricted Stock Award and Unit Activity) (Details)	9 Months Ended
	Sep. 30, 2020$ / sharesshares
Restricted Stock
Number of Unvested Restricted Shares
Unvested shares, beginning balance (in shares) | shares	4,098,318
Granted (in shares) | shares	3,069,521
Vested (in shares) | shares	(1,294,285)
Forfeited/canceled (in shares) | shares	(4,166,493)
Unvested shares, ending balance (in shares) | shares	1,707,061
Weighted Average Grant Date Fair Value
Unvested shares, beginning balance (in usd per share) | $ / shares	$ 4.73
Granted (in usd per share) | $ / shares	0.85
Vested (in usd per share) | $ / shares	5.73
Forfeited/canceled (in usd per share) | $ / shares	1.67
Unvested shares, ending balance (in usd per share) | $ / shares	$ 4.73
Performance Shares
Number of Unvested Restricted Shares
Unvested shares, beginning balance (in shares) | shares	1,783,660
Granted (in shares) | shares	0
Vested (in shares) | shares	0
Forfeited/canceled (in shares) | shares	(943,065)
Unvested shares, ending balance (in shares) | shares	840,595
Weighted Average Grant Date Fair Value
Unvested shares, beginning balance (in usd per share) | $ / shares	$ 2.96
Granted (in usd per share) | $ / shares	0
Vested (in usd per share) | $ / shares	0
Forfeited/canceled (in usd per share) | $ / shares	1.98
Unvested shares, ending balance (in usd per share) | $ / shares	$ 4.07

EARNINGS (LOSS) PER SHARE (Deta

EARNINGS (LOSS) PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Basic:
Net loss - basic	$ (380,963)	$ (484,802)	$ (1,459,569)	$ (187,604)
Net loss - basic (in shares)	160,682,629	159,548,477	160,053,093	160,553,796
Net loss - basic (in usd per share)	$ (2.37)	$ (3.04)	$ (9.12)	$ (1.17)
Effect of dilutive securities:
Stock awards	$ 0	$ 0	$ 0	$ 0
Stock options and awards (in shares)	0	0	0	0
Diluted:
Net loss - diluted	$ (380,963)	$ (484,802)	$ (1,459,569)	$ (187,604)
Net loss - diluted (in shares)	160,682,629	159,548,477	160,053,093	160,553,796
Net loss - diluted (in usd per share)	$ (2.37)	$ (3.04)	$ (9.12)	$ (1.17)
Anti-dilutive shares	0	2,073,638	0	4,266,206

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES (Future Commitments) (Details) MMBTU in Thousands, $ in Thousands	Sep. 30, 2020USD ($)MMBTU
Commitments [Line Items]
Remaining 2020 (in mmbtu)	286
2021 (in mmbtu)	183
2022 (in mmbtu)	70
2023 (in mmbtu)	17
Total (in mmbtu)	556
Remaining 2020 | $	$ 1,875
2021 | $	7,500
Total | $	$ 9,375
Transportation Commitment
Commitments [Line Items]
Remaining 2020 (in mmbtu)	126,960
2021 (in mmbtu)	510,575
2022 (in mmbtu)	535,414
2023 (in mmbtu)	520,114
2024 (in mmbtu)	493,841
Thereafter (in mmbtu)	3,791,093
Total (in mmbtu)	5,977,997
Remaining 2020 | $	$ 67,458
2021 | $	278,805
2022 | $	288,135
2023 | $	284,454
2024 | $	267,077
Thereafter | $	2,220,685
Total | $	$ 3,406,614

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) MMBTU in Thousands, $ in Thousands	1 Months Ended			3 Months Ended		9 Months Ended
	Sep. 30, 2020USD ($)MMBTU	Apr. 30, 2020	Oct. 31, 2018USD ($)	Sep. 30, 2020USD ($)MMBTU	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)MMBTUcomplaint	Sep. 30, 2019USD ($)
Commitments [Line Items]
Number of claims filed (in claims) | complaint						2
Loss contingency, damages sought, percentages of unpaid overtime compensation		6.00%
Environmental cost			$ 180
Muskie v. Company
Commitments [Line Items]
Loss contingency, damages sought	$ 2,500
Stingray Pressure Pumping LLC v. Gulfport Energy Corporation
Commitments [Line Items]
Loss contingency, damages sought	$ 37,000
Transportation Commitment
Commitments [Line Items]
Firm transportation contracts, remainder of 2020 (in mmbtu) | MMBTU	1,380			1,380		1,380
Firm transportation contracts, due in 2021 (in mmbtu) | MMBTU	1,399			1,399		1,399
Midship Pipeline LLC | Transportation Commitment
Commitments [Line Items]
Prepayment reservation charges						$ 32,900
Loss on Long-Term Purchase Commitment | Muskie Proppant LLC
Commitments [Line Items]
Non-utilization fees, accrued damages year to date				$ 1,900	$ 20	$ 5,600	$ 400

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES (Future Minimum Commitments) (Details) $ in Thousands	Sep. 30, 2020USD ($)
Commitments and Contingencies Disclosure [Abstract]
Remaining 2020	$ 1,875
2021	7,500
Total	$ 9,375

DERIVATIVE INSTRUMENTS (Schedul

DERIVATIVE INSTRUMENTS (Schedule of Derivative Instruments) (Details)	9 Months Ended
	Sep. 30, 2020MMBTU$ / MMBTU$ / bblbbl
NYMEX Henry Hub - Remaining 2020
Derivative [Line Items]
Daily Volume (MMBtu/day) | MMBTU	500,000
Weighted average price (in usd per MMBtu or Bbl) | $ / MMBTU	2.69
NYMEX WTI - Remaining 2020
Derivative [Line Items]
Daily Volume (Bbls/day) | bbl	3,000
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl	35.49
Mont Belvieu C3 - Remaining 2020
Derivative [Line Items]
Daily Volume (Bbls/day) | bbl	1,500
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl	20.27
NYMEX Henry Hub - 2022 | Short | Call Option
Derivative [Line Items]
Daily Volume (MMBtu/day) | MMBTU	628,000
Weighted average price (in usd per MMBtu or Bbl) | $ / MMBTU	2.90
NYMEX Henry Hub - 2023 | Short | Call Option
Derivative [Line Items]
Daily Volume (MMBtu/day) | MMBTU	628,000
Weighted average price (in usd per MMBtu or Bbl) | $ / MMBTU	2.90
NYMEX Henry Hub - 2021
Derivative [Line Items]
Daily Volume (MMBtu/day) | MMBTU	250,000
Weighted average floor price (in usd per MMBtu) | $ / MMBTU	2.46
Weighted average ceiling price (in usd per MMBtu) | $ / bbl	2.81
Transco Zone 4 - Remaining 2020 | Long
Derivative [Line Items]
Daily Volume (MMBtu/day) | MMBTU	60,000
Weighted average price (in usd per MMBtu or Bbl) | $ / MMBTU	(0.05)
Fixed Spread - Remaining 2020 | Long
Derivative [Line Items]
Daily Volume (MMBtu/day) | MMBTU	10,000
Weighted average price (in usd per MMBtu or Bbl) | $ / MMBTU	(0.54)

DERIVATIVE INSTRUMENTS (Narrati

DERIVATIVE INSTRUMENTS (Narrative) (Details) MMBTU in Thousands, $ in Thousands	Nov. 06, 2020USD ($)MMBTU$ / MMBTU	Oct. 30, 2020USD ($)MMBTU	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)
Derivative [Line Items]
Net cash receipts on settled derivative instruments | $			$ 225,364	$ 80,744
Subsequent Event
Derivative [Line Items]
Daily volume (in MMBtu) | MMBTU	475
Net cash receipts on settled derivative instruments | $	$ 60,200	$ 200
Strike price | $ / MMBTU	2.90
2020 | Subsequent Event
Derivative [Line Items]
Daily volume (in MMBtu) | MMBTU		40

DERIVATIVE INSTRUMENTS (Conting

DERIVATIVE INSTRUMENTS (Contingent Consideration Arrangement) (Details)	9 Months Ended
	Sep. 30, 2020USD ($)$ / shares
Derivative [Line Items]
Derivative, credit risk related contingent features, payment to be received, denominator (in usd per share)	$ 8.03
Derivative Threshold, Greater Than or Equal to $60.65
Derivative [Line Items]
Payment to be received | $	$ 150,000
Derivative, credit risk related contingent features, commodity price threshold (in usd per share)	$ 60.65
Derivative Threshold, Between $52.62 and $60.65
Derivative [Line Items]
Payment to be received | $	$ 150,000
Derivative Threshold, Between $52.62 and $60.65 | Minimum
Derivative [Line Items]
Derivative, credit risk related contingent features, commodity price threshold (in usd per share)	$ 52.62
Derivative Threshold, Between $52.62 and $60.65 | Maximum
Derivative [Line Items]
Derivative, credit risk related contingent features, commodity price threshold (in usd per share)	$ 60.65
Derivative Threshold, Less Than or Equal to $52.62
Derivative [Line Items]
Payment to be received | $	$ 0
Derivative, credit risk related contingent features, commodity price threshold (in usd per share)	$ 52.62

DERIVATIVE INSTRUMENTS (Derivat

DERIVATIVE INSTRUMENTS (Derivative Instruments in Financial Position) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Short-term derivative asset	$ 6,245	$ 126,201
Long-term derivative asset	1,098	563
Short-term derivative liability	(24,164)	(303)
Long-term derivative liability	(63,803)	(53,135)
Total net (liability) asset derivative position	(80,624)	73,326
Commodity Contracts
Derivatives, Fair Value [Line Items]
Short-term derivative asset	6,245	125,383
Long-term derivative asset	1,098	0
Short-term derivative liability	(24,164)	(303)
Long-term derivative liability	(63,803)	(53,135)
Total net (liability) asset derivative position	(80,624)	71,945
Contingent consideration arrangement
Derivatives, Fair Value [Line Items]
Short-term derivative asset		818
Long-term derivative asset	0	563
Total contingent consideration derivative position	$ 0	$ 1,381

DERIVATIVE INSTRUMENTS (Net (Lo

DERIVATIVE INSTRUMENTS (Net (Loss) Gain on Derivative Instruments) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Derivative [Line Items]
Net (loss) gain on natural gas, oil and NGL derivatives	$ (53,823)	$ 27,074	$ 71,414	$ 178,169
Natural gas derivatives
Derivative [Line Items]
Net (loss) gain on natural gas, oil and NGL derivatives	(52,648)	11,731	28,894	147,774
Oil derivatives
Derivative [Line Items]
Net (loss) gain on natural gas, oil and NGL derivatives	(782)	12,736	44,155	24,153
NGL derivatives
Derivative [Line Items]
Net (loss) gain on natural gas, oil and NGL derivatives	(393)	3,641	(254)	7,276
Contingent consideration arrangement
Derivative [Line Items]
Net (loss) gain on natural gas, oil and NGL derivatives	$ 0	$ (1,034)	$ (1,381)	$ (1,034)

DERIVATIVE INSTRUMENTS (Sched_2

DERIVATIVE INSTRUMENTS (Schedule of Offsetting) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gross assets presented in the consolidated balance sheet	$ 7,343	$ 126,764
Gross assets subject to mater netting agreement - assets	(6,948)	(53,438)
Net amount - assets	395	73,326
Gross liabilities presented in the consolidated balance sheet	(87,967)	(53,438)
Gross amounts subject to master netting agreement - liabilities	6,948	53,438
Net amount - liabilities	$ (81,019)	$ 0

RESTRUCTURING AND LIABILITY M_3

RESTRUCTURING AND LIABILITY MANAGEMENT (Summary of Cost Incurred) (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2020USD ($)	Sep. 30, 2020USD ($)
Restructuring and Related Activities [Abstract]
Workforce reduction	10.00%	10.00%
Reduction in workforce	$ 1,460	$ 1,460
Liability management	7,524	8,141
Total restructuring and liability management	$ 8,984	$ 9,601

FAIR VALUE MEASUREMENTS (Detail

FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	Jan. 02, 2020	Sep. 30, 2020	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Liabilities:
Fair value of contingent consideration asset	$ 23,100		$ 19,700
Contingent consideration, gain (loss) due to change in value		$ (200)	(3,100)
Contingent consideration, settlements			300
Asset retirement obligation capitalized			2,343	$ 5,769
Level 1
Assets:
Derivative Instruments		0	0		$ 0
Liabilities:
Derivative Instruments		0	0		0
Level 2
Assets:
Derivative Instruments		7,343	7,343		126,764
Liabilities:
Derivative Instruments		87,967	87,967		53,438
Level 3
Assets:
Derivative Instruments		0	0		0
Liabilities:
Derivative Instruments		$ 0	0		$ 0
Prepaid Expenses and Other Current Assets
Liabilities:
Fair value of contingent consideration asset			1,000
Other Noncurrent Assets
Liabilities:
Fair value of contingent consideration asset			$ 18,700

REVENUE FROM CONTRACTS WITH C_2

REVENUE FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Performance obligation period	However, settlement statements for certain sales may be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product
Receivables from contracts with customers	$ 92.4	$ 121.2
Maximum
Disaggregation of Revenue [Line Items]
Performance obligation period	30 days

LEASES (Narrative) (Details)

LEASES (Narrative) (Details)	Sep. 30, 2020
Lessee, Lease, Description [Line Items]
Weighted average remaining lease term	9 months 21 days
Weighted-average discount rate - operating leases	2.65%
Minimum
Lessee, Lease, Description [Line Items]
Lease term	1 year
Minimum | Drilling Rig
Lessee, Lease, Description [Line Items]
Lease term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease term	5 years
Maximum | Drilling Rig
Lessee, Lease, Description [Line Items]
Lease term	2 years

LEASES (Maturities of Lease Lia

LEASES (Maturities of Lease Liabilities) (Details) $ in Thousands	Sep. 30, 2020USD ($)
Leases [Abstract]
Remaining 2020	$ 1,664
2021	142
2022	115
2023	90
2024	30
Total lease payments	2,041
Less: Imputed interest	(29)
Total	$ 2,012

LEASES (Lease Cost) (Details)

LEASES (Lease Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Leases [Abstract]
Operating lease cost	$ 1,692	$ 4,551	$ 7,970	$ 20,835
Operating lease cost—related party	0	5,610	0	16,830
Variable lease cost	245	105	705	1,065
Variable lease cost—related party	0	5,357	0	64,968
Short-term lease cost	2,259	224	7,698	407
Total lease cost	$ 4,196	$ 15,847	$ 16,373	$ 104,105

LEASES (Other Information) (Det

LEASES (Other Information) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Leases [Abstract]
Operating cash flows from operating leases	$ 109	$ 146
Investing cash flow from operating leases	9,786	18,998
Investing cash flow from operating leases—related party	$ 6,800	$ 78,518

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Mar. 31, 2020	Sep. 30, 2020	Apr. 30, 2020
Income Tax Disclosure [Abstract]
Tax expense	$ 7.3
Testing period		3 years
Maximum percentage of company's securities allowed to be owned by third party			4.90%

CONDENSED CONSOLIDATING FINAN_3

CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Balance Sheets) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 51,043			$ 6,060
Accounts receivable - oil and natural gas sales	92,443			121,210
Accounts receivable - joint interest and other	15,421			47,975
Accounts receivable - intercompany	0			0
Prepaid expenses and other current assets	51,187			4,431
Short-term derivative instruments	6,245			126,201
Current assets	216,339			305,877
Property and equipment:
Oil and natural gas properties	10,786,305			10,595,735
Other property and equipment	95,921			96,719
Accumulated depletion, depreciation, amortization and impairment	(8,779,704)			(7,228,660)
Property and equipment, net	2,102,522			3,463,794
Other assets:
Equity investments and investments in subsidiaries	16,560			32,044
Long-term derivative instruments	1,098			563
Deferred tax asset	0			7,563
Operating lease assets	2,012			14,168
Operating lease assets—related parties	0			43,270
Other assets	37,028			15,540
Total other assets	56,698			113,148
Total assets	2,375,559			3,882,819
Current liabilities:
Accounts payable and accrued liabilities	295,359			415,218
Accounts payable - intercompany	0			0
Short-term derivative instruments	24,164			303
Current portion of operating lease liabilities	1,757			13,826
Current portion of operating lease liabilities—related parties	0			21,220
Current maturities of long-term debt	656			631
Current liabilities	321,936			451,198
Long-term derivative instruments	63,803			53,135
Asset retirement obligation - long-term	62,935			60,355
Uncertain tax position liability	3,371			3,127
Non-current operating lease liabilities	255			342
Non-current operating lease liabilities—related parties	0			22,050
Long-term debt, net of current maturities	2,068,036			1,978,020
Total liabilities	2,520,336			2,568,227
Stockholders’ equity:
Common stock	1,607			1,597
Paid-in capital	4,212,241			4,207,554
Accumulated other comprehensive loss	(51,330)			(46,833)
Accumulated deficit	(4,307,295)			(2,847,726)
Total stockholders’ equity	(144,777)	$ 231,340	$ 784,049	1,314,592	$ 3,123,104	$ 3,607,408	$ 3,368,266	$ 3,327,768
Total liabilities and stockholders’ equity	2,375,559			3,882,819
Reportable Legal Entities | Parent
Current assets:
Cash and cash equivalents	43,774			2,768
Accounts receivable - oil and natural gas sales	861			859
Accounts receivable - joint interest and other	428			5,279
Accounts receivable - intercompany	332,011			1,065,593
Prepaid expenses and other current assets	18,192			4,047
Short-term derivative instruments	6,245			126,201
Current assets	401,511			1,204,747
Property and equipment:
Oil and natural gas properties	1,248,836			1,314,933
Other property and equipment	92,551			92,650
Accumulated depletion, depreciation, amortization and impairment	(1,425,619)			(1,418,888)
Property and equipment, net	(84,232)			(11,305)
Other assets:
Equity investments and investments in subsidiaries	1,802,762			3,064,503
Long-term derivative instruments	1,098			563
Deferred tax asset				7,563
Operating lease assets	2,012			14,168
Operating lease assets—related parties				43,270
Other assets	28,390			10,026
Total other assets	1,834,262			3,140,093
Total assets	2,151,541			4,333,535
Current liabilities:
Accounts payable and accrued liabilities	59,543			48,006
Accounts payable - intercompany	74,733			878,283
Short-term derivative instruments	24,164			303
Current portion of operating lease liabilities	1,757			13,826
Current portion of operating lease liabilities—related parties				21,220
Current maturities of long-term debt	656			631
Current liabilities	160,853			962,269
Long-term derivative instruments	63,803			53,135
Asset retirement obligation - long-term	0			0
Uncertain tax position liability	3,371			3,127
Non-current operating lease liabilities	255			342
Non-current operating lease liabilities—related parties				22,050
Long-term debt, net of current maturities	2,068,036			1,978,020
Total liabilities	2,296,318			3,018,943
Stockholders’ equity:
Common stock	1,607			1,597
Paid-in capital	4,212,241			4,207,554
Accumulated other comprehensive loss	(51,329)			(46,833)
Accumulated deficit	(4,307,296)			(2,847,726)
Total stockholders’ equity	(144,777)			1,314,592
Total liabilities and stockholders’ equity	2,151,541			4,333,535
Reportable Legal Entities | Guarantors
Current assets:
Cash and cash equivalents	2,197			3,097
Accounts receivable - oil and natural gas sales	91,582			120,351
Accounts receivable - joint interest and other	14,993			42,696
Accounts receivable - intercompany	73,885			843,223
Prepaid expenses and other current assets	32,919			308
Short-term derivative instruments	0			0
Current assets	215,576			1,009,675
Property and equipment:
Oil and natural gas properties	9,531,593			9,273,681
Other property and equipment	51			50
Accumulated depletion, depreciation, amortization and impairment	(7,352,069)			(5,808,254)
Property and equipment, net	2,179,575			3,465,477
Other assets:
Equity investments and investments in subsidiaries	6,333			6,332
Long-term derivative instruments				0
Deferred tax asset				0
Operating lease assets	0			0
Operating lease assets—related parties				0
Other assets	8,638			5,514
Total other assets	14,971			11,846
Total assets	2,410,122			4,486,998
Current liabilities:
Accounts payable and accrued liabilities	235,778			367,088
Accounts payable - intercompany	321,373			1,026,249
Short-term derivative instruments	0			0
Current portion of operating lease liabilities	0			0
Current portion of operating lease liabilities—related parties				0
Current maturities of long-term debt	0			0
Current liabilities	557,151			1,393,337
Long-term derivative instruments	0			0
Asset retirement obligation - long-term	62,935			58,322
Uncertain tax position liability	0			0
Non-current operating lease liabilities	0			0
Non-current operating lease liabilities—related parties				0
Long-term debt, net of current maturities	0			0
Total liabilities	620,086			1,451,659
Stockholders’ equity:
Common stock	0			0
Paid-in capital	4,291,981			4,171,408
Accumulated other comprehensive loss	3			0
Accumulated deficit	(2,501,948)			(1,136,069)
Total stockholders’ equity	1,790,036			3,035,339
Total liabilities and stockholders’ equity	2,410,122			4,486,998
Reportable Legal Entities | Non-Guarantors
Current assets:
Cash and cash equivalents	5,072			195
Accounts receivable - oil and natural gas sales	0			0
Accounts receivable - joint interest and other	0			0
Accounts receivable - intercompany	0			0
Prepaid expenses and other current assets	76			76
Short-term derivative instruments	0			0
Current assets	5,148			271
Property and equipment:
Oil and natural gas properties	6,606			7,850
Other property and equipment	3,319			4,019
Accumulated depletion, depreciation, amortization and impairment	(2,016)			(1,518)
Property and equipment, net	7,909			10,351
Other assets:
Equity investments and investments in subsidiaries	16,521			21,000
Long-term derivative instruments				0
Deferred tax asset				0
Operating lease assets	0			0
Operating lease assets—related parties				0
Other assets	0			0
Total other assets	16,521			21,000
Total assets	29,578			31,622
Current liabilities:
Accounts payable and accrued liabilities	38			124
Accounts payable - intercompany	9,789			4,285
Short-term derivative instruments	0			0
Current portion of operating lease liabilities	0			0
Current portion of operating lease liabilities—related parties				0
Current maturities of long-term debt	0			0
Current liabilities	9,827			4,409
Long-term derivative instruments	0			0
Asset retirement obligation - long-term	0			2,033
Uncertain tax position liability	0			0
Non-current operating lease liabilities	0			0
Non-current operating lease liabilities—related parties				0
Long-term debt, net of current maturities	0			0
Total liabilities	9,827			6,442
Stockholders’ equity:
Common stock	0			0
Paid-in capital	267,560			267,557
Accumulated other comprehensive loss	(48,902)			(44,763)
Accumulated deficit	(198,907)			(197,614)
Total stockholders’ equity	19,751			25,180
Total liabilities and stockholders’ equity	29,578			31,622
Eliminations
Current assets:
Cash and cash equivalents	0			0
Accounts receivable - oil and natural gas sales	0			0
Accounts receivable - joint interest and other	0			0
Accounts receivable - intercompany	(405,896)			(1,908,816)
Prepaid expenses and other current assets	0			0
Short-term derivative instruments	0			0
Current assets	(405,896)			(1,908,816)
Property and equipment:
Oil and natural gas properties	(730)			(729)
Other property and equipment	0			0
Accumulated depletion, depreciation, amortization and impairment	0			0
Property and equipment, net	(730)			(729)
Other assets:
Equity investments and investments in subsidiaries	(1,809,056)			(3,059,791)
Long-term derivative instruments				0
Deferred tax asset				0
Operating lease assets	0			0
Operating lease assets—related parties				0
Other assets	0			0
Total other assets	(1,809,056)			(3,059,791)
Total assets	(2,215,682)			(4,969,336)
Current liabilities:
Accounts payable and accrued liabilities	0			0
Accounts payable - intercompany	(405,895)			(1,908,817)
Short-term derivative instruments	0			0
Current portion of operating lease liabilities	0			0
Current portion of operating lease liabilities—related parties				0
Current maturities of long-term debt	0			0
Current liabilities	(405,895)			(1,908,817)
Long-term derivative instruments	0			0
Asset retirement obligation - long-term	0			0
Uncertain tax position liability	0			0
Non-current operating lease liabilities	0			0
Non-current operating lease liabilities—related parties				0
Long-term debt, net of current maturities	0			0
Total liabilities	(405,895)			(1,908,817)
Stockholders’ equity:
Common stock	0			0
Paid-in capital	(4,559,541)			(4,438,965)
Accumulated other comprehensive loss	48,898			44,763
Accumulated deficit	2,700,856			1,333,683
Total stockholders’ equity	(1,809,787)			(3,060,519)
Total liabilities and stockholders’ equity	$ (2,215,682)			$ (4,969,336)

CONDENSED CONSOLIDATING FINAN_4

CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Statements of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
REVENUES:
Total revenues	$ 136,176			$ 341,746			$ 621,815	$ 1,226,658
Costs and expenses:
Lease operating expenses	15,274			22,473			46,946	64,668
Production taxes	4,028			6,565			12,432	22,584
Midstream gathering and processing expenses	110,567			135,006			334,789	382,643
Depreciation, depletion and amortization	51,551			163,270			194,369	406,654
Impairment of oil and natural gas properties	270,874			571,442			1,357,099	571,442
General and administrative expenses	20,524			13,198			46,546	34,982
Restructuring and liability management	8,984			0			9,601	0
Accretion expense	774			747			2,270	3,173
Total Operating Expenses	482,576			912,701			2,004,052	1,486,146
LOSS FROM OPERATIONS	(346,400)			(570,955)			(1,382,237)	(259,488)
OTHER EXPENSE (INCOME):
Interest expense	34,321			35,556			99,677	107,595
Interest income	(52)			(338)			(282)	(649)
Gain on debt extinguishment	0			(23,600)			(49,579)	(23,600)
Loss from equity method investments and investments in subsidiaries	153			43,082			10,987	164,391
Other (income) expense	141			3,194			9,239	3,757
Total Other Expense	34,563			57,894			70,042	251,494
LOSS BEFORE INCOME TAXES	(380,963)			(628,849)			(1,452,279)	(510,982)
INCOME TAX EXPENSE	0			(144,047)			7,290	(323,378)
NET LOSS	(380,963)	$ (561,068)	$ (517,538)	(484,802)	$ 234,956	$ 62,242	(1,459,569)	(187,604)
Reportable Legal Entities | Parent
REVENUES:
Total revenues	(53,823)			27,358			71,415	493,895
Costs and expenses:
Lease operating expenses	(157)			(231)			(157)	26,918
Production taxes	0			36			0	6,117
Midstream gathering and processing expenses	0			0			0	71,420
Depreciation, depletion and amortization	2,265			2,686			7,155	201,250
Impairment of oil and natural gas properties	0			0			0	0
General and administrative expenses	29,454			25,757			75,214	51,695
Restructuring and liability management	8,984						9,601
Accretion expense	0			0			0	1,389
Total Operating Expenses	40,546			28,248			91,813	358,789
LOSS FROM OPERATIONS	(94,369)			(890)			(20,398)	135,106
OTHER EXPENSE (INCOME):
Interest expense	34,488			36,566			100,490	109,864
Interest income	(16)			(187)			(103)	(454)
Gain on debt extinguishment				(23,600)			(49,579)	(23,600)
Loss from equity method investments and investments in subsidiaries	251,951			616,348			1,377,819	560,883
Other (income) expense	172			(1,168)			3,255	(605)
Total Other Expense	286,595			627,959			1,431,882	646,088
LOSS BEFORE INCOME TAXES	(380,964)			(628,849)			(1,452,280)	(510,982)
INCOME TAX EXPENSE	0			(144,047)			7,290	(323,378)
NET LOSS	(380,964)			(484,802)			(1,459,570)	(187,604)
Reportable Legal Entities | Guarantors
REVENUES:
Total revenues	189,999			314,388			550,400	732,763
Costs and expenses:
Lease operating expenses	15,431			22,704			47,103	37,750
Production taxes	4,028			6,529			12,432	16,467
Midstream gathering and processing expenses	110,567			135,006			334,789	311,223
Depreciation, depletion and amortization	49,120			160,418			186,716	205,183
Impairment of oil and natural gas properties	270,874			571,442			1,357,099	571,442
General and administrative expenses	(9,098)			(12,675)			(29,122)	(16,933)
Restructuring and liability management	0						0
Accretion expense	774			747			2,270	1,784
Total Operating Expenses	441,696			884,171			1,911,287	1,126,916
LOSS FROM OPERATIONS	(251,697)			(569,783)			(1,360,887)	(394,153)
OTHER EXPENSE (INCOME):
Interest expense	(167)			(1,010)			(813)	(2,269)
Interest income	(36)			(151)			(179)	(195)
Gain on debt extinguishment				0			0	0
Loss from equity method investments and investments in subsidiaries	0			0			0	0
Other (income) expense	(31)			3,362			5,984	3,362
Total Other Expense	(234)			2,201			4,992	898
LOSS BEFORE INCOME TAXES	(251,463)			(571,984)			(1,365,879)	(395,051)
INCOME TAX EXPENSE	0			0			0	0
NET LOSS	(251,463)			(571,984)			(1,365,879)	(395,051)
Reportable Legal Entities | Non-Guarantors
REVENUES:
Total revenues	0			0			0	0
Costs and expenses:
Lease operating expenses	0			0			0	0
Production taxes	0			0			0	0
Midstream gathering and processing expenses	0			0			0	0
Depreciation, depletion and amortization	166			166			498	221
Impairment of oil and natural gas properties	0			0			0	0
General and administrative expenses	168			116			454	220
Restructuring and liability management	0						0
Accretion expense	0			0			0	0
Total Operating Expenses	334			282			952	441
LOSS FROM OPERATIONS	(334)			(282)			(952)	(441)
OTHER EXPENSE (INCOME):
Interest expense	0			0			0	0
Interest income	0			0			0	0
Gain on debt extinguishment				0			0	0
Loss from equity method investments and investments in subsidiaries	153			40			341	379
Other (income) expense	0			0			0	0
Total Other Expense	153			40			341	379
LOSS BEFORE INCOME TAXES	(487)			(322)			(1,293)	(820)
INCOME TAX EXPENSE	0			0			0	0
NET LOSS	(487)			(322)			(1,293)	(820)
Eliminations
REVENUES:
Total revenues	0			0			0	0
Costs and expenses:
Lease operating expenses	0			0			0	0
Production taxes	0			0			0	0
Midstream gathering and processing expenses	0			0			0	0
Depreciation, depletion and amortization	0			0			0	0
Impairment of oil and natural gas properties	0			0			0	0
General and administrative expenses	0			0			0	0
Restructuring and liability management	0						0
Accretion expense	0			0			0	0
Total Operating Expenses	0			0			0	0
LOSS FROM OPERATIONS	0			0			0	0
OTHER EXPENSE (INCOME):
Interest expense	0			0			0	0
Interest income	0			0			0	0
Gain on debt extinguishment				0			0	0
Loss from equity method investments and investments in subsidiaries	(251,951)			(573,306)			(1,367,173)	(396,871)
Other (income) expense	0			1,000			0	1,000
Total Other Expense	(251,951)			(572,306)			(1,367,173)	(395,871)
LOSS BEFORE INCOME TAXES	251,951			572,306			1,367,173	395,871
INCOME TAX EXPENSE	0			0			0	0
NET LOSS	$ 251,951			$ 572,306			$ 1,367,173	$ 395,871

CONDENSED CONSOLIDATING FINAN_5

CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Statements of Comprehensive Income (Loss)) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Condensed Financial Statements, Captions [Line Items]
Net loss	$ (380,963)	$ (561,068)	$ (517,538)	$ (484,802)	$ 234,956	$ 62,242	$ (1,459,569)	$ (187,604)
Foreign currency translation adjustment	3,661			(2,064)			(4,497)	5,347
Other Comprehensive Income (Loss)	3,661	$ 6,872	$ (15,030)	(2,064)	$ 3,610	$ 3,801	(4,497)	5,347
Comprehensive (loss) income	(377,302)			(486,866)			(1,464,066)	(182,257)
Reportable Legal Entities | Parent
Condensed Financial Statements, Captions [Line Items]
Net loss	(380,964)			(484,802)			(1,459,570)	(187,604)
Foreign currency translation adjustment	3,661			(2,064)			(4,497)	5,347
Other Comprehensive Income (Loss)	3,661			(2,064)			(4,497)	5,347
Comprehensive (loss) income	(377,303)			(486,866)			(1,464,067)	(182,257)
Reportable Legal Entities | Guarantors
Condensed Financial Statements, Captions [Line Items]
Net loss	(251,463)			(571,984)			(1,365,879)	(395,051)
Foreign currency translation adjustment	0			(43)			(360)	112
Other Comprehensive Income (Loss)	0			(43)			(360)	112
Comprehensive (loss) income	(251,463)			(572,027)			(1,366,239)	(394,939)
Reportable Legal Entities | Non-Guarantors
Condensed Financial Statements, Captions [Line Items]
Net loss	(487)			(322)			(1,293)	(820)
Foreign currency translation adjustment	3,661			(2,021)			(4,137)	5,235
Other Comprehensive Income (Loss)	3,661			(2,021)			(4,137)	5,235
Comprehensive (loss) income	3,174			(2,343)			(5,430)	4,415
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net loss	251,951			572,306			1,367,173	395,871
Foreign currency translation adjustment	(3,661)			2,064			4,497	(5,347)
Other Comprehensive Income (Loss)	(3,661)			2,064			4,497	(5,347)
Comprehensive (loss) income	$ 248,290			$ 574,370			$ 1,371,670	$ 390,524

CONDENSED CONSOLIDATING FINAN_6

CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Cash Flows) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	$ 200,001	$ 617,355
Net cash used in investing activities	(290,696)	(638,648)
Net cash (used in) provided by financing activities	135,678	(20,880)
Net (decrease) increase in cash, cash equivalents and restricted cash	44,983	(42,173)
Cash, cash equivalents and restricted cash at beginning of period	6,060	52,297
Cash, cash equivalents and restricted cash at end of period	51,043	10,124
Reportable Legal Entities | Parent
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(95,023)	(7,604)
Net cash used in investing activities	351	9,178
Net cash (used in) provided by financing activities	135,678	(20,880)
Net (decrease) increase in cash, cash equivalents and restricted cash	41,006	(19,306)
Cash, cash equivalents and restricted cash at beginning of period	2,768	25,585
Cash, cash equivalents and restricted cash at end of period	43,774	6,279
Reportable Legal Entities | Guarantors
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	290,147	621,511
Net cash used in investing activities	(291,047)	(644,507)
Net cash (used in) provided by financing activities	0	0
Net (decrease) increase in cash, cash equivalents and restricted cash	(900)	(22,996)
Cash, cash equivalents and restricted cash at beginning of period	3,097	26,711
Cash, cash equivalents and restricted cash at end of period	2,197	3,715
Reportable Legal Entities | Non-Guarantors
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	4,442	3,445
Net cash used in investing activities	0	(3,751)
Net cash (used in) provided by financing activities	435	435
Net (decrease) increase in cash, cash equivalents and restricted cash	4,877	129
Cash, cash equivalents and restricted cash at beginning of period	195	1
Cash, cash equivalents and restricted cash at end of period	5,072	130
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	435	3
Net cash used in investing activities	0	432
Net cash (used in) provided by financing activities	(435)	(435)
Net (decrease) increase in cash, cash equivalents and restricted cash	0	0
Cash, cash equivalents and restricted cash at beginning of period	0	0
Cash, cash equivalents and restricted cash at end of period	$ 0	$ 0

SUBSEQUENT EVENT (Narrative) (D

SUBSEQUENT EVENT (Narrative) (Details) - Subsequent Event - Senior Notes - USD ($) $ in Millions	Nov. 02, 2020	Oct. 15, 2020
6.000% senior unsecured notes due 2024
Subsequent Event [Line Items]
Debt instrument, interest		$ 17.4
6.625% senior unsecured notes due 2023
Subsequent Event [Line Items]
Debt instrument, interest	$ 10.8