Stone Energy (SGY) 10-Q 1 Nov 17 2017 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Nov. 01, 2017
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q3
Trading Symbol	SGY
Entity Registrant Name	STONE ENERGY CORP
Entity Central Index Key	904,080
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		19,999,112

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEET - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 245,714
Restricted cash	37,684
Accounts receivable	35,670
Fair value of derivative contracts	2,565
Current income tax receivable	27,672
Other current assets	9,295
Total current assets	358,600
Oil and gas properties, full cost method of accounting:
Proved	714,515
Less: accumulated depreciation, depletion and amortization	(330,921)
Net proved oil and gas properties	383,594
Unevaluated	102,283
Other property and equipment, net	18,433
Fair value of derivative contracts	1,040
Other assets, net	18,252
Total assets	882,202
Current liabilities:
Accounts payable to vendors	33,120
Undistributed oil and gas proceeds	5,439
Accrued interest	10,244
Fair value of derivative contracts	368
Asset retirement obligations	84,654
Current portion of long-term debt	421
Other current liabilities	28,503
Total current liabilities	162,749
Long-term debt	235,567
Asset retirement obligations	182,956
Fair value of derivative contracts	74
Other long-term liabilities	10,110
Total liabilities not subject to compromise	591,456
Liabilities subject to compromise	0
Total liabilities	591,456
Commitments and contingencies
Stockholders’ equity:
Common stock, value	200
Additional paid-in capital	555,323
Accumulated deficit	(264,777)
Total stockholders’ equity	290,746
Total liabilities and stockholders’ equity	$ 882,202
Predecessor
Current assets:
Cash and cash equivalents		$ 190,581
Restricted cash		0
Accounts receivable		48,464
Fair value of derivative contracts		0
Current income tax receivable		26,086
Other current assets		10,151
Total current assets		275,282
Oil and gas properties, full cost method of accounting:
Proved		9,616,236
Less: accumulated depreciation, depletion and amortization		(9,178,442)
Net proved oil and gas properties		437,794
Unevaluated		373,720
Other property and equipment, net		26,213
Fair value of derivative contracts		0
Other assets, net		26,474
Total assets		1,139,483
Current liabilities:
Accounts payable to vendors		19,981
Undistributed oil and gas proceeds		15,073
Accrued interest		809
Fair value of derivative contracts		0
Asset retirement obligations		88,000
Current portion of long-term debt		408
Other current liabilities		18,602
Total current liabilities		142,873
Long-term debt		352,376
Asset retirement obligations		154,019
Fair value of derivative contracts		0
Other long-term liabilities		17,315
Total liabilities not subject to compromise		666,583
Liabilities subject to compromise		1,110,182
Total liabilities		1,776,765
Commitments and contingencies
Stockholders’ equity:
Common stock, value		56
Predecessor treasury stock (1,658 shares, at cost)		(860)
Additional paid-in capital		1,659,731
Accumulated deficit		(2,296,209)
Total stockholders’ equity		(637,282)
Total liabilities and stockholders’ equity		$ 1,139,483

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Sep. 30, 2017	Dec. 31, 2016
Common stock, par value (in usd per share)	$ 0.01
Common stock, shares authorized (in shares)	60,000,000
Common stock, shares issued (in shares)	19,998,019
Predecessor
Common stock, par value (in usd per share)		$ 0.01
Common stock, shares authorized (in shares)		30,000,000
Common stock, shares issued (in shares)		5,610,020
Treasury stock, shares (in shares)		1,658

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	2 Months Ended	3 Months Ended		7 Months Ended	9 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Operating revenue:
Oil production		$ 61,841		$ 143,556
Natural gas production		5,451		14,201
Natural gas liquids production		2,473		6,264
Other operational income		9,760		9,936
Derivative income, net				1,414
Total operating revenue		79,525		175,371
Operating expenses:
Lease operating expenses		11,778		33,154
Transportation, processing and gathering expenses		1,076		3,045
Production taxes		188		446
Depreciation, depletion and amortization		27,553		76,553
Write-down of oil and gas properties		0		256,435
Accretion expense		8,095		19,698
Salaries, general and administrative expenses		15,887		37,718
Incentive compensation expense		4,646		4,646
Restructuring fees		129		739
Other operational expenses		703		3,292
Derivative expense, net		6,685		0
Total operating expenses		76,740		435,726
Gain (loss) on Appalachia Properties divestiture		(132)		(105)
Income (loss) from operations		2,653		(260,460)
Other (income) expense:
Interest expense		3,529		8,320
Interest income		(366)		(575)
Other income		(276)		(719)
Other expense		47		861
Reorganization items, net				0
Total other expense		2,934		7,887
Loss before income taxes		(281)		(268,347)
Provision (benefit) for income taxes:
Current		(1,578)		(3,570)
Deferred		0		0
Total income taxes		(1,578)		(3,570)
Net income (loss)		$ 1,297		$ (264,777)
Basic income (loss) per share (in usd per share)		$ 0.06		$ (13.24)
Diluted income (loss) per share (in usd per share)		$ 0.06		$ (13.24)
Average shares outstanding (in shares)		19,997		19,997
Average shares outstanding assuming dilution (in shares)		19,997		19,997
Predecessor
Operating revenue:
Oil production	$ 45,837		$ 71,116		$ 204,102
Natural gas production	13,476		15,601		43,327
Natural gas liquids production	8,706		6,666		15,119
Other operational income	903		1,044		1,737
Derivative income, net	0				0
Total operating revenue	68,922		94,427		264,285
Operating expenses:
Lease operating expenses	8,820		16,976		55,349
Transportation, processing and gathering expenses	6,933		10,633		18,657
Production taxes	682		835		1,894
Depreciation, depletion and amortization	37,429		58,918		166,707
Write-down of oil and gas properties	0		36,484		284,337
Accretion expense	5,447		10,082		30,147
Salaries, general and administrative expenses	9,629		15,425		48,193
Incentive compensation expense	2,008		2,160		11,809
Restructuring fees	0		5,784		16,173
Other operational expenses	530		9,059		49,266
Derivative expense, net	1,778		199		687
Total operating expenses	73,256		166,555		683,219
Gain (loss) on Appalachia Properties divestiture	213,453		0		0
Income (loss) from operations	209,119		(72,128)		(418,934)
Other (income) expense:
Interest expense	0		16,924		49,764
Interest income	(45)		(58)		(474)
Other income	(315)		(272)		(840)
Other expense	13,336		16		27
Reorganization items, net	(437,744)				0
Total other expense	(424,768)		16,610		48,477
Loss before income taxes	633,887		(88,738)		(467,411)
Provision (benefit) for income taxes:
Current	3,570		(991)		(4,178)
Deferred	0		1,888		10,947
Total income taxes	3,570		897		6,769
Net income (loss)	$ 630,317		$ (89,635)		$ (474,180)
Basic income (loss) per share (in usd per share)	$ 110.99		$ (16.01)		$ (84.90)
Diluted income (loss) per share (in usd per share)	$ 110.99		$ (16.01)		$ (84.90)
Average shares outstanding (in shares)	5,634		5,600		5,585
Average shares outstanding assuming dilution (in shares)	5,634		5,600		5,585

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	2 Months Ended	3 Months Ended		7 Months Ended	9 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Net income (loss)		$ (1,297)		$ 264,777
Other comprehensive loss, net of tax effect:
Derivatives		0		0
Foreign currency translation				0
Comprehensive income (loss)		$ 1,297		$ (264,777)
Predecessor
Net income (loss)	$ (630,317)		$ 89,635		$ 474,180
Other comprehensive loss, net of tax effect:
Derivatives	0		(3,467)		(20,107)
Foreign currency translation	0				6,073
Comprehensive income (loss)	$ 630,317		$ (93,102)		$ (488,214)

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY - USD ($)	Total	Common Stock	Treasury Stock	Additional Paid-In Capital	Accumulated Deficit	Accumulated Other Comprehensive Income (Loss)
Beginning Balance (Predecessor) at Dec. 31, 2015	$ (39,789,000)	$ 55,000	$ (860,000)	$ 1,648,687,000	$ (1,705,623,000)	$ 17,952,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) | Predecessor	(590,586,000)				(590,586,000)
Adjustment for fair value accounting of derivatives, net of tax | Predecessor	(24,025,000)					(24,025,000)
Adjustment for foreign currency translation, net of tax | Predecessor	6,073,000					6,073,000
Exercise of stock options, vesting of restricted stock and granting of stock awards | Predecessor	(731,000)	1,000		(732,000)
Amortization of stock compensation expense | Predecessor	11,776,000			11,776,000
Ending Balance (Predecessor) at Dec. 31, 2016	(637,282,000)	56,000	(860,000)	1,659,731,000	(2,296,209,000)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) | Predecessor	630,317,000				630,317,000
Adjustment for fair value accounting of derivatives, net of tax | Predecessor	0
Adjustment for foreign currency translation, net of tax | Predecessor	0
Exercise of stock options, vesting of restricted stock and granting of stock awards | Predecessor	(172,000)			(172,000)
Amortization of stock compensation expense | Predecessor	3,527,000			3,527,000
Issuance of Successor common stock and warrants	554,628,000	200,000		554,428,000
Ending Balance (Predecessor) at Feb. 28, 2017	(3,610,000)	56,000	(860,000)	1,663,086,000	(1,665,892,000)	0
Ending Balance at Feb. 28, 2017	554,628,000	200,000		554,428,000	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cancellation of Predecessor equity | Predecessor	3,610,000	(56,000)	$ 860,000	(1,663,086,000)	1,665,892,000
Net income (loss)	(264,777,000)				(264,777,000)
Adjustment for fair value accounting of derivatives, net of tax	0
Adjustment for foreign currency translation, net of tax	0
Exercise of stock options, vesting of restricted stock and granting of stock awards	(19,000)			(19,000)
Amortization of stock compensation expense	914,000			914,000
Ending Balance at Sep. 30, 2017	$ 290,746,000	$ 200,000		$ 555,323,000	$ (264,777,000)	$ 0

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS - USD ($) $ in Thousands	2 Months Ended	7 Months Ended	9 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016
Cash flows from operating activities:
Net income (loss)		$ (264,777)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		76,553
Write-down of oil and gas properties		256,435
Accretion expense		19,698
Deferred income tax provision		0
(Gain) loss on sale of oil and gas properties		105
Settlement of asset retirement obligations		(53,129)
Non-cash stock compensation expense		893
Non-cash derivative expense		1,210
Non-cash interest expense		3
Non-cash reorganization items		0
Other non-cash expense		877
Change in current income taxes		(5,156)
Decrease in accounts receivable		6,059
(Increase) decrease in other current assets		2,382
Increase (decrease) in accounts payable		10,662
Increase (decrease) in other current liabilities		17,944
Investment in derivative contracts		(2,416)
Other		3,054
Net cash provided by (used in) operating activities		70,397
Cash flows from investing activities:
Investment in oil and gas properties		(42,837)
Proceeds from sale of oil and gas properties, net of expenses		17,777
Investment in fixed and other assets		(158)
Change in restricted funds		37,863
Net cash provided by (used in) investing activities		12,645
Cash flows from financing activities:
Proceeds from bank borrowings		0
Repayments of bank borrowings		0
Repayments of building loan		(275)
Cash payment to noteholders		0
Debt issuance costs		0
Net payments for share-based compensation		(19)
Net cash provided by (used in) financing activities		(294)
Effect of exchange rate changes on cash		0
Net change in cash and cash equivalents		82,748
Cash and cash equivalents, beginning of period		162,966
Cash and cash equivalents, end of period	$ 162,966	245,714
Predecessor
Cash flows from operating activities:
Net income (loss)	630,317		$ (474,180)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	37,429		166,707
Write-down of oil and gas properties	0		284,337
Accretion expense	5,447		30,147
Deferred income tax provision	0		10,947
(Gain) loss on sale of oil and gas properties	(213,453)		0
Settlement of asset retirement obligations	(3,641)		(15,106)
Non-cash stock compensation expense	2,645		6,407
Non-cash derivative expense	1,778		1,261
Non-cash interest expense	0		14,278
Non-cash reorganization items	(458,677)		0
Other non-cash expense	172		6,081
Change in current income taxes	3,570		21,584
Decrease in accounts receivable	6,354		3,968
(Increase) decrease in other current assets	(2,274)		(4,426)
Increase (decrease) in accounts payable	(4,652)		3,217
Increase (decrease) in other current liabilities	(9,653)		(14,222)
Investment in derivative contracts	(3,736)		0
Other	2,490		(8,107)
Net cash provided by (used in) operating activities	(5,884)		32,893
Cash flows from investing activities:
Investment in oil and gas properties	(8,754)		(200,622)
Proceeds from sale of oil and gas properties, net of expenses	505,383		0
Investment in fixed and other assets	(61)		(1,231)
Change in restricted funds	(75,547)		1,046
Net cash provided by (used in) investing activities	421,021		(200,807)
Cash flows from financing activities:
Proceeds from bank borrowings	0		477,000
Repayments of bank borrowings	(341,500)		(135,500)
Repayments of building loan	(24)		(285)
Cash payment to noteholders	(100,000)		0
Debt issuance costs	(1,055)		(900)
Net payments for share-based compensation	(173)		(752)
Net cash provided by (used in) financing activities	(442,752)		339,563
Effect of exchange rate changes on cash	0		(9)
Net change in cash and cash equivalents	(27,615)		171,640
Cash and cash equivalents, beginning of period	190,581	$ 162,966	10,759
Cash and cash equivalents, end of period	$ 162,966		$ 182,399

FINANCIAL STATEMENT PRESENTATIO

FINANCIAL STATEMENT PRESENTATION	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
FINANCIAL STATEMENT PRESENTATION	FINANCIAL STATEMENT PRESENTATION Interim Financial Statements The condensed consolidated financial statements of Stone Energy Corporation (“Stone” or the “Company”) and its subsidiaries as of September 30, 2017 (Successor) and for the three month period ended September 30, 2017 (Successor), the periods from March 1, 2017 through September 30, 2017 (Successor), January 1, 2017 through February 28, 2017 (Predecessor) and the three and nine months ended September 30, 2016 (Predecessor) are unaudited and reflect all adjustments (consisting only of normal recurring adjustments), which are, in the opinion of management, necessary for a fair presentation of the financial position and operating results for the interim periods. The condensed consolidated balance sheet as of December 31, 2016 (Predecessor) has been derived from the audited financial statements as of that date contained in our Annual Report on Form 10-K for the year ended December 31, 2016 (our “ 2016 Annual Report on Form 10-K”). The condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto, together with management’s discussion and analysis of financial condition and results of operations, contained in our 2016 Annual Report on Form 10-K, although, as described below, such prior financial statements will not be comparable to the interim financial statements due to the adoption of fresh start accounting on February 28, 2017. For additional information, see Note 3 – Fresh Start Accounting . The results of operations for the period from March 1, 2017 through September 30, 2017 (Successor) are not necessarily indicative of future financial results. Certain prior period amounts have been reclassified to conform to current period presentation. Emergence from Voluntary Reorganization Under Chapter 11 Proceedings On December 14, 2016, the Company and its subsidiaries Stone Energy Offshore, L.L.C. (“Stone Offshore”) and Stone Energy Holding, L.L.C. (together with the Company, the “Debtors”) filed voluntary petitions (the “Bankruptcy Petitions”) in the United States Bankruptcy Court for the Southern District of Texas, Houston Division (the “Bankruptcy Court”) seeking relief under the provisions of Chapter 11 of Title 11 (“Chapter 11”) of the United States Bankruptcy Code (the “Bankruptcy Code”). On February 15, 2017, the Bankruptcy Court entered an order (the “Confirmation Order”) confirming the Second Amended Joint Prepackaged Plan of Reorganization of Stone Energy Corporation and its Debtor Affiliates, dated December 28, 2016 (the “Plan”), as modified by the Confirmation Order, and on February 28, 2017, the Plan became effective (the “Effective Date”) and the Debtors emerged from bankruptcy, with the bankruptcy cases then being closed by Final Decree Closing Chapter 11 Cases and Terminating Claims Agent Services entered by the Bankruptcy Court on April 20, 2017. Upon emergence from bankruptcy, the Company adopted fresh start accounting in accordance with the provisions of Accounting Standards Codification (“ASC”) 852, “ Reorganizations ”, which resulted in the Company becoming a new entity for financial reporting purposes on the Effective Date. As a result of the adoption of fresh start accounting, the Company’s unaudited condensed consolidated financial statements subsequent to February 28, 2017 will not be comparable to its financial statements prior to that date. See Note 3 – Fresh Start Accounting for further details on the impact of fresh start accounting on the Company’s unaudited condensed consolidated financial statements. References to “Successor” or “Successor Company” relate to the financial position and results of operations of the reorganized Company subsequent to February 28, 2017. References to “Predecessor” or “Predecessor Company” relate to the financial position and results of operations of the Company prior to, and including, February 28, 2017. Use of Estimates The preparation of financial statements in conformity with U.S. Generally Accepted Accounting Principles requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates on historical experience and on various other assumptions and information believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects are uncertain and, accordingly, these estimates may change as new events occur, as additional information is obtained and as the Company’s operating environment changes. Actual results could differ from those estimates. Estimates are used primarily when accounting for depreciation, depletion and amortization (“DD&A”) expense, unevaluated property costs, estimated future net cash flows from proved reserves, costs to abandon oil and gas properties, income taxes, accruals of capitalized costs, operating costs and production revenue, capitalized general and administrative costs and interest, insurance recoveries, estimated fair value of derivative contracts, contingencies and fair value estimates, including estimates of reorganization value, enterprise value and the fair value of assets and liabilities recorded as a result of the adoption of fresh start accounting. Recently Issued Accounting Standards In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “ Revenue from Contracts with Customers (Topic 606) ” to clarify the principles for recognizing revenue and to develop a common revenue standard and disclosure requirements. The standard may be applied retrospectively or using a modified retrospective approach, with the cumulative effect of initially applying ASU 2014-09 recognized at the date of initial application. In August 2015, the FASB issued ASU 2015-14, deferring the effective date of ASU 2014-09 by one year. As a result, the standard is effective for interim and annual periods beginning on or after December 15, 2017. We expect to apply the modified retrospective approach upon adoption of this standard. Although we are still evaluating the effect that this new standard may have on our financial statements and related disclosures, we do not anticipate that the implementation of this new standard will have a material effect. In February 2016, the FASB issued ASU 2016-02, “ Leases (Topic 842) ” to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The standard is effective for public entities for fiscal years beginning after December 15, 2018, and for interim periods within those fiscal years, with earlier application permitted. Upon adoption the lessee will apply the new standard retrospectively to all periods presented or retrospectively using a cumulative effect adjustment in the year of adoption. We are currently evaluating the effect that this new standard may have on our financial statements and related disclosures. In March 2016, the FASB issued ASU 2016-09, “ Compensation – Stock Compensation (Topic 718) ” to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and forfeitures, as well as classification in the statement of cash flows. ASU 2016-09 became effective for us on January 1, 2017. Under ASU 2016-09, the Company elected to not apply a forfeiture estimate and will recognize a credit in compensation expense to the extent awards are forfeited. The implementation of this new standard did not have a material effect on our financial statements or related disclosures. In August 2017, the FASB issued ASU 2017-12, “ Derivatives and Hedging (Topic 815) ” to improve the financial reporting of hedging relationships to better reflect an entity’s hedging strategies. The standard expands an entity’s ability to apply hedge accounting for both non-financial and financial risk components and amends the presentation and disclosure requirements. Additionally, ASU 2017-12 eliminates the need to separately measure and report hedge ineffectiveness and generally requires the entire change in fair value of a hedging instrument to be recorded in the same income statement line as the earnings effect of the hedged item. The standard is effective for public companies for fiscal years beginning after December 15, 2018 and interim periods within those fiscal years. Early adoption is permitted. The standard must be adopted by applying a modified retrospective approach to existing designated hedging relationships as of the adoption date, with a cumulative effect adjustment recorded to opening retained earnings as of the initial adoption date. We are currently evaluating the effect that this new standard may have on our financial statements and related disclosures.

REORGANIZATION

REORGANIZATION	9 Months Ended
	Sep. 30, 2017
Reorganizations [Abstract]
REORGANIZATION	REORGANIZATION On December 14, 2016, the Debtors filed Bankruptcy Petitions seeking relief under the provisions of Chapter 11 of the Bankruptcy Code to pursue a prepackaged plan of reorganization. On February 15, 2017, the Bankruptcy Court entered an order confirming the Plan, and on February 28, 2017, the Plan became effective and the Debtors emerged from bankruptcy. Prior to the filing of the Bankruptcy Petitions, the Debtors and certain holders of the 1 3 ⁄ 4 % Senior Convertible Notes due 2017 (the “2017 Convertible Notes”) and the 7 1 ⁄ 2 % Senior Notes due 2022 (the “2022 Notes”) (collectively, the “Notes” and the holders thereof, the “Noteholders”) and the lenders (the “Banks”) under the Fourth Amended and Restated Credit Agreement, dated as of June 24, 2014, as amended, modified, or otherwise supplemented from time to time (the “Pre-Emergence Credit Agreement”), entered into an Amended and Restated Restructuring Support Agreement (the “A&R RSA”). The A&R RSA contained certain covenants on the part of the Company and the Noteholders and Banks who are signatories to the A&R RSA, including that such Noteholders and Banks would support the Company’s sale of Stone’s producing properties and acreage, including approximately 86,000 net acres, in the Appalachia regions of Pennsylvania and West Virginia (the “Appalachia Properties”) to TH Exploration III, LLC, an affiliate of Tug Hill, Inc. (“Tug Hill”), pursuant to the terms of a Purchase and Sale Agreement dated October 20, 2016, as amended on December 9, 2016 (the “Tug Hill PSA”) for a purchase price of at least $350 million and approval of the Bankruptcy Court. Pursuant to the terms of the Tug Hill PSA, Stone agreed to sell the Appalachia Properties to Tug Hill for $360 million in cash, subject to customary purchase price adjustments. Pursuant to Bankruptcy Court orders dated January 11, 2017 and January 31, 2017, two additional bidders were allowed to participate in competitive bidding on the Appalachia Properties. On January 18, 2017, the Bankruptcy Court approved certain bidding procedures (the “Bidding Procedures”) in connection with the sale of the Appalachia Properties. In accordance with the Bidding Procedures, Stone conducted an auction for the sale of the Appalachia Properties on February 8, 2017 and upon conclusion, selected the final bid submitted by EQT Corporation, through its wholly-owned subsidiary EQT Production Company (“EQT”), with a final purchase price of $527 million in cash, subject to customary purchase price adjustments and approval by the Bankruptcy Court, with an upward adjustment to the purchase price of up to $16 million in an amount equal to certain downward adjustments, as the prevailing bid. On February 9, 2017, the Company entered into a purchase and sale agreement with EQT (the “EQT PSA”), reflecting the terms of the prevailing bid and on February 10, 2017, the Bankruptcy Court entered a sale order approving the sale of the Appalachia Properties to EQT. We completed the sale of the Appalachia Properties to EQT on February 27, 2017 for a final purchase price of $527 million in cash, subject to customary purchase price adjustments. At the close of the sale of the Appalachia Properties, the Tug Hill PSA was terminated, and the Company used a portion of the cash consideration received to pay Tug Hill a break-up fee and expense reimbursements totaling approximately $11.5 million , which is recognized as other expense in the statement of operations for the period of January 1, 2017 through February 28, 2017 (Predecessor). See Note 7 – Divestiture for additional information on the sale of the Appalachia Properties. Upon emergence from bankruptcy, pursuant to the terms of the Plan, the following significant transactions occurred: • Shares of the Predecessor Company’s issued and outstanding common stock immediately prior to the Effective Date were cancelled, and on the Effective Date, reorganized Stone issued an aggregate of 20.0 million shares of new common stock (the “New Common Stock”). • The Predecessor Company’s 2022 Notes and 2017 Convertible Notes were cancelled and the holders of such notes received their pro rata share of (a) $100 million of cash, (b) 19.0 million shares of the New Common Stock, representing 95% of the New Common Stock and (c) $225 million of 7.5% Senior Second Lien Notes due 2022 (the “2022 Second Lien Notes”). • The Predecessor Company’s common stockholders received their pro rata share of 1.0 million shares of the New Common Stock, representing 5% of the New Common Stock, and warrants to purchase approximately 3.5 million shares of New Common Stock. The warrants have an exercise price of $42.04 per share and a term of four years , unless terminated earlier by their terms upon the consummation of certain business combinations or sale transactions involving the Company. • The Predecessor Company’s Pre-Emergence Credit Agreement was amended and restated as the Amended Credit Agreement (as defined in Note 10 – Debt ). The obligations owed to the lenders under the Pre-Emergence Credit Agreement were converted to obligations under the Amended Credit Agreement. • All claims of creditors with unsecured claims, other than the claims by the holders of the 2022 Notes and 2017 Convertible Notes, including vendors, were unaltered and paid in full in the ordinary course of business to the extent the claims were undisputed. For further information regarding the equity and debt instruments of the Predecessor Company and the Successor Company, see Note 4 – Stockholders’ Equity and Note 10 – Debt . FRESH START ACCOUNTING Upon emergence from bankruptcy, the Company qualified for and adopted fresh start accounting in accordance with the provisions of ASC 852, “ Reorganizations ” as (i) the holders of existing voting shares of the Predecessor Company received less than 50% of the voting shares of the Successor Company and (ii) the reorganization value of the Company’s assets immediately prior to confirmation of the Plan was less than the post-petition liabilities and allowed claims. See Note 2 – Reorganization for the terms of the Plan. The Company applied fresh start accounting as of February 28, 2017. Fresh start accounting required the Company to present its assets, liabilities and equity as if it were a new entity upon emergence from bankruptcy, with no beginning retained earnings or deficit as of the fresh start reporting date. As described in Note 1 – Financial Statement Presentation , the new entity is referred to as Successor or Successor Company, and includes the financial position and results of operations of the reorganized Company subsequent to February 28, 2017. References to Predecessor or Predecessor Company relate to the financial position and results of operations of the Company prior to, and including, February 28, 2017. Reorganization Value Under fresh start accounting, reorganization value represents the fair value of the Successor Company’s total assets and is intended to approximate the amount a willing buyer would pay for the assets immediately after restructuring. Upon application of fresh start accounting, the Company allocated the reorganization value to its individual assets based on their estimated fair values. The Company’s reorganization value is derived from an estimate of enterprise value. Enterprise value represents the estimated fair value of an entity’s long-term debt and stockholders’ equity. In support of the Plan, the Company estimated the enterprise value of the core assets (as defined in the Plan) of the Successor Company to be in the range of $300 million to $450 million , which was subsequently approved by the Bankruptcy Court. This valuation analysis was prepared using reserve information, development schedules, other financial information and financial projections and applying standard valuation techniques, including net asset value analysis, precedent transactions analyses and public comparable company analyses. Based on the estimates and assumptions used in determining the enterprise value, the Company ultimately estimated the enterprise value of the Successor Company’s core assets to be approximately $420 million . Valuation of Assets The Company’s principal assets are its oil and gas properties, which the Company accounts for under the full cost accounting method. With the assistance of valuation experts, the Company determined the fair value of its oil and gas properties based on the discounted cash flows expected to be generated from these assets. The computations were based on market conditions and reserves in place as of the bankruptcy emergence date. The fair value analysis performed by valuation experts was based on the Company’s estimates of reserves as developed internally by the Company’s reserve engineers. For purposes of estimating the fair value of the Company’s proved, probable and possible reserves, an income approach was used, which estimated fair value based on the anticipated cash flows associated with the Company’s reserves, risked by reserve category and discounted using a weighted average cost of capital of 12.5% . The discount factor was derived from a weighted average cost of capital computation which utilized a blended expected cost of debt and expected returns on equity for similar market participants. Future revenues were based upon forward strip oil and natural gas prices as of the emergence date, adjusted for differentials realized by the Company, and adjusted for a 2% annual escalation after 2021. Development and operating costs were based on the Company’s recent cost trends adjusted for inflation. The discounted cash flow models also included estimates not typically included in proved reserves such as depreciation and income tax expenses. The proved reserve locations were limited to wells expected to be drilled in the Company’s five year development plan. As a result of this analysis, the Company concluded the fair value of its proved reserves was $380.8 million and the fair value of its probable and possible reserves was $16.8 million as of the Effective Date. The Company also reviewed its undeveloped leasehold acreage and inventory. An analysis of comparable market transactions indicated a fair value of undeveloped acreage and inventory totaling $80.2 million . These amounts are reflected in the Fresh Start Adjustments item number 12 below. The fair value of the Company’s asset retirement obligations was estimated at $290.1 million and was based on estimated plugging and abandonment costs as of the Effective Date, adjusted for inflation and discounted at the Successor Company’s credit-adjusted risk free rate of 12% . See further discussion in Fresh Start Adjustments below for details on the specific assumptions used in the valuation of the Company’s various other assets. The following table reconciles the enterprise value per the Plan to the estimated fair value (for fresh start accounting purposes) of the Successor Company’s common stock as of February 28, 2017 (in thousands, except per share value): February 28, 2017 Enterprise value $ 419,720 Plus: Cash and other assets 371,169 Less: Fair value of debt (236,261 ) Less: Fair value of warrants (15,648 ) Fair value of Successor common stock $ 538,980 Shares issued upon emergence 20,000 Per share value $ 26.95 The following table reconciles the enterprise value per the Plan to the estimated reorganization value as of the Effective Date (in thousands): February 28, 2017 Enterprise value $ 419,720 Plus: Cash and other assets 371,169 Plus: Asset retirement obligations (current and long-term) 290,067 Plus: Working capital and other liabilities 58,055 Reorganization value of Successor assets $ 1,139,011 Reorganization value and enterprise value were estimated using numerous projections and assumptions that are inherently subject to significant uncertainties and resolution of contingencies that are beyond our control. Accordingly, the estimates set forth herein are not necessarily indicative of actual outcomes, and there can be no assurance that the estimates, projections or assumptions will be realized. Condensed Consolidated Balance Sheet The adjustments set forth in the following condensed consolidated balance sheet reflect the effects of the transactions contemplated by the Plan and carried out by the Company (reflected in the column “Reorganization Adjustments”) as well as fair value adjustments as a result of the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes highlight methods used to determine fair values or other amounts of the assets and liabilities as well as significant assumptions or inputs. The following table reflects the reorganization and application of ASC 852 on our consolidated balance sheet as of February 28, 2017 (in thousands): Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company Assets Current assets: Cash and cash equivalents $ 198,571 $ (35,605 ) (1) $ — $ 162,966 Restricted cash — 75,547 (1) — 75,547 Accounts receivable 42,808 9,301 (2) — 52,109 Fair value of derivative contracts 1,267 — — 1,267 Current income tax receivable 22,516 — — 22,516 Other current assets 10,924 875 (3) (124 ) (12) 11,675 Total current assets 276,086 50,118 (124 ) 326,080 Oil and gas properties, full cost method of accounting: Proved 9,633,907 (188,933 ) (1) (8,774,122 ) (12) 670,852 Less: accumulated DD&A (9,215,679 ) — 9,215,679 (12) — Net proved oil and gas properties 418,228 (188,933 ) 441,557 670,852 Unevaluated 371,140 (127,838 ) (1) (146,292 ) (12) 97,010 Other property and equipment, net 25,586 (101 ) (4) (4,423 ) (13) 21,062 Fair value of derivative contracts 1,819 — — 1,819 Other assets, net 26,516 (4,328 ) (5) — 22,188 Total assets $ 1,119,375 $ (271,082 ) $ 290,718 $ 1,139,011 Liabilities and Stockholders’ Equity Current liabilities: Accounts payable to vendors $ 20,512 $ — $ — $ 20,512 Undistributed oil and gas proceeds 5,917 (4,139 ) (1) — 1,778 Accrued interest 266 — — 266 Asset retirement obligations 92,597 — — 92,597 Fair value of derivative contracts 476 — — 476 Current portion of long-term debt 411 — — 411 Other current liabilities 17,032 (195 ) (6) — 16,837 Total current liabilities 137,211 (4,334 ) — 132,877 Long-term debt 352,350 (116,500 ) (7) — 235,850 Asset retirement obligations 151,228 (8,672 ) (1) 54,914 (14) 197,470 Fair value of derivative contracts 653 — — 653 Other long-term liabilities 17,533 — — 17,533 Total liabilities not subject to compromise 658,975 (129,506 ) 54,914 584,383 Liabilities subject to compromise 1,110,182 (1,110,182 ) (8) — — Total liabilities 1,769,157 (1,239,688 ) 54,914 584,383 Commitments and contingencies Stockholders’ equity: Common stock (Predecessor) 56 (56 ) (9) — — Treasury stock (Predecessor) (860 ) 860 (9) — — Additional paid-in capital (Predecessor) 1,660,810 (1,660,810 ) (9) — — Common stock (Successor) — 200 (10) — 200 Additional paid-in capital (Successor) — 554,428 (10) — 554,428 Accumulated deficit (2,309,788 ) 2,073,984 (11) 235,804 (15) — Total stockholders’ equity (649,782 ) 968,606 235,804 554,628 Total liabilities and stockholders’ equity $ 1,119,375 $ (271,082 ) $ 290,718 $ 1,139,011 Reorganization Adjustments (dollar amounts in thousands, except per share values) 1. Reflects the net cash proceeds received from the sale of the Appalachia Properties in connection with the Plan and net cash payments made as of the Effective Date from implementation of the Plan: Sources: Net cash proceeds from sale of Appalachia Properties (a) $ 512,472 Total sources 512,472 Uses: Cash transferred to restricted account (b) 75,547 Break-up fee to Tug Hill 10,800 Repayment of outstanding borrowings under Pre-Emergence Credit Agreement 341,500 Repayment of 2017 Convertible Notes and 2022 Notes 100,000 Other fees and expenses (c) 20,230 Total uses 548,077 Net uses $ (35,605 ) (a) The closing of the sale of the Appalachia Properties occurred on February 27, 2017, but as emergence was contingent on such closing, the effects of the transaction are reflected as reorganization adjustments. See Note 7 – Divestiture for additional details on the sale. Total consideration received for the sale of the Appalachia Properties of $522,472 included cash consideration of $512,472 received at closing and a $10,000 indemnity escrow which was released subsequent to emergence from bankruptcy (see Reorganization Adjustments item number 2 below). (b) Reflects the movement of $75,000 of cash held in a restricted account to satisfy near-term plugging and abandonment liabilities, pursuant to the provisions of the Amended Credit Agreement (as defined in Note 10 – Debt ), and $547 held in a restricted cash account for certain cure amounts in connection with the Chapter 11 proceedings. (c) Other fees and expenses include approximately $15,180 of emergence and success fees, $2,600 of professional fees and $2,395 of payments made to seismic providers in settlement of their bankruptcy claims. 2. Reflects a receivable for a $10,000 indemnity escrow with release delayed until emergence from bankruptcy, net of a $699 reimbursement to Tug Hill in connection with the sale of the Appalachia Properties (see Note 7 – Divestiture ). 3. Reflects the payment of a claim to a seismic provider as a prepayment/deposit. 4. Reflects the sale of vehicles in connection with the sale of the Appalachia Properties. 5. Reflects the write-off of $2,577 of unamortized debt issuance costs related to the Pre-Emergence Credit Agreement and the reversal of a $1,750 prepayment made to Tug Hill in October 2016. 6. Reflects the accrual of $2,008 in expected bonus payments under the KEIP (as defined in Note 5 – Share–Based Compensation and Employee Benefit Plans ) and a $395 termination fee in connection with the early termination of an office lease, less the settlement of a property tax accrual of $2,598 in connection with the sale of the Appalachia Properties. 7. Reflects the repayment of $341,500 of outstanding borrowings under the Pre-Emergence Credit Agreement and the issuance of $225,000 of 2022 Second Lien Notes as part of the settlement of the Predecessor Company 2017 Convertible Notes and 2022 Notes. 8. Liabilities subject to compromise were settled as follows in accordance with the Plan: 1 ¾% Senior Convertible Notes due 2017 $ 300,000 7 ½% Senior Notes due 2022 775,000 Accrued interest 35,182 Liabilities subject to compromise of the Predecessor Company 1,110,182 Cash payment to senior noteholders (100,000 ) Issuance of 2022 Second Lien Notes to former holders of the senior notes (225,000 ) Fair value of equity issued to unsecured creditors (538,980 ) Fair value of warrants issued to unsecured creditors (15,648 ) Gain on settlement of liabilities subject to compromise $ 230,554 9. Reflects the cancellation of the Predecessor Company’s common stock, treasury stock and additional paid-in capital. 10. Reflects the issuance of Successor Company equity. In accordance with the Plan, the Successor Company issued 19.0 million shares of New Common Stock to the former holders of the 2017 Convertible Notes and the 2022 Notes and 1.0 million shares of New Common Stock to the Predecessor Company’s common stockholders. These amounts are subject to dilution by warrants issued to the Predecessor Company common stockholders, totaling approximately 3.5 million shares, with an exercise price of $42.04 per share and a term of four years . The fair value of the warrants was estimated at $4.43 per share using a Black-Scholes-Merton valuation model. 11. Reflects the cumulative impact of the reorganization adjustments discussed above: Gain on settlement of liabilities subject to compromise $ 230,554 Professional and other fees paid at emergence (10,648 ) Write-off of unamortized deferred financing costs (2,577 ) Other reorganization adjustments (1,915 ) Net impact to reorganization items 215,414 Gain on sale of Appalachia Properties 213,453 Cancellation of Predecessor Company equity 1,662,282 Other adjustments to accumulated deficit (17,165 ) Net impact to accumulated deficit $ 2,073,984 Fresh Start Adjustments 12. Fair value adjustments to oil and gas properties, associated inventory and unproved acreage. See above for a detailed discussion of the fair value methodology. 13. Fair value adjustment for an office building owned by the Company. The income and sales comparison approaches were used in determining the fair value, using anticipated future earnings and an appropriate expected rate of return, as well as relying upon recent sales or offerings of similar assets. 14. Fair value adjustments to the Company’s asset retirement obligations using estimated plugging and abandonment costs as of the Effective Date, adjusted for inflation and discounted at the Successor Company’s credit-adjusted risk free rate. 15. Reflects the cumulative effect of the fresh start accounting adjustments discussed above. Reorganization Items Reorganization items represent liabilities settled, net of amounts incurred subsequent to the Chapter 11 filing as a direct result of the Plan and are classified as “Reorganization items, net” in the Company’s unaudited condensed consolidated statement of operations. The following table summarizes reorganization items, net (in thousands): Predecessor Period from Gain on settlement of liabilities subject to compromise $ 230,554 Fresh start valuation adjustments 235,804 Reorganization professional fees and other expenses (20,512 ) Write-off of deferred financing costs (2,577 ) Other reorganization items (5,525 ) Gain on reorganization items, net $ 437,744 The cash payments for reorganization items for the period from January 1, 2017 through February 28, 2017 include approximately $10.6 million of emergence and success fees and approximately $9.1 million of other reorganization professional fees and expenses paid on the Effective Date.

FRESH START ACCOUNTING

FRESH START ACCOUNTING	9 Months Ended
	Sep. 30, 2017
Reorganizations [Abstract]
FRESH START ACCOUNTING	REORGANIZATION On December 14, 2016, the Debtors filed Bankruptcy Petitions seeking relief under the provisions of Chapter 11 of the Bankruptcy Code to pursue a prepackaged plan of reorganization. On February 15, 2017, the Bankruptcy Court entered an order confirming the Plan, and on February 28, 2017, the Plan became effective and the Debtors emerged from bankruptcy. Prior to the filing of the Bankruptcy Petitions, the Debtors and certain holders of the 1 3 ⁄ 4 % Senior Convertible Notes due 2017 (the “2017 Convertible Notes”) and the 7 1 ⁄ 2 % Senior Notes due 2022 (the “2022 Notes”) (collectively, the “Notes” and the holders thereof, the “Noteholders”) and the lenders (the “Banks”) under the Fourth Amended and Restated Credit Agreement, dated as of June 24, 2014, as amended, modified, or otherwise supplemented from time to time (the “Pre-Emergence Credit Agreement”), entered into an Amended and Restated Restructuring Support Agreement (the “A&R RSA”). The A&R RSA contained certain covenants on the part of the Company and the Noteholders and Banks who are signatories to the A&R RSA, including that such Noteholders and Banks would support the Company’s sale of Stone’s producing properties and acreage, including approximately 86,000 net acres, in the Appalachia regions of Pennsylvania and West Virginia (the “Appalachia Properties”) to TH Exploration III, LLC, an affiliate of Tug Hill, Inc. (“Tug Hill”), pursuant to the terms of a Purchase and Sale Agreement dated October 20, 2016, as amended on December 9, 2016 (the “Tug Hill PSA”) for a purchase price of at least $350 million and approval of the Bankruptcy Court. Pursuant to the terms of the Tug Hill PSA, Stone agreed to sell the Appalachia Properties to Tug Hill for $360 million in cash, subject to customary purchase price adjustments. Pursuant to Bankruptcy Court orders dated January 11, 2017 and January 31, 2017, two additional bidders were allowed to participate in competitive bidding on the Appalachia Properties. On January 18, 2017, the Bankruptcy Court approved certain bidding procedures (the “Bidding Procedures”) in connection with the sale of the Appalachia Properties. In accordance with the Bidding Procedures, Stone conducted an auction for the sale of the Appalachia Properties on February 8, 2017 and upon conclusion, selected the final bid submitted by EQT Corporation, through its wholly-owned subsidiary EQT Production Company (“EQT”), with a final purchase price of $527 million in cash, subject to customary purchase price adjustments and approval by the Bankruptcy Court, with an upward adjustment to the purchase price of up to $16 million in an amount equal to certain downward adjustments, as the prevailing bid. On February 9, 2017, the Company entered into a purchase and sale agreement with EQT (the “EQT PSA”), reflecting the terms of the prevailing bid and on February 10, 2017, the Bankruptcy Court entered a sale order approving the sale of the Appalachia Properties to EQT. We completed the sale of the Appalachia Properties to EQT on February 27, 2017 for a final purchase price of $527 million in cash, subject to customary purchase price adjustments. At the close of the sale of the Appalachia Properties, the Tug Hill PSA was terminated, and the Company used a portion of the cash consideration received to pay Tug Hill a break-up fee and expense reimbursements totaling approximately $11.5 million , which is recognized as other expense in the statement of operations for the period of January 1, 2017 through February 28, 2017 (Predecessor). See Note 7 – Divestiture for additional information on the sale of the Appalachia Properties. Upon emergence from bankruptcy, pursuant to the terms of the Plan, the following significant transactions occurred: • Shares of the Predecessor Company’s issued and outstanding common stock immediately prior to the Effective Date were cancelled, and on the Effective Date, reorganized Stone issued an aggregate of 20.0 million shares of new common stock (the “New Common Stock”). • The Predecessor Company’s 2022 Notes and 2017 Convertible Notes were cancelled and the holders of such notes received their pro rata share of (a) $100 million of cash, (b) 19.0 million shares of the New Common Stock, representing 95% of the New Common Stock and (c) $225 million of 7.5% Senior Second Lien Notes due 2022 (the “2022 Second Lien Notes”). • The Predecessor Company’s common stockholders received their pro rata share of 1.0 million shares of the New Common Stock, representing 5% of the New Common Stock, and warrants to purchase approximately 3.5 million shares of New Common Stock. The warrants have an exercise price of $42.04 per share and a term of four years , unless terminated earlier by their terms upon the consummation of certain business combinations or sale transactions involving the Company. • The Predecessor Company’s Pre-Emergence Credit Agreement was amended and restated as the Amended Credit Agreement (as defined in Note 10 – Debt ). The obligations owed to the lenders under the Pre-Emergence Credit Agreement were converted to obligations under the Amended Credit Agreement. • All claims of creditors with unsecured claims, other than the claims by the holders of the 2022 Notes and 2017 Convertible Notes, including vendors, were unaltered and paid in full in the ordinary course of business to the extent the claims were undisputed. For further information regarding the equity and debt instruments of the Predecessor Company and the Successor Company, see Note 4 – Stockholders’ Equity and Note 10 – Debt . FRESH START ACCOUNTING Upon emergence from bankruptcy, the Company qualified for and adopted fresh start accounting in accordance with the provisions of ASC 852, “ Reorganizations ” as (i) the holders of existing voting shares of the Predecessor Company received less than 50% of the voting shares of the Successor Company and (ii) the reorganization value of the Company’s assets immediately prior to confirmation of the Plan was less than the post-petition liabilities and allowed claims. See Note 2 – Reorganization for the terms of the Plan. The Company applied fresh start accounting as of February 28, 2017. Fresh start accounting required the Company to present its assets, liabilities and equity as if it were a new entity upon emergence from bankruptcy, with no beginning retained earnings or deficit as of the fresh start reporting date. As described in Note 1 – Financial Statement Presentation , the new entity is referred to as Successor or Successor Company, and includes the financial position and results of operations of the reorganized Company subsequent to February 28, 2017. References to Predecessor or Predecessor Company relate to the financial position and results of operations of the Company prior to, and including, February 28, 2017. Reorganization Value Under fresh start accounting, reorganization value represents the fair value of the Successor Company’s total assets and is intended to approximate the amount a willing buyer would pay for the assets immediately after restructuring. Upon application of fresh start accounting, the Company allocated the reorganization value to its individual assets based on their estimated fair values. The Company’s reorganization value is derived from an estimate of enterprise value. Enterprise value represents the estimated fair value of an entity’s long-term debt and stockholders’ equity. In support of the Plan, the Company estimated the enterprise value of the core assets (as defined in the Plan) of the Successor Company to be in the range of $300 million to $450 million , which was subsequently approved by the Bankruptcy Court. This valuation analysis was prepared using reserve information, development schedules, other financial information and financial projections and applying standard valuation techniques, including net asset value analysis, precedent transactions analyses and public comparable company analyses. Based on the estimates and assumptions used in determining the enterprise value, the Company ultimately estimated the enterprise value of the Successor Company’s core assets to be approximately $420 million . Valuation of Assets The Company’s principal assets are its oil and gas properties, which the Company accounts for under the full cost accounting method. With the assistance of valuation experts, the Company determined the fair value of its oil and gas properties based on the discounted cash flows expected to be generated from these assets. The computations were based on market conditions and reserves in place as of the bankruptcy emergence date. The fair value analysis performed by valuation experts was based on the Company’s estimates of reserves as developed internally by the Company’s reserve engineers. For purposes of estimating the fair value of the Company’s proved, probable and possible reserves, an income approach was used, which estimated fair value based on the anticipated cash flows associated with the Company’s reserves, risked by reserve category and discounted using a weighted average cost of capital of 12.5% . The discount factor was derived from a weighted average cost of capital computation which utilized a blended expected cost of debt and expected returns on equity for similar market participants. Future revenues were based upon forward strip oil and natural gas prices as of the emergence date, adjusted for differentials realized by the Company, and adjusted for a 2% annual escalation after 2021. Development and operating costs were based on the Company’s recent cost trends adjusted for inflation. The discounted cash flow models also included estimates not typically included in proved reserves such as depreciation and income tax expenses. The proved reserve locations were limited to wells expected to be drilled in the Company’s five year development plan. As a result of this analysis, the Company concluded the fair value of its proved reserves was $380.8 million and the fair value of its probable and possible reserves was $16.8 million as of the Effective Date. The Company also reviewed its undeveloped leasehold acreage and inventory. An analysis of comparable market transactions indicated a fair value of undeveloped acreage and inventory totaling $80.2 million . These amounts are reflected in the Fresh Start Adjustments item number 12 below. The fair value of the Company’s asset retirement obligations was estimated at $290.1 million and was based on estimated plugging and abandonment costs as of the Effective Date, adjusted for inflation and discounted at the Successor Company’s credit-adjusted risk free rate of 12% . See further discussion in Fresh Start Adjustments below for details on the specific assumptions used in the valuation of the Company’s various other assets. The following table reconciles the enterprise value per the Plan to the estimated fair value (for fresh start accounting purposes) of the Successor Company’s common stock as of February 28, 2017 (in thousands, except per share value): February 28, 2017 Enterprise value $ 419,720 Plus: Cash and other assets 371,169 Less: Fair value of debt (236,261 ) Less: Fair value of warrants (15,648 ) Fair value of Successor common stock $ 538,980 Shares issued upon emergence 20,000 Per share value $ 26.95 The following table reconciles the enterprise value per the Plan to the estimated reorganization value as of the Effective Date (in thousands): February 28, 2017 Enterprise value $ 419,720 Plus: Cash and other assets 371,169 Plus: Asset retirement obligations (current and long-term) 290,067 Plus: Working capital and other liabilities 58,055 Reorganization value of Successor assets $ 1,139,011 Reorganization value and enterprise value were estimated using numerous projections and assumptions that are inherently subject to significant uncertainties and resolution of contingencies that are beyond our control. Accordingly, the estimates set forth herein are not necessarily indicative of actual outcomes, and there can be no assurance that the estimates, projections or assumptions will be realized. Condensed Consolidated Balance Sheet The adjustments set forth in the following condensed consolidated balance sheet reflect the effects of the transactions contemplated by the Plan and carried out by the Company (reflected in the column “Reorganization Adjustments”) as well as fair value adjustments as a result of the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes highlight methods used to determine fair values or other amounts of the assets and liabilities as well as significant assumptions or inputs. The following table reflects the reorganization and application of ASC 852 on our consolidated balance sheet as of February 28, 2017 (in thousands): Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company Assets Current assets: Cash and cash equivalents $ 198,571 $ (35,605 ) (1) $ — $ 162,966 Restricted cash — 75,547 (1) — 75,547 Accounts receivable 42,808 9,301 (2) — 52,109 Fair value of derivative contracts 1,267 — — 1,267 Current income tax receivable 22,516 — — 22,516 Other current assets 10,924 875 (3) (124 ) (12) 11,675 Total current assets 276,086 50,118 (124 ) 326,080 Oil and gas properties, full cost method of accounting: Proved 9,633,907 (188,933 ) (1) (8,774,122 ) (12) 670,852 Less: accumulated DD&A (9,215,679 ) — 9,215,679 (12) — Net proved oil and gas properties 418,228 (188,933 ) 441,557 670,852 Unevaluated 371,140 (127,838 ) (1) (146,292 ) (12) 97,010 Other property and equipment, net 25,586 (101 ) (4) (4,423 ) (13) 21,062 Fair value of derivative contracts 1,819 — — 1,819 Other assets, net 26,516 (4,328 ) (5) — 22,188 Total assets $ 1,119,375 $ (271,082 ) $ 290,718 $ 1,139,011 Liabilities and Stockholders’ Equity Current liabilities: Accounts payable to vendors $ 20,512 $ — $ — $ 20,512 Undistributed oil and gas proceeds 5,917 (4,139 ) (1) — 1,778 Accrued interest 266 — — 266 Asset retirement obligations 92,597 — — 92,597 Fair value of derivative contracts 476 — — 476 Current portion of long-term debt 411 — — 411 Other current liabilities 17,032 (195 ) (6) — 16,837 Total current liabilities 137,211 (4,334 ) — 132,877 Long-term debt 352,350 (116,500 ) (7) — 235,850 Asset retirement obligations 151,228 (8,672 ) (1) 54,914 (14) 197,470 Fair value of derivative contracts 653 — — 653 Other long-term liabilities 17,533 — — 17,533 Total liabilities not subject to compromise 658,975 (129,506 ) 54,914 584,383 Liabilities subject to compromise 1,110,182 (1,110,182 ) (8) — — Total liabilities 1,769,157 (1,239,688 ) 54,914 584,383 Commitments and contingencies Stockholders’ equity: Common stock (Predecessor) 56 (56 ) (9) — — Treasury stock (Predecessor) (860 ) 860 (9) — — Additional paid-in capital (Predecessor) 1,660,810 (1,660,810 ) (9) — — Common stock (Successor) — 200 (10) — 200 Additional paid-in capital (Successor) — 554,428 (10) — 554,428 Accumulated deficit (2,309,788 ) 2,073,984 (11) 235,804 (15) — Total stockholders’ equity (649,782 ) 968,606 235,804 554,628 Total liabilities and stockholders’ equity $ 1,119,375 $ (271,082 ) $ 290,718 $ 1,139,011 Reorganization Adjustments (dollar amounts in thousands, except per share values) 1. Reflects the net cash proceeds received from the sale of the Appalachia Properties in connection with the Plan and net cash payments made as of the Effective Date from implementation of the Plan: Sources: Net cash proceeds from sale of Appalachia Properties (a) $ 512,472 Total sources 512,472 Uses: Cash transferred to restricted account (b) 75,547 Break-up fee to Tug Hill 10,800 Repayment of outstanding borrowings under Pre-Emergence Credit Agreement 341,500 Repayment of 2017 Convertible Notes and 2022 Notes 100,000 Other fees and expenses (c) 20,230 Total uses 548,077 Net uses $ (35,605 ) (a) The closing of the sale of the Appalachia Properties occurred on February 27, 2017, but as emergence was contingent on such closing, the effects of the transaction are reflected as reorganization adjustments. See Note 7 – Divestiture for additional details on the sale. Total consideration received for the sale of the Appalachia Properties of $522,472 included cash consideration of $512,472 received at closing and a $10,000 indemnity escrow which was released subsequent to emergence from bankruptcy (see Reorganization Adjustments item number 2 below). (b) Reflects the movement of $75,000 of cash held in a restricted account to satisfy near-term plugging and abandonment liabilities, pursuant to the provisions of the Amended Credit Agreement (as defined in Note 10 – Debt ), and $547 held in a restricted cash account for certain cure amounts in connection with the Chapter 11 proceedings. (c) Other fees and expenses include approximately $15,180 of emergence and success fees, $2,600 of professional fees and $2,395 of payments made to seismic providers in settlement of their bankruptcy claims. 2. Reflects a receivable for a $10,000 indemnity escrow with release delayed until emergence from bankruptcy, net of a $699 reimbursement to Tug Hill in connection with the sale of the Appalachia Properties (see Note 7 – Divestiture ). 3. Reflects the payment of a claim to a seismic provider as a prepayment/deposit. 4. Reflects the sale of vehicles in connection with the sale of the Appalachia Properties. 5. Reflects the write-off of $2,577 of unamortized debt issuance costs related to the Pre-Emergence Credit Agreement and the reversal of a $1,750 prepayment made to Tug Hill in October 2016. 6. Reflects the accrual of $2,008 in expected bonus payments under the KEIP (as defined in Note 5 – Share–Based Compensation and Employee Benefit Plans ) and a $395 termination fee in connection with the early termination of an office lease, less the settlement of a property tax accrual of $2,598 in connection with the sale of the Appalachia Properties. 7. Reflects the repayment of $341,500 of outstanding borrowings under the Pre-Emergence Credit Agreement and the issuance of $225,000 of 2022 Second Lien Notes as part of the settlement of the Predecessor Company 2017 Convertible Notes and 2022 Notes. 8. Liabilities subject to compromise were settled as follows in accordance with the Plan: 1 ¾% Senior Convertible Notes due 2017 $ 300,000 7 ½% Senior Notes due 2022 775,000 Accrued interest 35,182 Liabilities subject to compromise of the Predecessor Company 1,110,182 Cash payment to senior noteholders (100,000 ) Issuance of 2022 Second Lien Notes to former holders of the senior notes (225,000 ) Fair value of equity issued to unsecured creditors (538,980 ) Fair value of warrants issued to unsecured creditors (15,648 ) Gain on settlement of liabilities subject to compromise $ 230,554 9. Reflects the cancellation of the Predecessor Company’s common stock, treasury stock and additional paid-in capital. 10. Reflects the issuance of Successor Company equity. In accordance with the Plan, the Successor Company issued 19.0 million shares of New Common Stock to the former holders of the 2017 Convertible Notes and the 2022 Notes and 1.0 million shares of New Common Stock to the Predecessor Company’s common stockholders. These amounts are subject to dilution by warrants issued to the Predecessor Company common stockholders, totaling approximately 3.5 million shares, with an exercise price of $42.04 per share and a term of four years . The fair value of the warrants was estimated at $4.43 per share using a Black-Scholes-Merton valuation model. 11. Reflects the cumulative impact of the reorganization adjustments discussed above: Gain on settlement of liabilities subject to compromise $ 230,554 Professional and other fees paid at emergence (10,648 ) Write-off of unamortized deferred financing costs (2,577 ) Other reorganization adjustments (1,915 ) Net impact to reorganization items 215,414 Gain on sale of Appalachia Properties 213,453 Cancellation of Predecessor Company equity 1,662,282 Other adjustments to accumulated deficit (17,165 ) Net impact to accumulated deficit $ 2,073,984 Fresh Start Adjustments 12. Fair value adjustments to oil and gas properties, associated inventory and unproved acreage. See above for a detailed discussion of the fair value methodology. 13. Fair value adjustment for an office building owned by the Company. The income and sales comparison approaches were used in determining the fair value, using anticipated future earnings and an appropriate expected rate of return, as well as relying upon recent sales or offerings of similar assets. 14. Fair value adjustments to the Company’s asset retirement obligations using estimated plugging and abandonment costs as of the Effective Date, adjusted for inflation and discounted at the Successor Company’s credit-adjusted risk free rate. 15. Reflects the cumulative effect of the fresh start accounting adjustments discussed above. Reorganization Items Reorganization items represent liabilities settled, net of amounts incurred subsequent to the Chapter 11 filing as a direct result of the Plan and are classified as “Reorganization items, net” in the Company’s unaudited condensed consolidated statement of operations. The following table summarizes reorganization items, net (in thousands): Predecessor Period from Gain on settlement of liabilities subject to compromise $ 230,554 Fresh start valuation adjustments 235,804 Reorganization professional fees and other expenses (20,512 ) Write-off of deferred financing costs (2,577 ) Other reorganization items (5,525 ) Gain on reorganization items, net $ 437,744 The cash payments for reorganization items for the period from January 1, 2017 through February 28, 2017 include approximately $10.6 million of emergence and success fees and approximately $9.1 million of other reorganization professional fees and expenses paid on the Effective Date.

STOCKHOLDERS' EQUITY

STOCKHOLDERS' EQUITY	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
STOCKHOLDERS' EQUITY	STOCKHOLDERS’ EQUITY Common Stock As discussed in Note 2 – Reorganization , upon emergence from bankruptcy, all existing shares of Predecessor common stock were cancelled, and the Successor Company issued an aggregate of 20.0 million shares of New Common Stock, par value $0.01 per share, to the Predecessor Company’s existing common stockholders and holders of the 2017 Convertible Notes and the 2022 Notes pursuant to the Plan. Warrants As discussed in Note 2 – Reorganization , the Predecessor Company’s existing common stockholders received warrants to purchase approximately 3.5 million shares of New Common Stock. The warrants have an exercise price of $42.04 per share and a term of four years , unless terminated earlier by their terms upon the consummation of certain business combinations or sale transactions involving the Company. The Company allocated $15.6 million of the enterprise value to the warrants which is reflected in “Successor additional paid-in capital” on the unaudited condensed consolidated balance sheet at September 30, 2017 (Successor).

SHARE-BASED COMPENSATION AND EM

SHARE-BASED COMPENSATION AND EMPLOYEE BENEFIT PLANS	9 Months Ended
	Sep. 30, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
SHARE-BASED COMPENSATION AND EMPLOYEE BENEFIT PLANS	SHARE–BASED COMPENSATION AND EMPLOYEE BENEFIT PLANS Predecessor Awards Immediately prior to emergence, the vesting of all Predecessor outstanding, unvested share-based awards for non-executive employees was accelerated and, as a result, all unrecognized compensation cost related to such awards was recognized, with $1.7 million expensed as salaries, general and administrative (“SG&A”) expense in the Predecessor Company statement of operations during the period from January 1, 2017 through February 28, 2017, and $0.6 million capitalized into oil and gas properties. Upon emergence from bankruptcy, all Predecessor outstanding, unvested restricted shares held by the Company’s executives were cancelled and exchanged for a proportionate share of the 5% of New Common Stock, plus a proportionate share of the warrants for ownership of up to 15% of the Successor Company’s common equity. Vesting continues in accordance with the applicable vesting provisions of the original awards. As of September 30, 2017 , there was $14 thousand of unrecognized compensation cost related to unvested restricted shares held by the Company’s executives. The current weighted average remaining vesting period of such awards is approximately three months . All other Predecessor Company executive share-based awards were cancelled upon emergence from bankruptcy. The board of directors of the Predecessor Company received grants of stock, totaling 10,404 shares, during the period from January 1, 2017 through February 28, 2017, representing the pro-rated portion of their annual retainer for such period. The aggregate grant date value of such stock totaled $69 thousand and was recognized as SG&A expense in the Predecessor Company statement of operations for the period from January 1, 2017 through February 28, 2017. Pursuant to the Plan, as of the Effective Date, all non-employee directors of the Predecessor Company ceased to serve on the Company’s board of directors. Successor Awards On March 1, 2017, the board of directors of the Successor Company (the “Board”) received grants of restricted stock units under the 2017 LTIP (see 2017 Long-Term Incentive Plan below). The restricted stock units are scheduled to vest in full on the day prior to the annual meeting of the Company’s stockholders in May 2018, subject to: (i) the director’s continued service on the Board through the vesting date, and (ii) earlier vesting upon the occurrence of a change of control event or the termination of the director’s service due to death or removal from the Board without cause. A total of 62,137 restricted stock units were granted with an aggregate grant date fair value of $1.7 million , based on a per share grant date fair value of $26.95 . As of September 30, 2017, there was $0.9 million of unrecognized compensation cost related to such restricted stock units, with a current weighted average remaining vesting period of approximately seven months . 2017 Long-Term Incentive Plan On the Effective Date, pursuant to the Plan, the Stone Energy Corporation 2017 Long-Term Incentive Plan (the “2017 LTIP”) became effective, replacing the Stone Energy Corporation 2009 Amended and Restated Stock Incentive Plan (As Amended and Restated December 17, 2015). The types of awards that may be granted under the 2017 LTIP include stock options, restricted stock, restricted stock units, dividend equivalents and other forms of awards granted or denominated in shares of New Common Stock, as well as certain cash-based awards. The maximum number of shares of New Common Stock that may be issued or transferred pursuant to awards under the 2017 LTIP is 2,614,379 . As of November 1, 2017, other than the grant of the 62,137 restricted stock units to the Board (see Successor Awards above), there have been no other issuances or awards of stock under the 2017 LTIP. Key Executive Incentive Plan Pursuant to the terms of the Executive Claims Settlement Agreement approved by the Bankruptcy Court on January 10, 2017, the Company’s executives agreed to waive their claims related to the Company’s 2016 Performance Incentive Compensation Plan (the “2016 PICP”), and in exchange therefor, the Company adopted the Stone Energy Corporation Key Executive Incentive Plan (“KEIP”), in which the Company’s executives were allowed to participate. Future payments to the Company’s executives under the KEIP were limited to $2 million , or the equivalent of the target bonus under the 2016 PICP for the fourth quarter of 2016, to be paid in two equal installments. The first payment to the Company’s executives under the KEIP was made subsequent to consummation of the bankruptcy cases, on April 24, 2017, and the second payment was made on May 30, 2017. 2017 Annual Incentive Compensation Plan On July 25, 2017, the Board approved the Stone Energy Corporation 2017 Annual Incentive Compensation Plan (the “2017 Annual Incentive Plan”) for all salaried employees (other than the interim chief executive officer) of the Company. The 2017 Annual Incentive Plan is a performance-based incentive program that provides award opportunities based on the Company’s annual performance in certain performance measures as defined by the Board. The 2017 Annual Incentive Plan replaced the Company’s 2005 Annual Incentive Compensation Plan. We recognized a charge of $4.1 million during the three months ended September 30, 2017 (Successor), net of amounts capitalized, representing a pro-rated portion of the 2017 estimated annual incentive compensation awards, for the nine months ended September 30, 2017. This charge is reflected in incentive compensation expense on the statement of operations. Retention Award Agreement On July 25, 2017, the Board approved retention awards and the form of Stone Energy Corporation Retention Award Agreement (the “Retention Award Agreement”) and authorized the Company to enter into Retention Award Agreements with certain executive officers and employees of the Company. The Retention Award Agreement provides for a retention award to certain individuals to be paid in a lump sum cash payment within 30 days of the earliest to occur of (i) the first anniversary (June 1, 2018) of the effective date of the Retention Award Agreement, subject to the individual remaining employed by the Company or a subsidiary of the Company on such date, (ii) a change in control of the Company or (iii) a termination of the individual’s employment with the Company (a) due to death, (b) by the Company without “cause” or (c) by the individual for “good reason.” We recognized a charge of $0.5 million during the three months ended September 30, 2017 (Successor), representing a pro-rated portion of estimated retention awards for the period from June 1, 2017 through September 30, 2017. This charge is reflected in incentive compensation expense on the statement of operations. Executive Severance Plan On July 25, 2017, the Board approved the Stone Energy Corporation Executive Severance Plan (the “Executive Severance Plan”), which provides for the payment of severance and change in control benefits to the executive officers (other than the interim chief executive officer) of the Company. Pursuant to the Executive Severance Plan, if a covered executive officer is terminated (i) by the Company without “cause” or (ii) by the executive officer for “good reason” (each, an “Involuntary Termination”), the executive officer will receive (i) a lump sum cash payment in an amount equal to 1.0 x or 1.5 x the executive officer’s annual base salary, (ii) a lump sum cash payment equal to 100% of the executive officer’s annual bonus opportunity, at target, prorated by the number of days that have elapsed from January 1 of that calendar year, (iii) six months of health benefit continuation for the executive officer and the executive officer’s dependents, (iv) accelerated vesting of any outstanding and unvested equity awards, (v) certain outplacement services and (vi) any unpaid portion of the executive officer’s annual pay as of the date of the Involuntary Termination. The Executive Severance Plan replaced the Stone Energy Corporation Executive Severance Plan dated December 13, 2016.

EARNINGS PER SHARE

EARNINGS PER SHARE	9 Months Ended
	Sep. 30, 2017
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE On February 28, 2017, upon emergence from Chapter 11 bankruptcy, the Company’s Predecessor equity was cancelled and new equity was issued. Additionally, the Predecessor Company’s 2017 Convertible Notes were cancelled. See Note 2 – Reorganization and Note 4 – Stockholders’ Equity for further details. The following tables set forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods (in thousands, except per share amounts): Successor Predecessor Three Months Ended Three Months Ended Income (numerator): Basic: Net income (loss) $ 1,297 $ (89,635 ) Net income attributable to participating securities (4 ) — Net income (loss) attributable to common stock - basic $ 1,293 $ (89,635 ) Diluted: Net income (loss) $ 1,297 $ (89,635 ) Net income attributable to participating securities (4 ) — Net income (loss) attributable to common stock - diluted $ 1,293 $ (89,635 ) Weighted average shares (denominator): Weighted average shares - basic 19,997 5,600 Dilutive effect of stock options — — Dilutive effect of warrants — — Dilutive effect of convertible notes — — Weighted average shares - diluted 19,997 5,600 Basic income (loss) per share $ 0.06 $ (16.01 ) Diluted income (loss) per share $ 0.06 $ (16.01 ) Successor Predecessor Period from Period from Nine Months Ended Income (numerator): Basic: Net income (loss) $ (264,777 ) $ 630,317 $ (474,180 ) Net income attributable to participating securities — (4,995 ) — Net income (loss) attributable to common stock - basic $ (264,777 ) $ 625,322 $ (474,180 ) Diluted: Net income (loss) $ (264,777 ) $ 630,317 $ (474,180 ) Net income attributable to participating securities — (4,995 ) — Net income (loss) attributable to common stock - diluted $ (264,777 ) $ 625,322 $ (474,180 ) Weighted average shares (denominator): Weighted average shares - basic 19,997 5,634 5,585 Dilutive effect of stock options — — — Dilutive effect of warrants — — — Dilutive effect of convertible notes — — — Weighted average shares - diluted 19,997 5,634 5,585 Basic income (loss) per share $ (13.24 ) $ 110.99 $ (84.90 ) Diluted income (loss) per share $ (13.24 ) $ 110.99 $ (84.90 ) All outstanding stock options were considered antidilutive during the period from January 1, 2017 through February 28, 2017 (Predecessor) (approximately 10,400 shares) because the exercise price of the options exceeded the average price of our common stock for the applicable period. During the three and nine months ended September 30, 2016 (Predecessor), all outstanding stock options were considered antidilutive (approximately 12,900 shares) because we had net losses for such periods. On February 28, 2017, upon emergence from bankruptcy, all outstanding stock options were cancelled. See Note 5 – Share-Based Compensation and Employee Benefit Plans . On February 28, 2017, upon emergence from bankruptcy, the Predecessor Company’s existing common stockholders received warrants to purchase common stock of the Successor Company. See Note 2 – Reorganization . For the three months ended September 30, 2017 (Successor), all outstanding warrants (approximately 3,529,000 ) were considered antidilutive because the exercise price of the warrants exceeded the average price of our common stock for the applicable period. For the period of March 1, 2017 through September 30, 2017 (Successor), all outstanding warrants (approximately 3,529,000 ) were antidilutive because we had a net loss for such period. The Predecessor Company had no outstanding restricted stock units. The Board received grants of restricted stock units on March 1, 2017. See Note 5 – Share-Based Compensation and Employee Benefit Plans. For the period from March 1, 2017 through September 30, 2017 (Successor), all outstanding restricted stock units (approximately 62,000 ) were considered antidilutive because we had a net loss for such period. For the period from January 1, 2017 through February 28, 2017 (Predecessor), the average price of our common stock was less than the effective conversion price for the 2017 Convertible Notes, resulting in no dilutive effect on the diluted earnings per share computation for such period. For the three and nine months ended September 30, 2016 (Predecessor), the 2017 Convertible Notes had no dilutive effect on the diluted earnings per share computation as we had net losses for such periods. On February 28, 2017, upon emergence from bankruptcy, the 2017 Convertible Notes were cancelled. See Note 2 – Reorganization . During the three months ended September 30, 2017 (Successor), there were no issuances of common stock of the Successor Company. During the period from March 1, 2017 through September 30, 2017 (Successor), 1,195 shares of common stock of the Successor Company were issued from authorized shares upon the lapsing of forfeiture restrictions of restricted stock for employees. During the periods from January 1, 2017 through February 28, 2017 (Predecessor) and the three and nine months ended September 30, 2016 (Predecessor), approximately 47,390 shares, 12,900 shares and 75,100 shares of Predecessor Company common stock, respectively, were issued from authorized shares upon the granting of stock awards and the lapsing of forfeiture restrictions of restricted stock for employees and nonemployee directors.

DIVESTITURE

DIVESTITURE	9 Months Ended
	Sep. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
DIVESTITURE	DIVESTITURE On February 27, 2017, we completed the sale of the Appalachia Properties to EQT for net cash consideration of approximately $522.5 million , representing gross proceeds of $527.0 million adjusted downward by approximately $4.5 million for purchase price adjustments for operations related to the Appalachia Properties after June 1, 2016, the effective date of the transaction. A portion of the consideration received from the sale of the Appalachia Properties was used to fund the Company’s cash payment obligations under the Plan. See Note 2 – Reorganization . At December 31, 2016, the estimated proved oil and natural gas reserves associated with these assets totaled 18 MMBoe (million barrels of oil equivalent), which represented approximately 34% of our estimated proved oil and natural gas reserves on a volume equivalent basis. We no longer have assets or operations in Appalachia. Since accounting for the sale of these oil and gas properties as a reduction of the capitalized costs of oil and gas properties would have significantly altered the relationship between capitalized costs and reserves, we recognized a gain on the sale of $213.5 million during the period from January 1, 2017 through February 28, 2017 (Predecessor), computed as follows (in millions): Net consideration received for sale of Appalachia Properties $ 522.5 Add: Release of funds held in suspense 4.1 Transfer of asset retirement obligations 8.7 Other adjustments, net 2.6 Less: Transaction costs (7.1 ) Carrying value of properties sold (317.3 ) Gain on sale $ 213.5 The carrying value of the properties sold was determined by allocating total capitalized costs within the U.S. full cost pool between properties sold and properties retained based on their relative fair values.

INVESTMENT IN OIL AND GAS PROPE

INVESTMENT IN OIL AND GAS PROPERTIES	9 Months Ended
	Sep. 30, 2017
Extractive Industries [Abstract]
INVESTMENT IN OIL AND GAS PROPERTIES	INVESTMENT IN OIL AND GAS PROPERTIES With the adoption of fresh start accounting, the Company recorded its oil and gas properties at fair value as of February 28, 2017. The Company’s proved, probable and possible reserves and unevaluated properties (including inventory) were assigned values of $380.8 million , $16.8 million and $80.2 million , respectively. See Note 3 – Fresh Start Accounting for a discussion of the valuation approach used. Under the full cost method of accounting, we compare, at the end of each financial reporting period, the present value of estimated future net cash flows from proved reserves (adjusted for designated cash flow hedges and excluding cash flows related to estimated abandonment costs) to the net capitalized costs of proved oil and gas properties, net of related deferred taxes. We refer to this comparison as a ceiling test. If the net capitalized costs of proved oil and gas properties exceed the estimated discounted future net cash flows from proved reserves, we are required to write down the value of our oil and gas properties to the value of the discounted cash flows. At March 31, 2017 (Successor), our ceiling test computation resulted in a write-down of our U.S. oil and gas properties of $256.4 million based on twelve-month average prices, net of applicable differentials, of $45.40 per Bbl of oil, $2.24 per Mcf of natural gas and $19.18 per Bbl of natural gas liquids (“NGLs”). The write-down at March 31, 2017 is reflected in the statement of operations of the Successor Company for the period from March 1, 2017 through September 30, 2017 and was primarily due to differences between the trailing twelve-month average pricing assumption used in calculating the ceiling test and the forward prices used in fresh start accounting to estimate the fair value of our oil and gas properties on the fresh start reporting date of February 28, 2017. Weighted average commodity prices used in the determination of the fair value of our oil and gas properties for purposes of fresh start accounting were $56.01 per Bbl of oil, $2.52 per Mcf of natural gas and $14.18 per Bbl of NGLs, net of applicable differentials. Since none of our derivatives as of March 31, 2017 were designated as cash flow hedges (see Note 9 – Derivative Instruments and Hedging Activities ), the write-down at March 31, 2017 was not affected by hedging. At September 30, 2016 (Predecessor), our ceiling test computation resulted in a write-down of our U.S. oil and gas properties of $36.5 million based on twelve-month average prices, net of applicable differentials, of $40.51 per Bbl of oil, $1.99 per Mcf of natural gas and $13.88 per Bbl of NGLs. The write-down at September 30, 2016 was decreased by $9.6 million as a result of hedges. At June 30, 2016 (Predecessor), our ceiling test computation resulted in a write-down of our U.S. oil and gas properties of $118.6 million based on twelve-month average prices, net of applicable differentials, of $43.49 per Bbl of oil, $1.93 per Mcf of natural gas and $9.33 per Bbl of NGLs. The write-down at June 30, 2016 was decreased by $18.1 million as a result of hedges. At March 31, 2016 (Predecessor), our ceiling test computation resulted in a write-down of our U.S. oil and gas properties of $128.9 million based on twelve-month average prices, net of applicable differentials, of $46.72 per Bbl of oil, $2.01 per Mcf of natural gas and $13.65 per Bbl of NGLs. At March 31, 2016, the write-down of oil and gas properties also included $0.3 million related to our Canadian oil and gas properties, which were deemed to be fully impaired at the end of 2015. The write-down at March 31, 2016 was decreased by $23 million as a result of hedges. The September 30, June 30 and March 31, 2016 write-downs are reflected in the statement of operations of the Predecessor Company.

DERIVATIVE INSTRUMENTS AND HEDG

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Our hedging strategy is designed to protect our near and intermediate term cash flows from future declines in oil and natural gas prices. This protection is essential to capital budget planning, which is sensitive to expenditures that must be committed to in advance, such as rig contracts and the purchase of tubular goods. We enter into derivative transactions to secure a commodity price for a portion of our expected future production that is acceptable at the time of the transaction. We do not enter into derivative transactions for trading purposes. All derivatives are recognized as assets or liabilities on the balance sheet and are measured at fair value. At the end of each quarterly period, these derivatives are marked-to-market. If the derivative does not qualify or is not designated as a cash flow hedge, subsequent changes in the fair value of the derivative are recognized in earnings through derivative income (expense) in the statement of operations. If the derivative qualifies and is designated as a cash flow hedge, subsequent changes in the fair value of the derivative are recognized in stockholders’ equity through other comprehensive income (loss), net of related taxes, to the extent the hedge is considered effective. Monthly settlements of effective hedges are reflected in revenue from oil and natural gas production. Monthly settlements of ineffective hedges and derivatives not designated or that do not qualify for hedge accounting are recognized in earnings through derivative income (expense). The resulting cash flows from all monthly settlements are reported as cash flows from operating activities. Through December 31, 2016, we designated our commodity derivatives as cash flow hedges for accounting purposes upon entering into the contracts. A small portion of our cash flow hedges were typically determined to be ineffective because oil and natural gas price changes in the markets in which we sell our products were not 100% correlative to changes in the underlying price basis indicative in the derivative contract. We had no outstanding derivatives at December 31, 2016. With respect to our 2017, 2018 and 2019 commodity derivative contracts, we have elected to not designate these contracts as cash flow hedges for accounting purposes. Accordingly, the net changes in the mark-to-market valuations and the monthly settlements on these derivative contracts will be recorded in earnings through derivative income (expense). We have entered into put contracts, fixed-price swaps and collar contracts with various counterparties for a portion of our expected 2017, 2018 and 2019 oil and natural gas production from the Gulf Coast Basin. All of our derivative transactions have been carried out in the over-the-counter market and are not typically subject to margin-deposit requirements. The use of derivative instruments involves the risk that the counterparties will be unable to meet the financial terms of such transactions. The counterparties to all of our derivative instruments have an “investment grade” credit rating. We monitor the credit ratings of our derivative counterparties on an ongoing basis. Although we typically enter into derivative contracts with multiple counterparties to mitigate our exposure to any individual counterparty, if any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection, we may not realize the benefit of some of our derivative instruments and incur a loss. At November 1, 2017 , our derivative instruments were with five counterparties, two of which accounted for approximately 64% of our contracted volumes. Currently, all of our outstanding derivative instruments are with lenders under our current bank credit facility. Put contracts are purchased at a rate per unit of hedged production that fluctuates with the commodity futures market. The historical cost of the put contract represents our maximum cash exposure. We are not obligated to make any further payments under the put contract regardless of future commodity price fluctuations. Under put contracts, monthly payments are made to us if the New York Mercantile Exchange (“NYMEX”) prices fall below the agreed upon floor price, while allowing us to fully participate in commodity prices above the floor. Swaps typically provide for monthly payments by us if prices rise above the swap price or monthly payments to us if prices fall below the swap price. Collar contracts typically require payments by us if the NYMEX average closing price is above the ceiling price or payments to us if the NYMEX average closing price is below the floor price. Settlements for our oil put contracts, oil collar contracts and fixed-price oil swaps are based on an average of the NYMEX closing price for West Texas Intermediate crude oil during the entire calendar month. Settlements for our natural gas collar contracts and fixed-price natural gas swaps are based on the NYMEX price for the last day of a respective contract month. The following tables illustrate our derivative positions for calendar years 2017, 2018 and 2019 as of November 1, 2017 : Put Contracts (NYMEX) Oil Daily Volume Price 2017 February - December 2,000 $ 50.00 2017 July - December 1,000 41.10 2018 January - December 1,000 54.00 2018 January - December 1,000 45.00 Fixed-Price Swaps (NYMEX) Natural Gas Oil Daily Volume (MMBtus/d) Swap Price ($ per MMBtu) Daily Volume (Bbls/d) Swap Price ($ per Bbl) 2017 March - December 1,000 $ 53.90 2017 July - December 11,000 $ 3.00 2017 October - December 1,000 52.10 2018 January - December 1,000 52.50 2018 January - December 1,000 51.98 2018 January - December 1,000 53.67 2019 January - December 1,000 51.00 2019 January - December 1,000 51.57 Collar Contracts (NYMEX) Natural Gas Oil Daily Volume Floor Price Ceiling Price Daily Volume (Bbls/d) Floor Price Ceiling Price 2017 March - December 1,000 $ 50.00 $ 56.45 2017 April - December 1,000 50.00 56.75 2018 January - December 6,000 $ 2.75 $ 3.24 1,000 45.00 55.35 Derivatives not designated or not qualifying as hedging instruments The following table discloses the location and fair value amounts of derivatives not designated or not qualifying as hedging instruments, as reported in our balance sheet, at September 30, 2017 (Successor) (in millions). We had no outstanding hedging instruments at December 31, 2016 (Predecessor). Fair Value of Derivatives Not Designated or Not Qualifying as Hedging Instruments at September 30, 2017 (Successor) Asset Derivatives Liability Derivatives Description Balance Sheet Location Fair Balance Sheet Location Fair Commodity contracts Current assets: Fair value of $ 2.6 Current liabilities: Fair value of derivative contracts $ 0.4 Long-term assets: Fair value 1.0 Long-term liabilities: Fair 0.1 $ 3.6 $ 0.5 Gains or losses related to changes in fair value and cash settlements for derivatives not designated or not qualifying as hedging instruments are recorded as derivative income (expense) in the statement of operations. The following table discloses the before tax effect of our derivatives not designated or not qualifying as hedging instruments on the statement of operations for the three months ended September 30, 2017 (Successor), the period from January 1, 2017 through February 28, 2017 (Predecessor) and the period from March 1, 2017 through September 30, 2017 (Successor) (in millions). Gain (Loss) Recognized in Derivative Income (Expense) Successor Successor Predecessor Three Months Ended Period from Period from Description Commodity contracts: Cash settlements $ 1.2 $ 2.6 $ — Change in fair value (7.9 ) (1.2 ) (1.8 ) Total gains (losses) on derivatives not designated or not qualifying as hedging instruments $ (6.7 ) $ 1.4 $ (1.8 ) Derivatives qualifying as hedging instruments None of our derivative contracts outstanding as of September 30, 2017 (Successor) were designated as accounting hedges. We had no outstanding derivatives at December 31, 2016 (Predecessor). At September 30, 2016, we had outstanding derivatives that were designated and qualified as hedging instruments. The following tables disclose the before tax effect of derivatives qualifying as hedging instruments, as reported in the statement of operations, during the three and nine months ended September 30, 2016 (Predecessor) (in millions): Effect of Derivatives Qualifying as Hedging Instruments on the Statement of Operations for the Three Months Ended September 30, 2016 (Predecessor) Derivatives in Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion) (a) Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) 2016 Location 2016 Location 2016 Commodity contracts $ 2.3 Operating revenue - oil/natural gas production $ 7.7 Derivative income (expense), net $ (0.2 ) Total $ 2.3 $ 7.7 $ (0.2 ) (a) For the three months ended September 30, 2016 , effective hedging contracts increased oil revenue by $5.3 million and increased natural gas revenue by $2.4 million . Effect of Derivatives Qualifying as Hedging Instruments on the Statement of Operations for the Nine Months Ended September 30, 2016 (Predecessor) Derivatives in Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion) (a) Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) 2016 Location 2016 Location 2016 Commodity contracts $ (1.7 ) Operating revenue - oil/natural gas production $ 29.4 Derivative income (expense), net $ (0.7 ) Total $ (1.7 ) $ 29.4 $ (0.7 ) (a) For the nine months ended September 30, 2016 , effective hedging contracts increased oil revenue by $19.7 million and increased natural gas revenue by $9.7 million . Offsetting of derivative assets and liabilities Our derivative contracts are subject to netting arrangements. It is our policy to not offset our derivative contracts in presenting the fair value of these contracts as assets and liabilities in our balance sheet. The following table presents the potential impact of the offset rights associated with our recognized assets and liabilities at September 30, 2017 (Successor) (in millions): As Presented Without Netting Effects of Netting With Effects of Netting Current assets: Fair value of derivative contracts $ 2.6 $ (0.4 ) $ 2.2 Long-term assets: Fair value of derivative contracts 1.0 (0.1 ) 0.9 Current liabilities: Fair value of derivative contracts (0.4 ) 0.4 — Long-term liabilities: Fair value of derivative contracts (0.1 ) 0.1 — We had no outstanding derivative contracts at December 31, 2016 (Predecessor).

DEBT

DEBT	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
DEBT	DEBT Our debt balances (net of related unamortized discounts and debt issuance costs) as of September 30, 2017 and December 31, 2016 were as follows (in millions): Successor Predecessor September 30, December 31, 7 ½% Senior Second Lien Notes due 2022 $ 225.0 $ — 1 ¾% Senior Convertible Notes due 2017 — 300.0 7 ½% Senior Notes due 2022 — 775.0 Predecessor revolving credit facility — 341.5 4.20% Building Loan 11.0 11.3 Total debt 236.0 1,427.8 Less: current portion of long-term debt (0.4 ) (0.4 ) Less: liabilities subject to compromise — (1,075.0 ) Long-term debt $ 235.6 $ 352.4 Reorganization On December 14, 2016, the Debtors filed Bankruptcy Petitions seeking relief under the provisions of Chapter 11 of the Bankruptcy Code to pursue a prepackaged plan of reorganization. The 2017 Convertible Notes and 2022 Notes were impacted by the Chapter 11 process and were classified in the accompanying condensed consolidated balance sheet at December 31, 2016 as liabilities subject to compromise under the provisions of ASC 852, “ Reorganizations ”. On February 15, 2017, the Bankruptcy Court entered an order confirming the Plan, and on February 28, 2017, the Plan became effective and the Debtors emerged from bankruptcy. Upon emergence from bankruptcy, pursuant to the terms of the Plan, the Predecessor Company’s 2017 Convertible Notes and 2022 Notes were cancelled, the Predecessor Company’s Pre-Emergence Credit Agreement was amended and restated, and the Company issued the 2022 Second Lien Notes. Current Portion of Long-Term Debt As of September 30, 2017 (Successor), the current portion of long-term debt of $0.4 million represented principal payments due within one year on the 4.20% Building Loan (the “Building Loan”). Successor Revolving Credit Facility On the Effective Date, pursuant to the terms of the Plan, the Company entered into the Fifth Amended and Restated Credit Agreement with the lenders party thereto and Bank of America, N.A. (the “Amended Credit Agreement”), as administrative agent and issuing lender, which amended and replaced the Company’s Pre-Emergence Credit Agreement. The Amended Credit Agreement provides for a reserve-based revolving credit facility and matures on February 28, 2021. The Company’s available borrowings under the Amended Credit Agreement are set at $150 million until the first borrowing base redetermination in November 2017. On September 30, 2017 , the Company had no outstanding borrowings and $12.6 million of outstanding letters of credit, leaving $137.4 million of availability under the Amended Credit Agreement. The borrowing base will be redetermined in early November 2017. Interest on loans under the Amended Credit Agreement is calculated using the London Interbank Offering Rate (“LIBOR”) or the base rate, at the election of the Company, plus, in each case, an applicable margin. The applicable margin is determined based on borrowing base utilization and ranges from 2.00% to 3.00% per annum for base rate loans and 3.00% to 4.00% per annum for LIBOR loans. The borrowing base under the Amended Credit Agreement is redetermined semi-annually, in May and November, by the lenders, in accordance with the lenders’ customary practices for oil and gas loans. In addition, we and the lenders each have discretion at any time, but not more than two additional times in any calendar year, to have the borrowing base redetermined. Subject to certain exceptions, the Amended Credit Agreement is required to be guaranteed by all of the material domestic direct and indirect subsidiaries of the Company. As of September 30, 2017 , the Amended Credit Agreement is guaranteed by Stone Offshore. The Amended Credit Agreement is secured by substantially all of the Company’s and its subsidiaries’ assets. The Amended Credit Agreement provides for customary optional and mandatory prepayments, affirmative and negative covenants and events of default, including limitation on the incurrence of debt, liens, restrictive agreements, mergers, asset sales, dividends, investments, affiliate transactions and restrictions on commodity hedging. During the continuance of an event of default, the lenders may take a number of actions, including declaring the entire amount then outstanding under the Amended Credit Agreement due and payable. The Amended Credit Agreement also requires maintenance of certain financial covenants, including (i) a consolidated funded debt to EBITDA ratio of not more than 2.75 x for the test period ending March 31, 2017, 2.50 x for the test period ending June 30, 2017, 3.00 x for the test period ending September 30, 2017, 2.75 x for the test period ending December 31, 2017, 2.50 x for the test periods ending March 31, 2018, June 30, 2018, September 30, 2018 and December 31, 2018, respectively, 2.75 x for the test period ending March 31, 2019, 3.00 x for the test period ending June 30, 2019, 3.50 x for the test periods ending September 30, 2019 and December 31, 2019, respectively, 3.00 x for the test period ending March 31, 2020, 2.75 x for the test periods ending June 30, 2020 and September 30, 2020, respectively, and 2.50 x for the test periods ending December 31, 2020 and March 31, 2021, respectively, (ii) a consolidated interest coverage ratio of not less than 2.75 to 1.00, and (iii) a requirement to maintain minimum liquidity of at least 20% of the borrowing base. We were in compliance with all covenants under the Amended Credit Agreement as of September 30, 2017 . Predecessor Revolving Credit Facility On June 24, 2014 , the Predecessor Company entered into the Pre-Emergence Credit Agreement with the lenders party thereto and Bank of America, N.A., as administrative agent and issuing lender, with commitments totaling $900 million (subject to borrowing base limitations). The borrowing base under the Pre-Emergence Credit Agreement prior to its amendment and restatement as the Amended Credit Agreement was $150 million . Interest on loans under the Pre-Emergence Credit Agreement was calculated using the LIBOR rate or the base rate, at our election. The margin for loans at the LIBOR rate was determined based on borrowing base utilization and ranged from 1.500% to 2.500% . Prior to emergence from bankruptcy, the Predecessor Company had $341.5 million of outstanding borrowings and $12.5 million of outstanding letters of credit under the Pre-Emergence Credit Agreement. At emergence, the outstanding borrowings were paid in full and the $12.5 million of outstanding letters of credit were converted to obligations under the Amended Credit Agreement. Building Loan On November 20, 2015, we entered into an $11.8 million term loan agreement, the Building Loan, maturing on December 20, 2030. There were no changes to the terms of the Building Loan pursuant to the Plan. As of September 30, 2017, the outstanding balance under the Building Loan totaled $11.0 million . Successor 2022 Second Lien Notes On the Effective Date, pursuant to the terms of the Plan, the Successor Company entered into an indenture by and among the Company, Stone Offshore as guarantor (the “Guarantor”), and The Bank of New York Mellon Trust Company, N.A., as trustee and collateral agent (the “2022 Second Lien Notes Indenture”), and issued $225.0 million of the Company’s 2022 Second Lien Notes pursuant thereto. Interest on the 2022 Second Lien Notes will accrue at a rate of 7.50% per annum payable semi-annually in arrears on May 31 and November 30 of each year in cash, beginning November 30, 2017. At September 30, 2017 , $9.8 million had been accrued in connection with the November 30, 2017 interest payment. The 2022 Second Lien Notes are secured on a second lien priority basis by the same collateral that secures the Amended Credit Agreement, including the Company’s oil and natural gas properties, and are guaranteed by the Guarantor. The 2022 Second Lien Notes mature on May 31, 2022. Pursuant to the terms of the Intercreditor Agreement (as defined below), the security interest in those assets that secure the 2022 Second Lien Notes and the related guarantee will be contractually subordinated to liens thereon that secure the Company’s Amended Credit Agreement and certain other permitted obligations as set forth in the 2022 Second Lien Notes Indenture. Consequently, the 2022 Second Lien Notes and the related guarantee will be effectively subordinated to the Amended Credit Agreement and such other permitted secured indebtedness to the extent of the value of such assets. At any time prior to May 31, 2020, the Company may, at its option, on any one or more occasions redeem up to 35% of the aggregate principal amount of the 2022 Second Lien Notes issued under the 2022 Second Lien Notes Indenture at a redemption price of 107.5% of the principal amount of the 2022 Second Lien Notes, plus accrued and unpaid interest to the redemption date, with an amount of cash equal to the net cash proceeds of certain equity offerings; provided that at least 65% of the aggregate principal amount of the 2022 Second Lien Notes remains outstanding after each such redemption. On or after May 31, 2020, the Company may redeem all or part of the 2022 Second Lien Notes at redemption prices (expressed as percentages of the principal amount) equal to (i) 105.625% for the twelve-month period beginning on May 31, 2020; (ii) 105.625% for the twelve-month period beginning on May 31, 2021; and (iii) 100.000% for the twelve-month period beginning May 31, 2022 and at any time thereafter, plus accrued and unpaid interest at the redemption date. In addition, at any time prior to May 31, 2020, the Company may redeem all or a part of the 2022 Second Lien Notes at a redemption price equal to 100% of the principal amount of the 2022 Second Lien Notes to be redeemed plus a make-whole premium, plus accrued and unpaid interest to the redemption date. The 2022 Second Lien Notes Indenture contains covenants that restrict the Company’s ability and the ability of certain of its subsidiaries to: (i) incur additional debt and issue preferred stock; (ii) make payments or distributions on account of the Company’s or its restricted subsidiaries’ capital stock; (iii) sell assets; (iv) restrict dividends or other payments of the Company’s restricted subsidiaries; (v) create liens that secure debt; (vi) enter into transactions with affiliates, and (vii) merge or consolidate with another company. These covenants are subject to a number of important exceptions and qualifications. At any time when the 2022 Second Lien Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services, a division of The McGraw-Hill Companies, Inc., and no Default or Event of Default (each as defined in the 2022 Second Lien Notes Indenture) has occurred and is continuing, many of these covenants will terminate. The 2022 Second Lien Notes Indenture also provides for certain events of default. In the case of an event of default arising from certain events of bankruptcy, insolvency or reorganization with respect to the Company or any of the Company’s restricted subsidiaries that is a significant subsidiary, or any group of the Company’s restricted subsidiaries that, taken as a whole, would constitute a significant subsidiary of the Company, all outstanding 2022 Second Lien Notes will become due and immediately payable without further action or notice. If any other event of default occurs and is continuing, the trustee of the 2022 Second Lien Notes or the holders of at least 25% in aggregate principal amount of the then outstanding 2022 Second Lien Notes may declare all the 2022 Second Lien Notes to be due and payable immediately. Intercreditor Agreement On the Effective Date, Bank of America, N.A., as priority lien agent, The Bank of New York Mellon Trust Company, N.A., as second lien collateral agent, and The Bank of New York Mellon Trust Company, N.A., as the 2022 Second Lien Notes trustee, entered into an intercreditor agreement, which was acknowledged and agreed to by the Company and the Guarantor (the “Intercreditor Agreement”) to govern the relationship of holders of the 2022 Second Lien Notes, the lenders under the Amended Credit Agreement and holders of other priority lien obligations, with respect to collateral and certain other matters. Predecessor Senior Notes 2017 Convertible Notes. On March 6, 2012, the Predecessor Company issued in a private offering $300 million in aggregate principal amount of the 2017 Convertible Notes to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, as amended (the “Securities Act”). The 2017 Convertible Notes were convertible into cash, shares of our common stock or a combination of cash and shares of our common stock, based on an initial conversion rate of 23.4449 shares of our common stock per $1,000 principal amount of 2017 Convertible Notes, which corresponded to an initial conversion price of approximately $42.65 per share of our common stock at the time of the issuance of the 2017 Convertible Notes. On June 10, 2016, we completed a 1-for-10 reverse stock split with respect to our common stock and proportional adjustments were made to the conversion price and shares as they relate to the 2017 Convertible Notes, resulting in a conversion rate of 2.34449 shares of our common stock with a corresponding conversion price of $426.50 per share. The 2017 Convertible Notes were due on March 1, 2017. Upon emergence from bankruptcy on February 28, 2017, pursuant to the Plan, the $300 million of debt related to the 2017 Convertible Notes was cancelled. See Note 2 – Reorganization for additional details. During the three and nine months ended September 30, 2016 (Predecessor), we recognized $4.1 million and $12.0 million , respectively, of interest expense for the amortization of the discount, $0.4 million and $1.1 million , respectively, of interest expense for the amortization of deferred financing costs and $1.3 million and $3.9 million , respectively, of interest expense related to the contractual interest coupon on the 2017 Convertible Notes. 2022 Notes. On November 8, 2012 and November 27, 2013, respectively, the Predecessor Company completed the public offering of $300 million and $475 million aggregate principal amount of our 2022 Notes. The 2022 Notes were scheduled to mature on November 15, 2022. Upon emergence from bankruptcy, pursuant to the Plan, the $775 million of debt related to the 2022 Notes was cancelled. See Note 2 – Reorganization for additional details.

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
ASSET RETIREMENT OBLIGATIONS	ASSET RETIREMENT OBLIGATIONS Upon emergence from bankruptcy, as discussed in Note 3 – Fresh Start Accounting , the Company adopted fresh start accounting which included the adjustment of asset retirement obligations to estimated fair values at February 28, 2017. The change in our asset retirement obligations during the period from January 1, 2017 through February 28, 2017 (Predecessor) and the period from March 1, 2017 through September 30, 2017 (Successor) is set forth below (in millions, inclusive of current portion): Asset retirement obligations as of January 1, 2017 (Predecessor) $ 242.0 Liabilities settled (3.6 ) Divestment of properties (8.7 ) Accretion expense 5.4 Asset retirement obligations as of February 28, 2017 (Predecessor) 235.2 Fair value fresh start adjustment 54.9 Asset retirement obligations as of February 28, 2017 (Successor) 290.1 Liabilities settled (53.1 ) Accretion expense 19.7 Revision of estimates 11.0 Asset retirement obligations as of September 30, 2017 (Successor) $ 267.6

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2017
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES As a result of the significant declines in commodity prices and the resulting ceiling test write-downs and net losses incurred, we determined during 2015 that it was more likely than not that a portion of our deferred tax assets will not be realized in the future. Accordingly, we established a valuation allowance against a portion of our deferred tax assets. As of September 30, 2017 (Successor), our valuation allowance totaled $236.7 million. Our assessment of the realizability of our deferred tax assets is based on the weight of all available evidence, both positive and negative, including future reversals of deferred tax liabilities. We had a current income tax receivable of $ 27.7 million at September 30, 2017 (Successor), which primarily relates to expected tax refunds from the carryback of net operating losses to previous tax years.

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) Through December 31, 2016, we designated our commodity derivatives as cash flow hedges for accounting purposes upon entering into the contracts, and accordingly, changes in the fair value of the derivative were recognized in stockholders’ equity through other comprehensive income (loss), net of related taxes, to the extent the hedge was considered effective. We had no outstanding derivative contracts at December 31, 2016. During the periods from March 1, 2017 through September 30, 2017 (Successor) and January 1, 2017 through February 28, 2017 (Predecessor), we entered into various commodity derivative contracts (see Note 9 – Derivative Instruments and Hedging Activities ). With respect to our 2017, 2018 and 2019 commodity derivative contracts, we have elected to not designate these contracts as cash flow hedges for accounting purposes. Accordingly, the net changes in the mark-to-market valuations and the monthly settlements on these derivative contracts will be recorded in earnings through derivative income (expense). Changes in accumulated other comprehensive income (loss) by component for the three and nine months ended September 30, 2016 (Predecessor), were as follows (in millions): Cash Flow Hedges Three Months Ended September 30, 2016 (Predecessor) Beginning balance, net of tax $ 7.4 Other comprehensive income (loss) before reclassifications: Change in fair value of derivatives 2.3 Income tax effect (0.8 ) Net of tax 1.5 Amounts reclassified from accumulated other comprehensive income: Operating revenue: oil/natural gas production 7.7 Income tax effect (2.7 ) Net of tax 5.0 Other comprehensive loss, net of tax (3.5 ) Ending balance, net of tax $ 3.9 Cash Flow Foreign Total Nine Months Ended September 30, 2016 (Predecessor) Beginning balance, net of tax $ 24.0 $ (6.0 ) $ 18.0 Other comprehensive income (loss) before reclassifications: Change in fair value of derivatives (1.7 ) — (1.7 ) Income tax effect 0.6 — 0.6 Net of tax (1.1 ) — (1.1 ) Amounts reclassified from accumulated other comprehensive income: Operating revenue: oil/natural gas production 29.4 — 29.4 Other operational expenses — (6.0 ) (6.0 ) Income tax effect (10.4 ) — (10.4 ) Net of tax 19.0 (6.0 ) 13.0 Other comprehensive income (loss), net of tax (20.1 ) 6.0 (14.1 ) Ending balance, net of tax $ 3.9 $ — $ 3.9 During the nine months ended September 30, 2016 (Predecessor), we reclassified a $6.0 million loss related to cumulative foreign currency translation adjustments from accumulated other comprehensive income into other operational expenses upon the substantial liquidation of our foreign subsidiary, Stone Energy Canada ULC.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2017
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS U.S. Generally Accepted Accounting Principles establish a fair value hierarchy that has three levels based on the reliability of the inputs used to determine the fair value. These levels include: Level 1, defined as inputs such as unadjusted quoted prices in active markets for identical assets or liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs for use when little or no market data exists, therefore requiring an entity to develop its own assumptions. As of September 30, 2017 (Successor) and December 31, 2016 (Predecessor), we held certain financial assets that are required to be measured at fair value on a recurring basis, including our commodity derivative instruments and our investments in marketable securities. We utilize the services of an independent third party to assist us in valuing our derivative instruments. The income approach is used in this determination utilizing the third party’s proprietary pricing model. The model accounts for our credit risk and the credit risk of our counterparties in the discount rate applied to estimated future cash inflows and outflows. Our swap contracts are included within the Level 2 fair value hierarchy, and our collar and put contracts are included within the Level 3 fair value hierarchy. Significant unobservable inputs used in establishing fair value for the collars and puts were the volatility impacts in the pricing model as it relates to the call portion of the collar and the floor of the put. For a more detailed description of our derivative instruments, see Note 9 – Derivative Instruments and Hedging Activities . We used the market approach in determining the fair value of our investments in marketable securities, which are included within the Level 1 fair value hierarchy. The following tables present our assets and liabilities that are measured at fair value on a recurring basis at September 30, 2017 (Successor) (in millions). Fair Value Measurements Successor as of September 30, 2017 Assets Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Marketable securities (Other assets) $ 9.3 $ 9.3 $ — $ — Derivative contracts 3.6 — 0.5 3.1 Total $ 12.9 $ 9.3 $ 0.5 $ 3.1 Fair Value Measurements at Successor as of September 30, 2017 Liabilities Total Quoted Prices in Active Markets for Identical Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Derivative contracts $ 0.5 $ — $ 0.1 $ 0.4 Total $ 0.5 $ — $ 0.1 $ 0.4 We had no liabilities measured at fair value on a recurring basis at December 31, 2016 (Predecessor). The following table presents our assets that are measured at fair value on a recurring basis at December 31, 2016 (Predecessor) (in millions). Fair Value Measurements Predecessor as of December 31, 2016 Assets Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Marketable securities (Other assets) $ 8.7 $ 8.7 $ — $ — Total $ 8.7 $ 8.7 $ — $ — The table below presents a reconciliation for assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the period from March 1, 2017 through September 30, 2017 (Successor) and the period from January 1, 2017 through February 28, 2017 (Predecessor) (in millions). Hedging Contracts, net Balance as of January 1, 2017 (Predecessor) $ — Total gains/(losses) (realized or unrealized): Included in earnings (0.6 ) Included in other comprehensive income — Purchases, sales, issuances and settlements 3.7 Transfers in and out of Level 3 — Balance as of February 28, 2017 (Successor) 3.1 Total gains/(losses) (realized or unrealized): Included in earnings (1.3 ) Included in other comprehensive income — Purchases, sales, issuances and settlements 1.0 Transfers in and out of Level 3 — Balance as of September 30, 2017 (Successor) $ 2.8 The amount of total gains/(losses) for the period included in earnings (derivative income) attributable to the change in unrealized gain/(losses) relating to derivatives still held at September 30, 2017 $ (1.7 ) The fair value of cash and cash equivalents approximated book value at September 30, 2017 and December 31, 2016 . Upon emergence from bankruptcy on February 28, 2017, the 2017 Convertible Notes and 2022 Notes were cancelled, and the Company issued the 2022 Second Lien Notes. As of December 31, 2016 , the fair value of the liability component of the 2017 Convertible Notes was approximately $293.5 million . As of December 31, 2016 , the fair value of the 2022 Notes was approximately $465.0 million . As of September 30, 2017 , the fair value of the 2022 Second Lien Notes was approximately $220.5 million . The fair values of the 2022 Notes and the 2022 Second Lien Notes were determined based on quotes obtained from brokers, which represent Level 1 inputs. We applied fair value concepts in determining the liability component of the 2017 Convertible Notes at inception and December 31, 2016 . The fair value of the liability was estimated using an income approach. The significant inputs in these determinations were market interest rates based on quotes obtained from brokers and represent Level 2 inputs. On February 28, 2017, the Company emerged from bankruptcy and adopted fresh start accounting, which resulted in the Company becoming a new entity for financial reporting purposes. Upon the adoption of fresh start accounting, the Company’s assets and liabilities were recorded at their fair values as of the fresh start reporting date, February 28, 2017. See Note 3 – Fresh Start Accounting for a detailed discussion of the fair value approaches used by the Company. The inputs utilized in the valuation of our most significant asset, our oil and gas properties, included mostly unobservable inputs, which fall within Level 3 of the fair value hierarchy.

FEDERAL ROYALTY RECOVERY

FEDERAL ROYALTY RECOVERY	9 Months Ended
	Sep. 30, 2017
Federal Royalty Recovery [Abstract]
Federal Royalty Refund	FEDERAL ROYALTY RECOVERY In July 2017, we received a federal royalty recovery totaling $14.1 million as part of a multi-year federal royalty refund claim. Approximately $9.6 million of the refund was recognized as other operational income and $4.5 million as a reduction of lease operating expenses during the three months ended September 30, 2017 (Successor). Included in SG&A expenses during the three months ended September 30, 2017 (Successor) is a $3.9 million success-based consulting fee incurred in connection with the federal royalty recovery.

REDUCTION IN WORKFORCE

REDUCTION IN WORKFORCE	9 Months Ended
	Sep. 30, 2017
Restructuring and Related Activities [Abstract]
Reduction in Workforce	REDUCTION IN WORKFORCE During the second quarter of 2017, we implemented workforce reduction plans to better align our employee base with current business needs, resulting in a reduction of approximately 20% of our total workforce. The workforce reductions were complete as of July 31, 2017. In connection with the reductions, we recognized a charge of $5.7 million during the three months ended June 30, 2017 (Successor), consisting primarily of severance payments to affected employees and payment of related employer payroll taxes. This charge is reflected in SG&A expenses on the statement of operations. Approximately $4.5 million of the workforce reduction costs were paid in cash during the second quarter of 2017. At June 30, 2017, we recorded a liability of $1.2 million for severance payments and related employer payroll taxes. The liability was fully paid in July 2017. In addition to the workforce reduction costs, during the three months ended June 30, 2017 (Successor), we recognized a charge of $3.0 million for severance costs related to the sale of the Appalachia Properties and the retirement of the prior chief executive officer of the Company. These severance costs are reflected in SG&A expenses on the statement of operations.

OTHER OPERATIONAL EXPENSES

OTHER OPERATIONAL EXPENSES	9 Months Ended
	Sep. 30, 2017
Other Income and Expenses [Abstract]
OTHER OPERATIONAL EXPENSES	OTHER OPERATIONAL EXPENSES Other operational expenses for the period from March 1, 2017 through September 30, 2017 (Successor) totaled $3.3 million , comprised primarily of $2.1 million of stacking charges related to the platform rig at Pompano, while awaiting demobilization. Other operational expenses for the nine months ended September 30, 2016 (Predecessor) totaled $49.3 million . Included in other operational expenses for the nine months ended September 30, 2016 (Predecessor) is a $6.0 million loss on the substantial liquidation of our foreign subsidiary, Stone Energy Canada ULC, representing cumulative foreign currency translation adjustments, which were reclassified from accumulated other comprehensive income during the first quarter of 2016. See Note 14 – Accumulated Other Comprehensive Income (Loss) . Also included in other operational expenses for the nine months ended September 30, 2016 (Predecessor) are $15.3 million of rig subsidy and stacking charges related to the ENSCO 8503 deep water drilling rig, an Appalachian drilling rig and the platform rig at Pompano, a $20 million charge related to the termination of our deep water drilling rig contract with Ensco and $7.5 million of charges related to the terminations of the Appalachian drilling rig contract and a contract with an offshore vessel provider.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES On March 21, 2016, we received notice letters from the Bureau of Ocean Energy Management (“BOEM”) stating that BOEM had determined that we no longer qualified for a supplemental bonding waiver under the financial criteria specified in BOEM’s guidance to lessees at such time. In late March 2016, we proposed a tailored plan to BOEM for financial assurances relating to our abandonment obligations, which provides for posting some incremental financial assurances in favor of BOEM. On May 13, 2016, we received notice letters from BOEM rescinding its demand for supplemental bonding with the understanding that we will continue to make progress with BOEM towards finalizing and implementing our long-term tailored plan. In July 2016, BOEM issued a Notice to Lessees (“NTL”), with an effective date of September 12, 2016, that augments requirements for the posting of additional financial assurances by offshore lessees. The NTL discontinues the policy of Supplemental Bonding Waivers and allows for the ability to self-insure up to 10% of a company’s tangible net worth, where a company can demonstrate a certain level of financial strength. The NTL also provides new procedures for how BOEM determines a lessee’s decommissioning obligations. A global update of the GOM decommissioning estimates was made on August 29, 2016, and BOEM requested that we resubmit our tailored plan to reflect the updated decommissioning estimates. We received a Self-Insurance letter from BOEM dated September 30, 2016 stating that we are not eligible to self-insure any of our additional security obligations and received a Proposal letter from BOEM dated October 20, 2016 indicating that additional security may be required. The September 30, 2016 Self-Insurance determination letter was rescinded by BOEM on March 24, 2017. In the first quarter of 2017, BOEM announced that it would extend the implementation timeline for the new NTL by an additional six months. In September 2017, BOEM again postponed any implementation of the July 2016 NTL, and has indicated they may be issuing a modified or substitute NTL in late 2017. Currently, we have posted an aggregate of approximately $118 million in surety bonds in favor of BOEM, third party bonds and letters of credit, all relating to our offshore abandonment obligations. The bonds represent guarantees by the surety insurance companies that we will operate in accordance with applicable rules and regulations and perform certain plugging and abandonment obligations as specified by applicable working interest purchase and sale agreements. A revised tailored plan may require incremental financial assurance or bonding for non-sole liability properties, dependent on adjustments following ongoing discussions with BOEM and the Bureau of Safety and Environmental Enforcement (“BSEE”), and any modifications to the proposed NTL. There is no assurance that our current tailored plan will be approved by BOEM, and BOEM may require further revisions to our plan.

NEW YORK STOCK EXCHANGE COMPLIA

NEW YORK STOCK EXCHANGE COMPLIANCE	9 Months Ended
	Sep. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
NEW YORK STOCK EXCHANGE COMPLIANCE	NEW YORK STOCK EXCHANGE COMPLIANCE On May 17, 2016, we were notified by the New York Stock Exchange (the “NYSE”) that our average global market capitalization had been less than $50 million over a consecutive 30 trading-day period at the same time that our stockholders’ equity was less than $50 million , which is non-compliant with Section 802.01B of the NYSE Listed Company Manual. On June 30, 2016, we submitted our 18-month business plan for curing the average market capitalization and stockholders’ equity deficiencies to the NYSE, and on August 4, 2016, the NYSE accepted the Plan. All of our quarterly updates to the business plan were accepted by the NYSE. Since March 1, 2017, the first day of trading subsequent to the effective date of the Company’s plan of reorganization, the Successor Company has maintained a market capitalization above $50 million . On August 24, 2017, we were notified by the NYSE that we are back in compliance with their continued listing standards as a result of the Company’s consistent positive performance with respect to the original business plan submission and the achievement of compliance with the average global market capitalization and stockholders’ equity listing requirements over the past two quarters. In accordance with the NYSE’s Listed Company Manual, we will be subject to a 12-month follow up period within which the Company will be reviewed to ensure that the Company does not fall below any of the NYSE’s continued listing standards.

FINANCIAL STATEMENT PRESENTAT27

FINANCIAL STATEMENT PRESENTATION (Policies)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Basis of Presentation	Interim Financial Statements The condensed consolidated financial statements of Stone Energy Corporation (“Stone” or the “Company”) and its subsidiaries as of September 30, 2017 (Successor) and for the three month period ended September 30, 2017 (Successor), the periods from March 1, 2017 through September 30, 2017 (Successor), January 1, 2017 through February 28, 2017 (Predecessor) and the three and nine months ended September 30, 2016 (Predecessor) are unaudited and reflect all adjustments (consisting only of normal recurring adjustments), which are, in the opinion of management, necessary for a fair presentation of the financial position and operating results for the interim periods. The condensed consolidated balance sheet as of December 31, 2016 (Predecessor) has been derived from the audited financial statements as of that date contained in our Annual Report on Form 10-K for the year ended December 31, 2016 (our “ 2016 Annual Report on Form 10-K”). The condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto, together with management’s discussion and analysis of financial condition and results of operations, contained in our 2016 Annual Report on Form 10-K, although, as described below, such prior financial statements will not be comparable to the interim financial statements due to the adoption of fresh start accounting on February 28, 2017. For additional information, see Note 3 – Fresh Start Accounting . The results of operations for the period from March 1, 2017 through September 30, 2017 (Successor) are not necessarily indicative of future financial results. Certain prior period amounts have been reclassified to conform to current period presentation. Emergence from Voluntary Reorganization Under Chapter 11 Proceedings On December 14, 2016, the Company and its subsidiaries Stone Energy Offshore, L.L.C. (“Stone Offshore”) and Stone Energy Holding, L.L.C. (together with the Company, the “Debtors”) filed voluntary petitions (the “Bankruptcy Petitions”) in the United States Bankruptcy Court for the Southern District of Texas, Houston Division (the “Bankruptcy Court”) seeking relief under the provisions of Chapter 11 of Title 11 (“Chapter 11”) of the United States Bankruptcy Code (the “Bankruptcy Code”). On February 15, 2017, the Bankruptcy Court entered an order (the “Confirmation Order”) confirming the Second Amended Joint Prepackaged Plan of Reorganization of Stone Energy Corporation and its Debtor Affiliates, dated December 28, 2016 (the “Plan”), as modified by the Confirmation Order, and on February 28, 2017, the Plan became effective (the “Effective Date”) and the Debtors emerged from bankruptcy, with the bankruptcy cases then being closed by Final Decree Closing Chapter 11 Cases and Terminating Claims Agent Services entered by the Bankruptcy Court on April 20, 2017. Upon emergence from bankruptcy, the Company adopted fresh start accounting in accordance with the provisions of Accounting Standards Codification (“ASC”) 852, “ Reorganizations ”, which resulted in the Company becoming a new entity for financial reporting purposes on the Effective Date. As a result of the adoption of fresh start accounting, the Company’s unaudited condensed consolidated financial statements subsequent to February 28, 2017 will not be comparable to its financial statements prior to that date. See Note 3 – Fresh Start Accounting for further details on the impact of fresh start accounting on the Company’s unaudited condensed consolidated financial statements. References to “Successor” or “Successor Company” relate to the financial position and results of operations of the reorganized Company subsequent to February 28, 2017. References to “Predecessor” or “Predecessor Company” relate to the financial position and results of operations of the Company prior to, and including, February 28, 2017.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with U.S. Generally Accepted Accounting Principles requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates on historical experience and on various other assumptions and information believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects are uncertain and, accordingly, these estimates may change as new events occur, as additional information is obtained and as the Company’s operating environment changes. Actual results could differ from those estimates. Estimates are used primarily when accounting for depreciation, depletion and amortization (“DD&A”) expense, unevaluated property costs, estimated future net cash flows from proved reserves, costs to abandon oil and gas properties, income taxes, accruals of capitalized costs, operating costs and production revenue, capitalized general and administrative costs and interest, insurance recoveries, estimated fair value of derivative contracts, contingencies and fair value estimates, including estimates of reorganization value, enterprise value and the fair value of assets and liabilities recorded as a result of the adoption of fresh start accounting.
Recently Issued Accounting Standards	Recently Issued Accounting Standards In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “ Revenue from Contracts with Customers (Topic 606) ” to clarify the principles for recognizing revenue and to develop a common revenue standard and disclosure requirements. The standard may be applied retrospectively or using a modified retrospective approach, with the cumulative effect of initially applying ASU 2014-09 recognized at the date of initial application. In August 2015, the FASB issued ASU 2015-14, deferring the effective date of ASU 2014-09 by one year. As a result, the standard is effective for interim and annual periods beginning on or after December 15, 2017. We expect to apply the modified retrospective approach upon adoption of this standard. Although we are still evaluating the effect that this new standard may have on our financial statements and related disclosures, we do not anticipate that the implementation of this new standard will have a material effect. In February 2016, the FASB issued ASU 2016-02, “ Leases (Topic 842) ” to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The standard is effective for public entities for fiscal years beginning after December 15, 2018, and for interim periods within those fiscal years, with earlier application permitted. Upon adoption the lessee will apply the new standard retrospectively to all periods presented or retrospectively using a cumulative effect adjustment in the year of adoption. We are currently evaluating the effect that this new standard may have on our financial statements and related disclosures. In March 2016, the FASB issued ASU 2016-09, “ Compensation – Stock Compensation (Topic 718) ” to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and forfeitures, as well as classification in the statement of cash flows. ASU 2016-09 became effective for us on January 1, 2017. Under ASU 2016-09, the Company elected to not apply a forfeiture estimate and will recognize a credit in compensation expense to the extent awards are forfeited. The implementation of this new standard did not have a material effect on our financial statements or related disclosures. In August 2017, the FASB issued ASU 2017-12, “ Derivatives and Hedging (Topic 815) ” to improve the financial reporting of hedging relationships to better reflect an entity’s hedging strategies. The standard expands an entity’s ability to apply hedge accounting for both non-financial and financial risk components and amends the presentation and disclosure requirements. Additionally, ASU 2017-12 eliminates the need to separately measure and report hedge ineffectiveness and generally requires the entire change in fair value of a hedging instrument to be recorded in the same income statement line as the earnings effect of the hedged item. The standard is effective for public companies for fiscal years beginning after December 15, 2018 and interim periods within those fiscal years. Early adoption is permitted. The standard must be adopted by applying a modified retrospective approach to existing designated hedging relationships as of the adoption date, with a cumulative effect adjustment recorded to opening retained earnings as of the initial adoption date. We are currently evaluating the effect that this new standard may have on our financial statements and related disclosures.
Derivatives	Our hedging strategy is designed to protect our near and intermediate term cash flows from future declines in oil and natural gas prices. This protection is essential to capital budget planning, which is sensitive to expenditures that must be committed to in advance, such as rig contracts and the purchase of tubular goods. We enter into derivative transactions to secure a commodity price for a portion of our expected future production that is acceptable at the time of the transaction. We do not enter into derivative transactions for trading purposes. All derivatives are recognized as assets or liabilities on the balance sheet and are measured at fair value. At the end of each quarterly period, these derivatives are marked-to-market. If the derivative does not qualify or is not designated as a cash flow hedge, subsequent changes in the fair value of the derivative are recognized in earnings through derivative income (expense) in the statement of operations. If the derivative qualifies and is designated as a cash flow hedge, subsequent changes in the fair value of the derivative are recognized in stockholders’ equity through other comprehensive income (loss), net of related taxes, to the extent the hedge is considered effective. Monthly settlements of effective hedges are reflected in revenue from oil and natural gas production. Monthly settlements of ineffective hedges and derivatives not designated or that do not qualify for hedge accounting are recognized in earnings through derivative income (expense). The resulting cash flows from all monthly settlements are reported as cash flows from operating activities. Through December 31, 2016, we designated our commodity derivatives as cash flow hedges for accounting purposes upon entering into the contracts. A small portion of our cash flow hedges were typically determined to be ineffective because oil and natural gas price changes in the markets in which we sell our products were not 100% correlative to changes in the underlying price basis indicative in the derivative contract. We had no outstanding derivatives at December 31, 2016. With respect to our 2017, 2018 and 2019 commodity derivative contracts, we have elected to not designate these contracts as cash flow hedges for accounting purposes. Accordingly, the net changes in the mark-to-market valuations and the monthly settlements on these derivative contracts will be recorded in earnings through derivative income (expense). We have entered into put contracts, fixed-price swaps and collar contracts with various counterparties for a portion of our expected 2017, 2018 and 2019 oil and natural gas production from the Gulf Coast Basin. All of our derivative transactions have been carried out in the over-the-counter market and are not typically subject to margin-deposit requirements. The use of derivative instruments involves the risk that the counterparties will be unable to meet the financial terms of such transactions. The counterparties to all of our derivative instruments have an “investment grade” credit rating. We monitor the credit ratings of our derivative counterparties on an ongoing basis. Although we typically enter into derivative contracts with multiple counterparties to mitigate our exposure to any individual counterparty, if any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection, we may not realize the benefit of some of our derivative instruments and incur a loss. At November 1, 2017 , our derivative instruments were with five counterparties, two of which accounted for approximately 64% of our contracted volumes. Currently, all of our outstanding derivative instruments are with lenders under our current bank credit facility. Put contracts are purchased at a rate per unit of hedged production that fluctuates with the commodity futures market. The historical cost of the put contract represents our maximum cash exposure. We are not obligated to make any further payments under the put contract regardless of future commodity price fluctuations. Under put contracts, monthly payments are made to us if the New York Mercantile Exchange (“NYMEX”) prices fall below the agreed upon floor price, while allowing us to fully participate in commodity prices above the floor. Swaps typically provide for monthly payments by us if prices rise above the swap price or monthly payments to us if prices fall below the swap price. Collar contracts typically require payments by us if the NYMEX average closing price is above the ceiling price or payments to us if the NYMEX average closing price is below the floor price. Settlements for our oil put contracts, oil collar contracts and fixed-price oil swaps are based on an average of the NYMEX closing price for West Texas Intermediate crude oil during the entire calendar month. Settlements for our natural gas collar contracts and fixed-price natural gas swaps are based on the NYMEX price for the last day of a respective contract month.
Fair Value of Financial Instruments	U.S. Generally Accepted Accounting Principles establish a fair value hierarchy that has three levels based on the reliability of the inputs used to determine the fair value. These levels include: Level 1, defined as inputs such as unadjusted quoted prices in active markets for identical assets or liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs for use when little or no market data exists, therefore requiring an entity to develop its own assumptions. As of September 30, 2017 (Successor) and December 31, 2016 (Predecessor), we held certain financial assets that are required to be measured at fair value on a recurring basis, including our commodity derivative instruments and our investments in marketable securities. We utilize the services of an independent third party to assist us in valuing our derivative instruments. The income approach is used in this determination utilizing the third party’s proprietary pricing model. The model accounts for our credit risk and the credit risk of our counterparties in the discount rate applied to estimated future cash inflows and outflows. Our swap contracts are included within the Level 2 fair value hierarchy, and our collar and put contracts are included within the Level 3 fair value hierarchy. Significant unobservable inputs used in establishing fair value for the collars and puts were the volatility impacts in the pricing model as it relates to the call portion of the collar and the floor of the put. For a more detailed description of our derivative instruments, see Note 9 – Derivative Instruments and Hedging Activities . We used the market approach in determining the fair value of our investments in marketable securities, which are included within the Level 1 fair value hierarchy.

FRESH START ACCOUNTING (Tables)

FRESH START ACCOUNTING (Tables)	9 Months Ended
	Sep. 30, 2017
Reorganizations [Abstract]
Reconciliation of Enterprise Value to Estimated Fair Value of Successor Common Stock	The following table reconciles the enterprise value per the Plan to the estimated fair value (for fresh start accounting purposes) of the Successor Company’s common stock as of February 28, 2017 (in thousands, except per share value): February 28, 2017 Enterprise value $ 419,720 Plus: Cash and other assets 371,169 Less: Fair value of debt (236,261 ) Less: Fair value of warrants (15,648 ) Fair value of Successor common stock $ 538,980 Shares issued upon emergence 20,000 Per share value $ 26.95
Reconciliation of Enterprise Value to Estimated Reorganization Value	The following table reconciles the enterprise value per the Plan to the estimated reorganization value as of the Effective Date (in thousands): February 28, 2017 Enterprise value $ 419,720 Plus: Cash and other assets 371,169 Plus: Asset retirement obligations (current and long-term) 290,067 Plus: Working capital and other liabilities 58,055 Reorganization value of Successor assets $ 1,139,011
Schedule of Fresh-Start Adjustments	The following table reflects the reorganization and application of ASC 852 on our consolidated balance sheet as of February 28, 2017 (in thousands): Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company Assets Current assets: Cash and cash equivalents $ 198,571 $ (35,605 ) (1) $ — $ 162,966 Restricted cash — 75,547 (1) — 75,547 Accounts receivable 42,808 9,301 (2) — 52,109 Fair value of derivative contracts 1,267 — — 1,267 Current income tax receivable 22,516 — — 22,516 Other current assets 10,924 875 (3) (124 ) (12) 11,675 Total current assets 276,086 50,118 (124 ) 326,080 Oil and gas properties, full cost method of accounting: Proved 9,633,907 (188,933 ) (1) (8,774,122 ) (12) 670,852 Less: accumulated DD&A (9,215,679 ) — 9,215,679 (12) — Net proved oil and gas properties 418,228 (188,933 ) 441,557 670,852 Unevaluated 371,140 (127,838 ) (1) (146,292 ) (12) 97,010 Other property and equipment, net 25,586 (101 ) (4) (4,423 ) (13) 21,062 Fair value of derivative contracts 1,819 — — 1,819 Other assets, net 26,516 (4,328 ) (5) — 22,188 Total assets $ 1,119,375 $ (271,082 ) $ 290,718 $ 1,139,011 Liabilities and Stockholders’ Equity Current liabilities: Accounts payable to vendors $ 20,512 $ — $ — $ 20,512 Undistributed oil and gas proceeds 5,917 (4,139 ) (1) — 1,778 Accrued interest 266 — — 266 Asset retirement obligations 92,597 — — 92,597 Fair value of derivative contracts 476 — — 476 Current portion of long-term debt 411 — — 411 Other current liabilities 17,032 (195 ) (6) — 16,837 Total current liabilities 137,211 (4,334 ) — 132,877 Long-term debt 352,350 (116,500 ) (7) — 235,850 Asset retirement obligations 151,228 (8,672 ) (1) 54,914 (14) 197,470 Fair value of derivative contracts 653 — — 653 Other long-term liabilities 17,533 — — 17,533 Total liabilities not subject to compromise 658,975 (129,506 ) 54,914 584,383 Liabilities subject to compromise 1,110,182 (1,110,182 ) (8) — — Total liabilities 1,769,157 (1,239,688 ) 54,914 584,383 Commitments and contingencies Stockholders’ equity: Common stock (Predecessor) 56 (56 ) (9) — — Treasury stock (Predecessor) (860 ) 860 (9) — — Additional paid-in capital (Predecessor) 1,660,810 (1,660,810 ) (9) — — Common stock (Successor) — 200 (10) — 200 Additional paid-in capital (Successor) — 554,428 (10) — 554,428 Accumulated deficit (2,309,788 ) 2,073,984 (11) 235,804 (15) — Total stockholders’ equity (649,782 ) 968,606 235,804 554,628 Total liabilities and stockholders’ equity $ 1,119,375 $ (271,082 ) $ 290,718 $ 1,139,011 Reorganization Adjustments (dollar amounts in thousands, except per share values) 1. Reflects the net cash proceeds received from the sale of the Appalachia Properties in connection with the Plan and net cash payments made as of the Effective Date from implementation of the Plan: Sources: Net cash proceeds from sale of Appalachia Properties (a) $ 512,472 Total sources 512,472 Uses: Cash transferred to restricted account (b) 75,547 Break-up fee to Tug Hill 10,800 Repayment of outstanding borrowings under Pre-Emergence Credit Agreement 341,500 Repayment of 2017 Convertible Notes and 2022 Notes 100,000 Other fees and expenses (c) 20,230 Total uses 548,077 Net uses $ (35,605 ) (a) The closing of the sale of the Appalachia Properties occurred on February 27, 2017, but as emergence was contingent on such closing, the effects of the transaction are reflected as reorganization adjustments. See Note 7 – Divestiture for additional details on the sale. Total consideration received for the sale of the Appalachia Properties of $522,472 included cash consideration of $512,472 received at closing and a $10,000 indemnity escrow which was released subsequent to emergence from bankruptcy (see Reorganization Adjustments item number 2 below). (b) Reflects the movement of $75,000 of cash held in a restricted account to satisfy near-term plugging and abandonment liabilities, pursuant to the provisions of the Amended Credit Agreement (as defined in Note 10 – Debt ), and $547 held in a restricted cash account for certain cure amounts in connection with the Chapter 11 proceedings. (c) Other fees and expenses include approximately $15,180 of emergence and success fees, $2,600 of professional fees and $2,395 of payments made to seismic providers in settlement of their bankruptcy claims. 2. Reflects a receivable for a $10,000 indemnity escrow with release delayed until emergence from bankruptcy, net of a $699 reimbursement to Tug Hill in connection with the sale of the Appalachia Properties (see Note 7 – Divestiture ). 3. Reflects the payment of a claim to a seismic provider as a prepayment/deposit. 4. Reflects the sale of vehicles in connection with the sale of the Appalachia Properties. 5. Reflects the write-off of $2,577 of unamortized debt issuance costs related to the Pre-Emergence Credit Agreement and the reversal of a $1,750 prepayment made to Tug Hill in October 2016. 6. Reflects the accrual of $2,008 in expected bonus payments under the KEIP (as defined in Note 5 – Share–Based Compensation and Employee Benefit Plans ) and a $395 termination fee in connection with the early termination of an office lease, less the settlement of a property tax accrual of $2,598 in connection with the sale of the Appalachia Properties. 7. Reflects the repayment of $341,500 of outstanding borrowings under the Pre-Emergence Credit Agreement and the issuance of $225,000 of 2022 Second Lien Notes as part of the settlement of the Predecessor Company 2017 Convertible Notes and 2022 Notes. 8. Liabilities subject to compromise were settled as follows in accordance with the Plan: 1 ¾% Senior Convertible Notes due 2017 $ 300,000 7 ½% Senior Notes due 2022 775,000 Accrued interest 35,182 Liabilities subject to compromise of the Predecessor Company 1,110,182 Cash payment to senior noteholders (100,000 ) Issuance of 2022 Second Lien Notes to former holders of the senior notes (225,000 ) Fair value of equity issued to unsecured creditors (538,980 ) Fair value of warrants issued to unsecured creditors (15,648 ) Gain on settlement of liabilities subject to compromise $ 230,554 9. Reflects the cancellation of the Predecessor Company’s common stock, treasury stock and additional paid-in capital. 10. Reflects the issuance of Successor Company equity. In accordance with the Plan, the Successor Company issued 19.0 million shares of New Common Stock to the former holders of the 2017 Convertible Notes and the 2022 Notes and 1.0 million shares of New Common Stock to the Predecessor Company’s common stockholders. These amounts are subject to dilution by warrants issued to the Predecessor Company common stockholders, totaling approximately 3.5 million shares, with an exercise price of $42.04 per share and a term of four years . The fair value of the warrants was estimated at $4.43 per share using a Black-Scholes-Merton valuation model. 11. Reflects the cumulative impact of the reorganization adjustments discussed above: Gain on settlement of liabilities subject to compromise $ 230,554 Professional and other fees paid at emergence (10,648 ) Write-off of unamortized deferred financing costs (2,577 ) Other reorganization adjustments (1,915 ) Net impact to reorganization items 215,414 Gain on sale of Appalachia Properties 213,453 Cancellation of Predecessor Company equity 1,662,282 Other adjustments to accumulated deficit (17,165 ) Net impact to accumulated deficit $ 2,073,984 Fresh Start Adjustments 12. Fair value adjustments to oil and gas properties, associated inventory and unproved acreage. See above for a detailed discussion of the fair value methodology. 13. Fair value adjustment for an office building owned by the Company. The income and sales comparison approaches were used in determining the fair value, using anticipated future earnings and an appropriate expected rate of return, as well as relying upon recent sales or offerings of similar assets. 14. Fair value adjustments to the Company’s asset retirement obligations using estimated plugging and abandonment costs as of the Effective Date, adjusted for inflation and discounted at the Successor Company’s credit-adjusted risk free rate. 15. Reflects the cumulative effect of the fresh start accounting adjustments discussed above.
Summary of Reorganization Items	The following table summarizes reorganization items, net (in thousands): Predecessor Period from Gain on settlement of liabilities subject to compromise $ 230,554 Fresh start valuation adjustments 235,804 Reorganization professional fees and other expenses (20,512 ) Write-off of deferred financing costs (2,577 ) Other reorganization items (5,525 ) Gain on reorganization items, net $ 437,744 The cash payments for reorganization items for the period from January 1, 2017 through February 28, 2017 include approximately $10.6 million of emergence and success fees and approximately $9.1 million of other reorganization professional fees and expenses paid on the Effective Date.

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	9 Months Ended
	Sep. 30, 2017
Earnings Per Share [Abstract]
Calculation of Basic and Diluted Weighted Average Shares Outstanding Earnings Per Share	The following tables set forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods (in thousands, except per share amounts): Successor Predecessor Three Months Ended Three Months Ended Income (numerator): Basic: Net income (loss) $ 1,297 $ (89,635 ) Net income attributable to participating securities (4 ) — Net income (loss) attributable to common stock - basic $ 1,293 $ (89,635 ) Diluted: Net income (loss) $ 1,297 $ (89,635 ) Net income attributable to participating securities (4 ) — Net income (loss) attributable to common stock - diluted $ 1,293 $ (89,635 ) Weighted average shares (denominator): Weighted average shares - basic 19,997 5,600 Dilutive effect of stock options — — Dilutive effect of warrants — — Dilutive effect of convertible notes — — Weighted average shares - diluted 19,997 5,600 Basic income (loss) per share $ 0.06 $ (16.01 ) Diluted income (loss) per share $ 0.06 $ (16.01 ) Successor Predecessor Period from Period from Nine Months Ended Income (numerator): Basic: Net income (loss) $ (264,777 ) $ 630,317 $ (474,180 ) Net income attributable to participating securities — (4,995 ) — Net income (loss) attributable to common stock - basic $ (264,777 ) $ 625,322 $ (474,180 ) Diluted: Net income (loss) $ (264,777 ) $ 630,317 $ (474,180 ) Net income attributable to participating securities — (4,995 ) — Net income (loss) attributable to common stock - diluted $ (264,777 ) $ 625,322 $ (474,180 ) Weighted average shares (denominator): Weighted average shares - basic 19,997 5,634 5,585 Dilutive effect of stock options — — — Dilutive effect of warrants — — — Dilutive effect of convertible notes — — — Weighted average shares - diluted 19,997 5,634 5,585 Basic income (loss) per share $ (13.24 ) $ 110.99 $ (84.90 ) Diluted income (loss) per share $ (13.24 ) $ 110.99 $ (84.90 )

DIVESTITURE (Tables)

DIVESTITURE (Tables)	9 Months Ended
	Sep. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Net Gain Recognized in Sale	Since accounting for the sale of these oil and gas properties as a reduction of the capitalized costs of oil and gas properties would have significantly altered the relationship between capitalized costs and reserves, we recognized a gain on the sale of $213.5 million during the period from January 1, 2017 through February 28, 2017 (Predecessor), computed as follows (in millions): Net consideration received for sale of Appalachia Properties $ 522.5 Add: Release of funds held in suspense 4.1 Transfer of asset retirement obligations 8.7 Other adjustments, net 2.6 Less: Transaction costs (7.1 ) Carrying value of properties sold (317.3 ) Gain on sale $ 213.5

DERIVATIVE INSTRUMENTS AND HE31

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Hedging Positions	The following tables illustrate our derivative positions for calendar years 2017, 2018 and 2019 as of November 1, 2017 : Put Contracts (NYMEX) Oil Daily Volume Price 2017 February - December 2,000 $ 50.00 2017 July - December 1,000 41.10 2018 January - December 1,000 54.00 2018 January - December 1,000 45.00 Fixed-Price Swaps (NYMEX) Natural Gas Oil Daily Volume (MMBtus/d) Swap Price ($ per MMBtu) Daily Volume (Bbls/d) Swap Price ($ per Bbl) 2017 March - December 1,000 $ 53.90 2017 July - December 11,000 $ 3.00 2017 October - December 1,000 52.10 2018 January - December 1,000 52.50 2018 January - December 1,000 51.98 2018 January - December 1,000 53.67 2019 January - December 1,000 51.00 2019 January - December 1,000 51.57 Collar Contracts (NYMEX) Natural Gas Oil Daily Volume Floor Price Ceiling Price Daily Volume (Bbls/d) Floor Price Ceiling Price 2017 March - December 1,000 $ 50.00 $ 56.45 2017 April - December 1,000 50.00 56.75 2018 January - December 6,000 $ 2.75 $ 3.24 1,000 45.00 55.35
Gains or Losses Related to Changes in Fair Value and Cash Settlements on Derivatives Not Qualifying as Hedging Instruments	The following table discloses the before tax effect of our derivatives not designated or not qualifying as hedging instruments on the statement of operations for the three months ended September 30, 2017 (Successor), the period from January 1, 2017 through February 28, 2017 (Predecessor) and the period from March 1, 2017 through September 30, 2017 (Successor) (in millions). Gain (Loss) Recognized in Derivative Income (Expense) Successor Successor Predecessor Three Months Ended Period from Period from Description Commodity contracts: Cash settlements $ 1.2 $ 2.6 $ — Change in fair value (7.9 ) (1.2 ) (1.8 ) Total gains (losses) on derivatives not designated or not qualifying as hedging instruments $ (6.7 ) $ 1.4 $ (1.8 ) The following table discloses the location and fair value amounts of derivatives not designated or not qualifying as hedging instruments, as reported in our balance sheet, at September 30, 2017 (Successor) (in millions). We had no outstanding hedging instruments at December 31, 2016 (Predecessor). Fair Value of Derivatives Not Designated or Not Qualifying as Hedging Instruments at September 30, 2017 (Successor) Asset Derivatives Liability Derivatives Description Balance Sheet Location Fair Balance Sheet Location Fair Commodity contracts Current assets: Fair value of $ 2.6 Current liabilities: Fair value of derivative contracts $ 0.4 Long-term assets: Fair value 1.0 Long-term liabilities: Fair 0.1 $ 3.6 $ 0.5
Before Tax Effect of Derivative Instruments in Statement of Operations	The following tables disclose the before tax effect of derivatives qualifying as hedging instruments, as reported in the statement of operations, during the three and nine months ended September 30, 2016 (Predecessor) (in millions): Effect of Derivatives Qualifying as Hedging Instruments on the Statement of Operations for the Three Months Ended September 30, 2016 (Predecessor) Derivatives in Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion) (a) Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) 2016 Location 2016 Location 2016 Commodity contracts $ 2.3 Operating revenue - oil/natural gas production $ 7.7 Derivative income (expense), net $ (0.2 ) Total $ 2.3 $ 7.7 $ (0.2 ) (a) For the three months ended September 30, 2016 , effective hedging contracts increased oil revenue by $5.3 million and increased natural gas revenue by $2.4 million . Effect of Derivatives Qualifying as Hedging Instruments on the Statement of Operations for the Nine Months Ended September 30, 2016 (Predecessor) Derivatives in Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion) (a) Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) 2016 Location 2016 Location 2016 Commodity contracts $ (1.7 ) Operating revenue - oil/natural gas production $ 29.4 Derivative income (expense), net $ (0.7 ) Total $ (1.7 ) $ 29.4 $ (0.7 ) (a) For the nine months ended September 30, 2016 , effective hedging contracts increased oil revenue by $19.7 million and increased natural gas revenue by $9.7 million .
Summary of Offsetting Liabilities	The following table presents the potential impact of the offset rights associated with our recognized assets and liabilities at September 30, 2017 (Successor) (in millions): As Presented Without Netting Effects of Netting With Effects of Netting Current assets: Fair value of derivative contracts $ 2.6 $ (0.4 ) $ 2.2 Long-term assets: Fair value of derivative contracts 1.0 (0.1 ) 0.9 Current liabilities: Fair value of derivative contracts (0.4 ) 0.4 — Long-term liabilities: Fair value of derivative contracts (0.1 ) 0.1 —
Summary of Offsetting Assets	The following table presents the potential impact of the offset rights associated with our recognized assets and liabilities at September 30, 2017 (Successor) (in millions): As Presented Without Netting Effects of Netting With Effects of Netting Current assets: Fair value of derivative contracts $ 2.6 $ (0.4 ) $ 2.2 Long-term assets: Fair value of derivative contracts 1.0 (0.1 ) 0.9 Current liabilities: Fair value of derivative contracts (0.4 ) 0.4 — Long-term liabilities: Fair value of derivative contracts (0.1 ) 0.1 —

DEBT (Tables)

DEBT (Tables)	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Long-Term Debt	Our debt balances (net of related unamortized discounts and debt issuance costs) as of September 30, 2017 and December 31, 2016 were as follows (in millions): Successor Predecessor September 30, December 31, 7 ½% Senior Second Lien Notes due 2022 $ 225.0 $ — 1 ¾% Senior Convertible Notes due 2017 — 300.0 7 ½% Senior Notes due 2022 — 775.0 Predecessor revolving credit facility — 341.5 4.20% Building Loan 11.0 11.3 Total debt 236.0 1,427.8 Less: current portion of long-term debt (0.4 ) (0.4 ) Less: liabilities subject to compromise — (1,075.0 ) Long-term debt $ 235.6 $ 352.4

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Changes in Asset Retirement Obligations	The change in our asset retirement obligations during the period from January 1, 2017 through February 28, 2017 (Predecessor) and the period from March 1, 2017 through September 30, 2017 (Successor) is set forth below (in millions, inclusive of current portion): Asset retirement obligations as of January 1, 2017 (Predecessor) $ 242.0 Liabilities settled (3.6 ) Divestment of properties (8.7 ) Accretion expense 5.4 Asset retirement obligations as of February 28, 2017 (Predecessor) 235.2 Fair value fresh start adjustment 54.9 Asset retirement obligations as of February 28, 2017 (Successor) 290.1 Liabilities settled (53.1 ) Accretion expense 19.7 Revision of estimates 11.0 Asset retirement obligations as of September 30, 2017 (Successor) $ 267.6

ACCUMULATED OTHER COMPREHENSI34

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Schedule of Changes in Accumulated Other Comprehensive Income Loss	Changes in accumulated other comprehensive income (loss) by component for the three and nine months ended September 30, 2016 (Predecessor), were as follows (in millions): Cash Flow Hedges Three Months Ended September 30, 2016 (Predecessor) Beginning balance, net of tax $ 7.4 Other comprehensive income (loss) before reclassifications: Change in fair value of derivatives 2.3 Income tax effect (0.8 ) Net of tax 1.5 Amounts reclassified from accumulated other comprehensive income: Operating revenue: oil/natural gas production 7.7 Income tax effect (2.7 ) Net of tax 5.0 Other comprehensive loss, net of tax (3.5 ) Ending balance, net of tax $ 3.9 Cash Flow Foreign Total Nine Months Ended September 30, 2016 (Predecessor) Beginning balance, net of tax $ 24.0 $ (6.0 ) $ 18.0 Other comprehensive income (loss) before reclassifications: Change in fair value of derivatives (1.7 ) — (1.7 ) Income tax effect 0.6 — 0.6 Net of tax (1.1 ) — (1.1 ) Amounts reclassified from accumulated other comprehensive income: Operating revenue: oil/natural gas production 29.4 — 29.4 Other operational expenses — (6.0 ) (6.0 ) Income tax effect (10.4 ) — (10.4 ) Net of tax 19.0 (6.0 ) 13.0 Other comprehensive income (loss), net of tax (20.1 ) 6.0 (14.1 ) Ending balance, net of tax $ 3.9 $ — $ 3.9

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2017
Fair Value Disclosures [Abstract]
Schedule of Assets and Liabilities Measured at Fair Value Recurring Basis	The following tables present our assets and liabilities that are measured at fair value on a recurring basis at September 30, 2017 (Successor) (in millions). Fair Value Measurements Successor as of September 30, 2017 Assets Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Marketable securities (Other assets) $ 9.3 $ 9.3 $ — $ — Derivative contracts 3.6 — 0.5 3.1 Total $ 12.9 $ 9.3 $ 0.5 $ 3.1 Fair Value Measurements at Successor as of September 30, 2017 Liabilities Total Quoted Prices in Active Markets for Identical Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Derivative contracts $ 0.5 $ — $ 0.1 $ 0.4 Total $ 0.5 $ — $ 0.1 $ 0.4 We had no liabilities measured at fair value on a recurring basis at December 31, 2016 (Predecessor). The following table presents our assets that are measured at fair value on a recurring basis at December 31, 2016 (Predecessor) (in millions). Fair Value Measurements Predecessor as of December 31, 2016 Assets Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Marketable securities (Other assets) $ 8.7 $ 8.7 $ — $ — Total $ 8.7 $ 8.7 $ — $ —
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The table below presents a reconciliation for assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the period from March 1, 2017 through September 30, 2017 (Successor) and the period from January 1, 2017 through February 28, 2017 (Predecessor) (in millions). Hedging Contracts, net Balance as of January 1, 2017 (Predecessor) $ — Total gains/(losses) (realized or unrealized): Included in earnings (0.6 ) Included in other comprehensive income — Purchases, sales, issuances and settlements 3.7 Transfers in and out of Level 3 — Balance as of February 28, 2017 (Successor) 3.1 Total gains/(losses) (realized or unrealized): Included in earnings (1.3 ) Included in other comprehensive income — Purchases, sales, issuances and settlements 1.0 Transfers in and out of Level 3 — Balance as of September 30, 2017 (Successor) $ 2.8 The amount of total gains/(losses) for the period included in earnings (derivative income) attributable to the change in unrealized gain/(losses) relating to derivatives still held at September 30, 2017 $ (1.7 )

REORGANIZATION (Details)

REORGANIZATION (Details) $ / shares in Units, a in Thousands

Mar. 01, 2017USD ($)$ / sharesshares

Feb. 28, 2017USD ($)shares

Feb. 27, 2017USD ($)shares

Feb. 08, 2017USD ($)

Jan. 11, 2017bidder

Dec. 09, 2016USD ($)a

Feb. 28, 2017USD ($)shares

Sep. 30, 2017$ / sharesshares

Sep. 30, 2016shares

Sep. 30, 2017USD ($)$ / sharesshares

Sep. 30, 2017$ / shares

Sep. 30, 2016USD ($)shares

Dec. 31, 2016

Restructuring Cost and Reserve [Line Items]

Net consideration received for sale of Appalachia Properties

$ 512,472,000

$ 17,777,000

New shares issued in reorganization (in shares) | shares

20,000,000

20,000,000

0

1,195

7 ½% Senior Second Lien Notes due 2022 | Senior Notes

Restructuring Cost and Reserve [Line Items]

Interest rate

7.50%

7.50%

7.50%

7.50%

Aggregate principal amount of senior subordinated notes

$ 225,000,000

Predecessor

Restructuring Cost and Reserve [Line Items]

Net consideration received for sale of Appalachia Properties

$ 505,383,000

$ 0

New shares issued in reorganization (in shares) | shares

47,390

12,900

75,100

Predecessor | 1 ¾% Senior Convertible Notes due 2017

Restructuring Cost and Reserve [Line Items]

Interest rate

1.75%

Predecessor | 7 ½% Senior Second Lien Notes due 2022 | Senior Notes

Restructuring Cost and Reserve [Line Items]

Interest rate

7.50%

Predecessor Company's Common Stockholders

Restructuring Cost and Reserve [Line Items]

Warrants issued in reorganization (in shares) | shares

3,500,000

Exercise price of warrants or rights (in usd per share) | $ / shares

$ 42.04

$ 42.04

$ 42.04

Exercise period for warrants

4 years

RSA | Common Stock

Restructuring Cost and Reserve [Line Items]

New shares issued in reorganization (in shares) | shares

20,000,000

RSA | Predecessor

Restructuring Cost and Reserve [Line Items]

Acreage sold in agreement | a

86

Number of additional bidders allowed to participate in competitive bidding | bidder

2

RSA | Tug Hill | Disposal Group, Disposed of by Sale | Predecessor

Restructuring Cost and Reserve [Line Items]

Net consideration received for sale of Appalachia Properties

$ 360,000,000

Loss on contract termination

$ 11,500,000

RSA | EQT Production Company | Disposal Group, Disposed of by Sale | Predecessor

Restructuring Cost and Reserve [Line Items]

Net consideration received for sale of Appalachia Properties

$ 527,000,000

$ 527,000,000

Upward adjustment to the purchase price

$ 16,000,000

RSA | Noteholders

Restructuring Cost and Reserve [Line Items]

Pro rata share of net cash proceeds

$ 100,000,000

Percentage of common stock issued in reorganization

95.00%

RSA | Noteholders | 7 ½% Senior Second Lien Notes due 2022 | Senior Notes

Restructuring Cost and Reserve [Line Items]

Aggregate principal amount of senior subordinated notes

$ 225,000,000

RSA | Noteholders | Common Stock

Restructuring Cost and Reserve [Line Items]

New shares issued in reorganization (in shares) | shares

19,000,000

RSA | Predecessor Company's Common Stockholders

Restructuring Cost and Reserve [Line Items]

Percentage of common stock issued in reorganization

5.00%

RSA | Predecessor Company's Common Stockholders | Common Stock

Restructuring Cost and Reserve [Line Items]

New shares issued in reorganization (in shares) | shares

1,000,000

Warrants issued in reorganization (in shares) | shares

3,500,000

Exercise price of warrants or rights (in usd per share) | $ / shares

$ 42.04

Exercise period for warrants

4 years

RSA | Appalachia regions of Pennsylvania and West Virginia | Predecessor

Restructuring Cost and Reserve [Line Items]

Minimum proceeds from sale property

$ 350,000,000

FRESH START ACCOUNTING - Additi

FRESH START ACCOUNTING - Additional Information (Details) - USD ($)	Mar. 01, 2017	Feb. 28, 2017	Feb. 27, 2017	Oct. 31, 2016	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Fresh-Start Adjustment [Line Items]
Accumulated deficit		$ 554,628,000			$ 554,628,000	$ 290,746,000		$ 290,746,000	$ 290,746,000
Enterprise value		$ 419,720,000			419,720,000
Annual escalation adjustment rate		2.00%
Expected period for development to begin		5 years
Proved reserves		$ 380,800,000			380,800,000
Probable and possible reserves		16,800,000			16,800,000
Unevaluated properties reserves		80,200,000			80,200,000
Fair value of asset retirement obligations		$ 290,067,000			290,067,000
Credit-adjusted risk free rate		12.00%
Repayment of outstanding borrowings under Pre-Emergence Credit Agreement		$ 341,500,000						$ 0
New shares issued in reorganization (in shares)	20,000,000	20,000,000				0		1,195
Emergence and success fees		$ 15,180,000
Professional fees		2,600,000
Predecessor Company's Common Stockholders
Fresh-Start Adjustment [Line Items]
Warrants issued in reorganization (in shares)	3,500,000
Exercise price of warrants or rights (in usd per share)						$ 42.04		$ 42.04	$ 42.04
Exercise period for warrants									4 years
Predecessor
Fresh-Start Adjustment [Line Items]
Accumulated deficit		(3,610,000)			(3,610,000)						$ (637,282,000)	$ (39,789,000)
Repayment of outstanding borrowings under Pre-Emergence Credit Agreement					$ 341,500,000					$ 135,500,000
New shares issued in reorganization (in shares)					47,390		12,900			75,100
Emergence and success fees					$ 10,600,000
Professional fees					9,100,000
Appalachia Properties | Disposal Group, Disposed of by Sale
Fresh-Start Adjustment [Line Items]
Indemnity escrow release			$ 10,000,000
Revaluation of Assets
Fresh-Start Adjustment [Line Items]
Write off of unamortized debt issuance costs		2,577,000
Revaluation of Assets | Tug Hill, Inc
Fresh-Start Adjustment [Line Items]
Net reimbursement in connection with the sale of asset		699,000			699,000
Loss on contract termination				$ 1,750,000
Revaluation of Liabilities | Senior Notes | 7 ½% Senior Notes due 2022
Fresh-Start Adjustment [Line Items]
Aggregate principal amount of senior subordinated notes		225,000,000			225,000,000
Revaluation of Liabilities | Predecessor
Fresh-Start Adjustment [Line Items]
Repayment of outstanding borrowings under Pre-Emergence Credit Agreement					341,500,000
Revaluation of Liabilities | Leasing Arrangement
Fresh-Start Adjustment [Line Items]
Loss on contract termination		395,000
Revaluation of Liabilities | Appalachia Properties | Disposal Group, Disposed of by Sale
Fresh-Start Adjustment [Line Items]
Settlement of a property tax accrual		2,598,000			$ 2,598,000
Revaluation of Liabilities | Deferred Bonus | 2016 Incentive Plan
Fresh-Start Adjustment [Line Items]
Deferred compensation arrangement compensation expense		$ 2,008,000
Exchange of Stock for Stock
Fresh-Start Adjustment [Line Items]
Estimated fair value of the warrants (in usd per share)		$ 4.43			$ 4.43
Exchange of Stock for Stock | Predecessor Company's Common Stockholders
Fresh-Start Adjustment [Line Items]
Warrants issued in reorganization (in shares)		3,500,000
Exercise price of warrants or rights (in usd per share)		$ 42.04			$ 42.04
Exercise period for warrants		4 years
Exchange of Stock for Stock | Senior Notes | 7 ½% Senior Notes due 2022 | Predecessor Company's Noteholders
Fresh-Start Adjustment [Line Items]
New shares issued in reorganization (in shares)		1,000,000
Exchange of Stock for Stock | Convertible Debt | 1 ¾% Senior Convertible Notes due 2017 | Predecessor Company's Noteholders
Fresh-Start Adjustment [Line Items]
New shares issued in reorganization (in shares)		19,000,000
Income Approach Valuation Technique
Fresh-Start Adjustment [Line Items]
Discounted weighted average cost of capital rate		12.50%
Minimum
Fresh-Start Adjustment [Line Items]
Enterprise value		$ 300,000,000			$ 300,000,000
Maximum
Fresh-Start Adjustment [Line Items]
Enterprise value		450,000,000			450,000,000
Accumulated Deficit
Fresh-Start Adjustment [Line Items]
Accumulated deficit		0			0	$ (264,777,000)		$ (264,777,000)	$ (264,777,000)
Accumulated Deficit | Predecessor
Fresh-Start Adjustment [Line Items]
Accumulated deficit		$ (1,665,892,000)			$ (1,665,892,000)						$ (2,296,209,000)	$ (1,705,623,000)

FRESH START ACCOUNTING - Reconc

FRESH START ACCOUNTING - Reconciliation of Enterprise Value to Estimated Fair Value of Successor Common Stock (Details) - USD ($) $ / shares in Units, $ in Thousands	Mar. 01, 2017	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2017
Reorganizations [Abstract]
Enterprise value		$ 419,720
Plus: Cash and other assets		371,169
Less: Fair value of debt		(236,261)
Less: Fair value of warrants		(15,648)	$ (15,600)	$ (15,600)
Fair value of Successor common stock		$ 538,980
Shares issued upon emergence (in shares)	20,000,000	20,000,000	0	1,195
Per share value (in usd per share)		$ 26.949

FRESH START ACCOUNTING - Reco39

FRESH START ACCOUNTING - Reconciliation of Enterprise Value to Estimated Reorganization Value (Details) $ in Thousands	Feb. 28, 2017USD ($)
Reorganizations [Abstract]
Enterprise value	$ 419,720
Plus: Cash and other assets	371,169
Plus: Asset retirement obligations (current and long-term)	290,067
Plus: Working capital and other liabilities	58,055
Reorganization value of Successor assets	$ 1,139,011

FRESH START ACCOUNTING - Schedu

FRESH START ACCOUNTING - Schedule of Fresh-Start Adjustments (Details) $ in Thousands	Feb. 28, 2017USD ($)
Current assets:
Cash and cash equivalents	$ 162,966
Restricted cash	75,547
Accounts receivable	52,109
Fair value of derivative contracts	1,267
Current income tax receivable	22,516
Other current assets	11,675
Total current assets	326,080
Proved	670,852
Less: accumulated DD&A	0
Net proved oil and gas properties	670,852
Unevaluated	97,010
Other property and equipment, net	21,062
Fair value of derivative contracts	1,819
Other assets, net	22,188
Total assets	1,139,011
Current liabilities:
Accounts payable to vendors	20,512
Undistributed oil and gas proceeds	1,778
Accrued interest	266
Asset retirement obligations	92,597
Fair value of derivative contracts	476
Current portion of long-term debt	411
Other current liabilities	16,837
Total current liabilities	132,877
Long-term debt	235,850
Asset retirement obligations	197,470
Fair value of derivative contracts	653
Other long-term liabilities	17,533
Total liabilities not subject to compromise	584,383
Liabilities subject to compromise	0
Total liabilities	584,383
Stockholders’ equity:
Common stock (Successor)	200
Additional paid-in capital (Successor)	554,428
Accumulated deficit	0
Total stockholders’ equity	554,628
Total liabilities and stockholders’ equity	1,139,011
Reorganization Adjustments
Current assets:
Cash and cash equivalents	(35,605)
Restricted cash	75,547
Accounts receivable	9,301
Fair value of derivative contracts	0
Current income tax receivable	0
Other current assets	875
Total current assets	50,118
Proved	(188,933)
Less: accumulated DD&A	0
Net proved oil and gas properties	(188,933)
Unevaluated	(127,838)
Other property and equipment, net	(101)
Fair value of derivative contracts	0
Other assets, net	(4,328)
Total assets	(271,082)
Current liabilities:
Accounts payable to vendors	0
Undistributed oil and gas proceeds	(4,139)
Accrued interest	0
Asset retirement obligations	0
Fair value of derivative contracts	0
Current portion of long-term debt	0
Other current liabilities	(195)
Total current liabilities	(4,334)
Long-term debt	(116,500)
Asset retirement obligations	(8,672)
Fair value of derivative contracts	0
Other long-term liabilities	0
Total liabilities not subject to compromise	(129,506)
Liabilities subject to compromise	(1,110,182)
Total liabilities	(1,239,688)
Stockholders’ equity:
Common stock	200
Additional paid-in capital	554,428
Accumulated deficit	2,073,984
Total stockholders’ equity	968,606
Total liabilities and stockholders’ equity	(271,082)
Fresh Start Adjustments
Current assets:
Cash and cash equivalents	0
Restricted cash	0
Accounts receivable	0
Fair value of derivative contracts	0
Current income tax receivable	0
Other current assets	(124)
Total current assets	(124)
Proved	(8,774,122)
Less: accumulated DD&A	9,215,679
Net proved oil and gas properties	441,557
Unevaluated	(146,292)
Other property and equipment, net	(4,423)
Fair value of derivative contracts	0
Other assets, net	0
Total assets	290,718
Current liabilities:
Accounts payable to vendors	0
Undistributed oil and gas proceeds	0
Accrued interest	0
Asset retirement obligations	0
Fair value of derivative contracts	0
Current portion of long-term debt	0
Other current liabilities	0
Total current liabilities	0
Long-term debt	0
Asset retirement obligations	54,914
Fair value of derivative contracts	0
Other long-term liabilities	0
Total liabilities not subject to compromise	54,914
Liabilities subject to compromise	0
Total liabilities	54,914
Stockholders’ equity:
Common stock	0
Additional paid-in capital	0
Accumulated deficit	235,804
Total stockholders’ equity	235,804
Total liabilities and stockholders’ equity	290,718
Predecessor
Current assets:
Cash and cash equivalents	198,571
Restricted cash	0
Accounts receivable	42,808
Fair value of derivative contracts	1,267
Current income tax receivable	22,516
Other current assets	10,924
Total current assets	276,086
Oil and gas properties, full cost method of accounting:
Proved	9,633,907
Less: accumulated DD&A	(9,215,679)
Net proved oil and gas properties	418,228
Unevaluated	371,140
Other property and equipment, net	25,586
Fair value of derivative contracts	1,819
Other assets, net	26,516
Total assets	1,119,375
Current liabilities:
Accounts payable to vendors	20,512
Undistributed oil and gas proceeds	5,917
Accrued interest	266
Asset retirement obligations	92,597
Fair value of derivative contracts	476
Current portion of long-term debt	411
Other current liabilities	17,032
Total current liabilities	137,211
Long-term debt	352,350
Asset retirement obligations	151,228
Fair value of derivative contracts	653
Other long-term liabilities	17,533
Total liabilities not subject to compromise	658,975
Liabilities subject to compromise	1,110,182
Total liabilities	1,769,157
Stockholders’ equity:
Common stock	56
Treasury stock (Predecessor)	(860)
Additional paid-in capital (Predecessor)	1,660,810
Accumulated deficit	(2,309,788)
Total stockholders’ equity	(649,782)
Total liabilities and stockholders’ equity	1,119,375
Predecessor | Reorganization Adjustments
Stockholders’ equity:
Common stock	(56)
Treasury stock (Predecessor)	860
Additional paid-in capital	(1,660,810)
Predecessor | Fresh Start Adjustments
Stockholders’ equity:
Common stock	0
Treasury stock (Predecessor)	0
Additional paid-in capital	$ 0

FRESH START ACCOUNTING - Reorga

FRESH START ACCOUNTING - Reorganization Adjustments (Details) - USD ($) $ in Thousands	Feb. 28, 2017	Feb. 27, 2017	Sep. 30, 2017
Fresh-Start Adjustment [Line Items]
Net consideration received for sale of Appalachia Properties	$ 512,472		$ 17,777
Cash transferred to restricted account	75,547
Break-up fee to Tug Hill	10,800
Repayment of outstanding borrowings under Pre-Emergence Credit Agreement	341,500		0
Repayment of 2017 Convertible Notes and 2022 Notes	100,000
Other fees and expenses	20,230
Total uses	548,077
Net change in cash and cash equivalents	(35,605)		$ 82,748
Restricted cash for certain cure amounts	547
Emergence and success fees	15,180
Professional fees	2,600
Payments to seismic providers	2,395
Amended Credit Agreement
Fresh-Start Adjustment [Line Items]
Cash transferred to restricted account	$ 75,000
Disposal Group, Disposed of by Sale | Appalachia Properties
Fresh-Start Adjustment [Line Items]
Net consideration received for sale of Appalachia Properties		$ 512,472
Net consideration received for sale of Appalachia Properties		522,472
Indemnity escrow release		$ 10,000

FRESH START ACCOUNTING - Liabil

FRESH START ACCOUNTING - Liabilities Subject to Compromise (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Feb. 28, 2017
Fresh-Start Adjustment [Line Items]
Liabilities subject to compromise	$ 0
Liabilities subject to compromise of the Predecessor Company	$ 0
Revaluation of Liabilities
Fresh-Start Adjustment [Line Items]
Accrued interest		$ 35,182
Liabilities subject to compromise of the Predecessor Company		1,110,182
Cash payment to senior noteholders		(100,000)
Issuance of 2022 Second Lien Notes to former holders of the senior notes		(225,000)
Gain on settlement of liabilities subject to compromise		230,554
Common Stock | Revaluation of Liabilities
Fresh-Start Adjustment [Line Items]
Equity fair value adjustments		(538,980)
Warrant
Fresh-Start Adjustment [Line Items]
Equity fair value adjustments		$ (15,648)
Convertible Debt | 1 ¾% Senior Convertible Notes due 2017
Fresh-Start Adjustment [Line Items]
Interest rate		1.75%
Convertible Debt | 1 ¾% Senior Convertible Notes due 2017 | Revaluation of Liabilities
Fresh-Start Adjustment [Line Items]
Liabilities subject to compromise		$ 300,000
Senior Notes | 7 ½% Senior Notes due 2022
Fresh-Start Adjustment [Line Items]
Interest rate		7.50%
Senior Notes | 7 ½% Senior Notes due 2022 | Revaluation of Liabilities
Fresh-Start Adjustment [Line Items]
Liabilities subject to compromise		$ 775,000

FRESH START ACCOUNTING - Cumula

FRESH START ACCOUNTING - Cumulative Impact of the Reorganization Adjustments (Details) - Exchange of Stock for Stock $ in Thousands	Feb. 28, 2017USD ($)
Fresh-Start Adjustment [Line Items]
Gain on settlement of liabilities subject to compromise	$ 230,554
Professional and other fees paid at emergence	(10,648)
Write-off of unamortized deferred financing costs	(2,577)
Other reorganization adjustments	(1,915)
Net impact to reorganization items	215,414
Gain on sale of Appalachia Properties	213,453
Cancellation of Predecessor Company equity	1,662,282
Other adjustments to accumulated deficit	(17,165)
Net impact to accumulated deficit	$ 2,073,984

FRESH START ACCOUNTING - Reor44

FRESH START ACCOUNTING - Reorganization Items (Details) - USD ($) $ in Thousands	2 Months Ended	7 Months Ended	9 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016
Fresh-Start Adjustment [Line Items]
Gain on reorganization items, net		$ 0
Predecessor
Fresh-Start Adjustment [Line Items]
Gain on settlement of liabilities subject to compromise	$ 230,554
Fresh start valuation adjustments	235,804
Reorganization professional fees and other expenses	(20,512)
Write-off of deferred financing costs	(2,577)
Other reorganization items	(5,525)
Gain on reorganization items, net	$ 437,744		$ 0

STOCKHOLDERS' EQUITY - Addition

STOCKHOLDERS' EQUITY - Additional Information (Details) - USD ($) $ / shares in Units, $ in Thousands	Mar. 01, 2017	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2017
Class of Stock [Line Items]
New shares issued in reorganization (in shares)	20,000,000	20,000,000	0	1,195
Common stock, par value (in usd per share)	$ 0.01		$ 0.01	$ 0.01	$ 0.01
Warrants allocated of the enterprise value		$ 15,648	$ 15,600	$ 15,600	$ 15,600
Predecessor Company's Common Stockholders
Class of Stock [Line Items]
Warrants issued in reorganization (in shares)	3,500,000
Exercise price of warrants or rights (in usd per share)			$ 42.04	$ 42.04	$ 42.04
Exercise period for warrants					4 years

SHARE-BASED COMPENSATION AND 46

SHARE-BASED COMPENSATION AND EMPLOYEE BENEFIT PLANS (Details) $ / shares in Units, $ in Thousands	Jul. 25, 2017day	Feb. 28, 2017	Jan. 10, 2017USD ($)instalment	Mar. 31, 2017shares	Feb. 28, 2017USD ($)shares	Sep. 30, 2017USD ($)$ / shares	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)$ / shares	Sep. 30, 2016USD ($)	Mar. 01, 2017USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of common stock issued in reorganization to existing shareholders		5.00%
Percentage of warrants issued in reorganization (up to)		15.00%
Number of days before retention award payout (in days) | day	30
Incentive compensation expense						$ 4,646		$ 4,646
2017 Annual Incentive Compensation Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Incentive compensation expense						4,100
Stone Energy Corporation Retention Award Agreement
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Incentive compensation expense						$ 500
Stone Energy Corporation Executive Severance Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of executive officer's annual bonus opportunity	100.00%
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period						3 months
Per share grant date fair value (in usd per share) | $ / shares						$ 26.95		$ 26.95
Stock Compensation Plan | 2017 Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
The maximum number of shares that may be issued (in shares) | shares										2,614,379
Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost						$ 900		$ 900
Award vesting period						7 months
Executives | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost						$ 14		$ 14
Board of Directors | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock units granted (in shares) | shares				62,137
Restricted stock units aggregate grant date fair value										$ 1,700
Predecessor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock compensation capitalized into oil and gas properties					$ 600
Incentive compensation expense					$ 2,008		$ 2,160		$ 11,809
Predecessor | Board of Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted during period (in shares) | shares					10,404
Aggregate grant date value of such stock					$ 69
Minimum | Stone Energy Corporation Executive Severance Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Lump sum cash payment salary payout rate	1
Maximum | Stone Energy Corporation Executive Severance Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Lump sum cash payment salary payout rate	1.5
Maximum | Executives | 2016 Incentive Plan | Deferred Bonus
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred compensation arrangement compensation expense			$ 2,000
Deferred compensation arrangement, number of installments | instalment			2
Selling, General and Administrative Expenses | Predecessor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Salaries, general and administrative expenses					$ 1,700

EARNINGS PER SHARE - Calculatio

EARNINGS PER SHARE - Calculation of Basic and Diluted Weighted Average Shares Outstanding and Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	2 Months Ended	3 Months Ended		7 Months Ended	9 Months Ended	12 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Basic:
Net income (loss)		$ 1,297		$ (264,777)
Net income attributable to participating securities		(4)		0
Net income (loss) attributable to common stock - basic		1,293		(264,777)
Diluted:
Net income (loss)		1,297		(264,777)
Net income attributable to participating securities		(4)		0
Net income (loss) attributable to common stock - diluted		$ 1,293		$ (264,777)
Weighted average shares (denominator):
Weighted average shares - basic (in shares)		19,997		19,997
Dilutive effect of convertible notes (in shares)		0		0
Weighted average shares - diluted (in shares)		19,997		19,997
Basic income (loss) per share (in usd per share)		$ 0.06		$ (13.24)
Diluted income (loss) per share (in usd per share)		$ 0.06		$ (13.24)
Employee Stock Option
Weighted average shares (denominator):
Dilutive effect of stock options, warrants, and restricted stock units (in shares)		0		0
Warrants
Weighted average shares (denominator):
Dilutive effect of stock options, warrants, and restricted stock units (in shares)		0		0
Predecessor
Basic:
Net income (loss)	$ 630,317		$ (89,635)		$ (474,180)	$ (590,586)
Net income attributable to participating securities	(4,995)		0		0
Net income (loss) attributable to common stock - basic	625,322		(89,635)		(474,180)
Diluted:
Net income (loss)	630,317		(89,635)		(474,180)	$ (590,586)
Net income attributable to participating securities	(4,995)		0		0
Net income (loss) attributable to common stock - diluted	$ 625,322		$ (89,635)		$ (474,180)
Weighted average shares (denominator):
Weighted average shares - basic (in shares)	5,634		5,600		5,585
Dilutive effect of convertible notes (in shares)	0		0		0
Weighted average shares - diluted (in shares)	5,634		5,600		5,585
Basic income (loss) per share (in usd per share)	$ 110.99		$ (16.01)		$ (84.90)
Diluted income (loss) per share (in usd per share)	$ 110.99		$ (16.01)		$ (84.90)
Predecessor | Employee Stock Option
Weighted average shares (denominator):
Dilutive effect of stock options, warrants, and restricted stock units (in shares)	0		0		0
Predecessor | Warrants
Weighted average shares (denominator):
Dilutive effect of stock options, warrants, and restricted stock units (in shares)	0		0		0

EARNINGS PER SHARE - Additional

EARNINGS PER SHARE - Additional Information (Details) - USD ($)	Mar. 01, 2017	Feb. 28, 2017	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
New shares issued in reorganization (in shares)	20,000,000	20,000,000		0		1,195
Warrant
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
Antidilutive stock options outstanding (in shares)				3,529,000		3,529,000
Restricted Stock
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
Antidilutive stock options outstanding (in shares)						62,000
Predecessor
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
New shares issued in reorganization (in shares)			47,390		12,900		75,100
Predecessor | 1 3⁄4% Senior Convertible Notes due 2017
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
Dilutive effect on the diluted earnings per share			$ 0		$ 0		$ 0
Predecessor | Employee Stock Option
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
Antidilutive stock options outstanding (in shares)			10,400		12,900		12,900
Predecessor | Restricted Stock
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
Antidilutive stock options outstanding (in shares)					0

DIVESTITURE - Additional Inform

DIVESTITURE - Additional Information (Details) $ in Thousands	Feb. 27, 2017USD ($)	Dec. 31, 2016MMBoe	Feb. 28, 2017USD ($)
Appalachia Properties | Disposal Group, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net consideration received for sale of Appalachia Properties	$ 522,472
Predecessor
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of proved oil and natural gas reserves		34.00%
Predecessor | Appalachia Properties | Disposal Group, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net consideration received for sale of Appalachia Properties	522,500
Gross proceeds from properties sold	527,000
Purchase price adjustment	$ 4,500
Net gain on sale			$ 213,500
Predecessor | Oil and Gas Properties | Appalachia Properties | Disposal Group, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Estimated proved oil and natural gas reserves | MMBoe		18

DIVESTITURE - Schedule of Net G

DIVESTITURE - Schedule of Net Gain Recognized in Sale (Details) - USD ($) $ in Thousands	Feb. 27, 2017	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Transfer of asset retirement obligations					$ 53,100
Carrying value of properties sold			$ (18,433)		(18,433)
Gain on sale			$ (132)		$ (105)
Appalachia Properties | Disposal Group, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net consideration received for sale of Appalachia Properties	$ 522,472
Predecessor
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Transfer of asset retirement obligations		$ 3,600
Carrying value of properties sold							$ (26,213)
Gain on sale		$ 213,453		$ 0		$ 0
Predecessor | Appalachia Properties | Disposal Group, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net consideration received for sale of Appalachia Properties	522,500
Release of funds held in suspense	4,100
Transfer of asset retirement obligations	8,700
Other adjustments, net	2,600
Transaction costs	(7,100)
Gain on sale	213,500
Predecessor | Appalachia Properties | Disposal Group, Disposed of by Sale | Oil and Gas Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of properties sold	$ (317,300)

INVESTMENT IN OIL AND GAS PRO51

INVESTMENT IN OIL AND GAS PROPERTIES - Additional Information (Details) $ in Thousands	2 Months Ended	3 Months Ended					7 Months Ended	9 Months Ended
	Feb. 28, 2017USD ($)$ / Mcf$ / bbl	Sep. 30, 2017USD ($)	Mar. 31, 2017USD ($)$ / Mcf$ / bbl	Sep. 30, 2016USD ($)$ / Mcf$ / bbl	Jun. 30, 2016USD ($)$ / Mcf$ / bbl	Mar. 31, 2016USD ($)$ / Mcf$ / bbl	Sep. 30, 2017USD ($)	Sep. 30, 2016USD ($)$ / Mcf$ / bbl
Oil and Gas In Process Activities [Line Items]
Proved reserves	$ 380,800
Probable and possible reserves	16,800
Unevaluated properties reserves	$ 80,200
Write-down of oil and gas properties		$ 0					$ 256,435
Oil
Oil and Gas In Process Activities [Line Items]
Average 12-month oil prices net of differentials (in dollars per Bbl) | $ / bbl	56.01		45.40
Natural Gas
Oil and Gas In Process Activities [Line Items]
Average twelve month gas prices net of differentials (in dollars per Mcf) | $ / Mcf	2.52		2.24
Natural Gas Liquids (MBbls)
Oil and Gas In Process Activities [Line Items]
Average 12-month gas prices net of differentials (in dollars per Bbl) | $ / bbl	14.18		19.18
Oil And Gas
Oil and Gas In Process Activities [Line Items]
Write-down of oil and gas properties			$ 256,400
Predecessor
Oil and Gas In Process Activities [Line Items]
Write-down of oil and gas properties	$ 0			$ 36,484				$ 284,337
Decrease in written down value of oil and gas properties				$ 9,600	$ 18,100	$ 23,000
Predecessor | CANADA
Oil and Gas In Process Activities [Line Items]
Write-down of oil and gas properties						$ 300
Predecessor | Oil
Oil and Gas In Process Activities [Line Items]
Average 12-month oil prices net of differentials (in dollars per Bbl) | $ / bbl				40.51	43.49	46.72		40.51
Predecessor | Natural Gas
Oil and Gas In Process Activities [Line Items]
Average twelve month gas prices net of differentials (in dollars per Mcf) | $ / Mcf				1.99	1.93	2.01		1.99
Predecessor | Natural Gas Liquids (MBbls)
Oil and Gas In Process Activities [Line Items]
Average 12-month gas prices net of differentials (in dollars per Bbl) | $ / bbl				13.88	9.33	13.65		13.88
Predecessor | Oil And Gas
Oil and Gas In Process Activities [Line Items]
Write-down of oil and gas properties				$ 36,500	$ 118,600	$ 128,900

DERIVATIVE INSTRUMENTS AND HE52

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Additional Information (Details)	Nov. 01, 2017counterparty	Sep. 30, 2017contract	Dec. 31, 2016	Dec. 31, 2016hedging_instrument	Dec. 31, 2016contract
Derivative Instruments, Gain (Loss) [Line Items]
Maximum correlation between price of oil & natural gas in market and underlying price basis indicative in the derivative contract			100.00%
Predecessor
Derivative Instruments, Gain (Loss) [Line Items]
Number of derivative instruments outstanding					0
Not Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Number of derivative instruments outstanding		0
Not Designated as Hedging Instrument | Predecessor
Derivative Instruments, Gain (Loss) [Line Items]
Number of derivative instruments outstanding				0	0
Subsequent Event | Fixed-Price Swaps And Costless Collars
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties | counterparty	5
Counterparty One and Counterparty Two | Subsequent Event
Derivative Instruments, Gain (Loss) [Line Items]
Percentage of counterparty contract volume	64.00%

DERIVATIVE INSTRUMENTS AND HE53

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Hedging Positions (Details) - Subsequent Event - Not Designated as Hedging Instrument bbl in Thousands, MMBTU in Thousands	Nov. 01, 2017MMBTU$ / MMBTU$ / bblbbl
Oil | Commodity Put Contract February Through December 2017, Contract One
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	2
Price ($ per Bbl)	50
Oil | Commodity Collar Contract July Through December 2017
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Price ($ per Bbl)	41.1
Oil | Commodity Put Contract January Through December 2018, Contract One
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Price ($ per Bbl)	54
Oil | Commodity Put Contract January Through December 2018, Contract Two
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Price ($ per Bbl)	45
Oil | Commodity Fixed-Price Swap Contract, March Through December 2017
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	53.9
Oil | Commodity Fixed-Price Swap Contract October through December 2017
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	52.10
Oil | Commodity Fixed-Price Swap Contract, January Through December 2018
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	52.5
Oil | Commodity Fixed-Price Swap Contract, January Through December 2018 Contract Two
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	51.98
Oil | Commodity Fixed-Price Swap Contract, January Through December 2018 Contract Three
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	53.67
Oil | Commodity Fixed-Price Swap Contract, January Through December 2019
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	51
Oil | Commodity Fixed-Price Swap Contract, January Through December 2019 Contract Two
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Swap Price ($ per MMBtu)	51.57
Oil | Commodity Collar Contract March Through December 2017, Contract One
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Price ($ per Bbl)	50
Ceiling Price ($ per Bbl)	56.45
Oil | Commodity Collar Contract April Through December 2017, Contract Two
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Price ($ per Bbl)	50
Ceiling Price ($ per Bbl)	56.75
Oil | Commodity Collar Contract January Through December 2018, Contract Two
Derivatives, Fair Value [Line Items]
Daily Volume (Bbls/d) | bbl	1
Price ($ per Bbl)	45
Ceiling Price ($ per Bbl)	55.35
Natural Gas | NYMEX Fixed-Price Swap Contract, July Through December 2017, Contract One
Derivatives, Fair Value [Line Items]
Daily Volume (MMBtus/d) | MMBTU	11
Swap Price ($ per MMBtu) | $ / MMBTU	3
Natural Gas | Commodity Collar Contract January Through December 2018, Contract Two
Derivatives, Fair Value [Line Items]
Price ($ per Bbl) | $ / MMBTU	2.75
Daily Volume (MMBtus/d) | MMBTU	6
Ceiling Price ($ per Bbl) | $ / MMBTU	3.24

DERIVATIVE INSTRUMENTS AND HE54

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Location and Fair Value Amounts of Derivative Instruments Reported in Balance Sheet (Details) $ in Millions	Sep. 30, 2017USD ($)
Asset Derivatives
Derivative contracts	$ 3.6
Liability Derivatives
Derivative contracts, liabilities	0.5
Not Designated as Hedging Instrument | Commodity contracts
Asset Derivatives
Derivative contracts	3.6
Liability Derivatives
Derivative contracts, liabilities	0.5
Not Designated as Hedging Instrument | Commodity contracts | Current assets: Fair value of derivative contracts
Asset Derivatives
Derivative contracts	2.6
Not Designated as Hedging Instrument | Commodity contracts | Long-term assets: Fair value of derivative contracts
Asset Derivatives
Derivative contracts	1
Not Designated as Hedging Instrument | Commodity contracts | Current liabilities: Fair value of derivative contracts
Liability Derivatives
Derivative contracts, liabilities	0.4
Not Designated as Hedging Instrument | Commodity contracts | Long-term liabilities: Fair value of derivative contracts
Liability Derivatives
Derivative contracts, liabilities	$ 0.1

DERIVATIVE INSTRUMENTS AND HE55

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Gains or Losses Related to Changes in Fair Value and Cash Settlements on Derivatives Not Qualifying as Hedging Instruments (Details) - Not Designated as Hedging Instrument - Commodity contracts - USD ($) $ in Millions	2 Months Ended	3 Months Ended	7 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Cash settlements		$ 1.2	$ 2.6
Change in fair value		(7.9)	(1.2)
Total gains (losses) on non-qualifying hedges		$ (6.7)	$ 1.4
Predecessor
Derivative Instruments, Gain (Loss) [Line Items]
Cash settlements	$ 0
Change in fair value	(1.8)
Total gains (losses) on non-qualifying hedges	$ (1.8)

DERIVATIVE INSTRUMENTS AND HE56

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Before Tax Effect of Derivative Instruments in Statement of Operations (Details) - Predecessor - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Increase in oil revenue owing to effective hedging contracts	$ 5.3	$ 19.7
increase in gas revenue owing to effective hedging contracts	2.4	9.7
Designated as Hedging Instrument | Cash Flow Hedging
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	2.3	(1.7)
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion)	7.7	29.4
Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion)	(0.2)	(0.7)
Designated as Hedging Instrument | Cash Flow Hedging | Commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	2.3	(1.7)
Designated as Hedging Instrument | Cash Flow Hedging | Commodity contracts | Operating revenue - oil/natural gas production
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion)	7.7	29.4
Designated as Hedging Instrument | Cash Flow Hedging | Commodity contracts | Derivative income (expense), net
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion)	$ (0.2)	$ (0.7)

DERIVATIVE INSTRUMENTS AND HE57

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Offsetting Assets and Liabilities (Details) $ in Millions	Sep. 30, 2017USD ($)
Current assets: Fair value of derivative contracts
Offsetting Derivative Assets [Abstract]
Derivative Assets As Presented Without Netting	$ 2.6
Derivative Assets Effects of Netting	(0.4)
Derivative Assets With Effects of Netting	2.2
Long-term assets: Fair value of derivative contracts
Offsetting Derivative Assets [Abstract]
Derivative Assets As Presented Without Netting	1
Derivative Assets Effects of Netting	(0.1)
Derivative Assets With Effects of Netting	0.9
Current liabilities: Fair value of derivative contracts
Offsetting Derivative Liabilities [Abstract]
Derivative Liabilities As Presented Without Netting	(0.4)
Derivative Liabilities Effects of Netting	0.4
Derivative Liabilities With Effects of Netting	0
Long-term liabilities: Fair value of derivative contracts
Offsetting Derivative Liabilities [Abstract]
Derivative Liabilities As Presented Without Netting	(0.1)
Derivative Liabilities Effects of Netting	0.1
Derivative Liabilities With Effects of Netting	$ 0

DEBT - Long-Term Debt (Details)

DEBT - Long-Term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Mar. 01, 2017	Feb. 28, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Long-term debt	$ 236,000
Less: current portion of long-term debt	(421)
Less: liabilities subject to compromise	0
Long-term debt	$ 235,567
7 ½% Senior Second Lien Notes due 2022 | Senior Notes
Debt Instrument [Line Items]
Interest rate	7.50%	7.50%
Long-term debt	$ 225,000
1 ¾% Senior Convertible Notes due 2017 | Convertible Debt
Debt Instrument [Line Items]
Interest rate			1.75%
Long-term debt	0
7 ½% Senior Notes due 2022 | Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 0
4.20% Building Loan | Secured Debt
Debt Instrument [Line Items]
Interest rate	4.20%
Long-term debt	$ 11,000
Less: current portion of long-term debt	(400)
Revolving Credit Facility | Line of Credit
Debt Instrument [Line Items]
Long-term debt	$ 0
Predecessor
Debt Instrument [Line Items]
Long-term debt				$ 1,427,800
Less: current portion of long-term debt				(408)
Less: liabilities subject to compromise				(1,075,000)
Long-term debt				$ 352,376
Predecessor | 7 ½% Senior Second Lien Notes due 2022 | Senior Notes
Debt Instrument [Line Items]
Interest rate				7.50%
Long-term debt				$ 0
Predecessor | 1 ¾% Senior Convertible Notes due 2017
Debt Instrument [Line Items]
Interest rate				1.75%
Predecessor | 1 ¾% Senior Convertible Notes due 2017 | Convertible Debt
Debt Instrument [Line Items]
Interest rate				1.75%
Long-term debt				$ 300,000
Predecessor | 7 ½% Senior Notes due 2022 | Senior Notes
Debt Instrument [Line Items]
Long-term debt				$ 775,000
Predecessor | 4.20% Building Loan | Secured Debt
Debt Instrument [Line Items]
Interest rate				4.20%
Long-term debt				$ 11,300
Predecessor | Revolving Credit Facility | Line of Credit
Debt Instrument [Line Items]
Long-term debt				$ 341,500

DEBT - Additional Information (

DEBT - Additional Information (Details)

Mar. 01, 2017USD ($)

Feb. 28, 2017USD ($)

Jun. 10, 2016$ / shares

Jun. 24, 2014USD ($)

Mar. 06, 2012USD ($)$ / shares

Sep. 30, 2017USD ($)

Sep. 30, 2016USD ($)

Sep. 30, 2017USD ($)

Sep. 30, 2016USD ($)

Feb. 27, 2017USD ($)

Dec. 31, 2016USD ($)

Jun. 14, 2016USD ($)

Nov. 20, 2015USD ($)

Nov. 27, 2013USD ($)

Nov. 08, 2012USD ($)

Debt Instrument [Line Items]

Current portion of long-term debt

$ 421,000

$ 421,000

Outstanding balance on building loan

236,000,000

236,000,000

Line of Credit | Revolving Credit Facility

Debt Instrument [Line Items]

Outstanding balance on building loan

0

0

Senior Notes Due 2022

Debt Instrument [Line Items]

Aggregate principal amount of senior subordinated notes

$ 475,000,000

$ 300,000,000

Extinguishment of debt

$ 775,000,000

Predecessor

Debt Instrument [Line Items]

Current portion of long-term debt

$ 408,000

Fair value of amount outstanding

$ 341,500,000

Outstanding balance on building loan

1,427,800,000

Stock split ratio

0.1

Interest expense related to contractual interest coupon of convertible notes

$ 1,300,000

$ 3,900,000

Predecessor | Minimum

Debt Instrument [Line Items]

Percentage of borrowing base utilization, percent

1.50%

Predecessor | Maximum

Debt Instrument [Line Items]

Percentage of borrowing base utilization, percent

2.50%

Predecessor | Line of Credit | Revolving Credit Facility

Debt Instrument [Line Items]

Outstanding balance on building loan

$ 341,500,000

Predecessor | Revolving credit facility

Debt Instrument [Line Items]

Available for borrowing

$ 150,000,000

Outstanding borrowing under bank credit facility

$ 12,500,000

Redetermined base borrowing and credit facility

$ 900,000,000

Predecessor | 1 3⁄4% Senior Convertible Notes due 2017

Debt Instrument [Line Items]

Aggregate principal amount of senior subordinated notes

$ 300,000,000

Initial conversion rate of common stock

0.0023449

0.0234449

Initial conversion price of convertible note 2017 (in usd per share) | $ / shares

$ 426.50

$ 42.65

Interest expense related to amortization of discount

4,100,000

12,000,000

Amortization of deferred financing costs

$ 400,000

$ 1,100,000

Bank of America, N.A. | Letter of Credit

Debt Instrument [Line Items]

Outstanding borrowing under bank credit facility

$ 12,500,000

Bank of America, N.A. | Line of Credit | Revolving Credit Facility

Debt Instrument [Line Items]

Consolidated interest coverage ratio (not less than)

2.75

Minimum liquidity required (at least)

0.2

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period One

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.75

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Two

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.50

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Three

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

3

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Four

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.75

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Five

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.50

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Six

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.75

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Seven

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

3

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Eight

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

3.50

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Nine

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

3

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Ten

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.75

Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Period Eleven

Debt Instrument [Line Items]

Consolidated funded debt to consolidated EBITDA ratio

2.50

4.20% Building Loan | Secured Debt

Debt Instrument [Line Items]

Current portion of long-term debt

$ 400,000

$ 400,000

Interest rate

4.20%

4.20%

Outstanding balance on building loan

$ 11,000,000

$ 11,000,000

4.20% Building Loan | Predecessor | Secured Debt

Debt Instrument [Line Items]

Interest rate

4.20%

Aggregate principal amount of senior subordinated notes

$ 11,800,000

Outstanding balance on building loan

$ 11,300,000

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Revolving Credit Facility

Debt Instrument [Line Items]

Long-term line of credit

0

0

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Letter of Credit

Debt Instrument [Line Items]

Outstanding borrowing under bank credit facility

12,600,000

12,600,000

Remaining borrowing capacity

$ 137,400,000

$ 137,400,000

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Line of Credit | Revolving Credit Facility

Debt Instrument [Line Items]

Available for borrowing

$ 150,000,000

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Base Rate | Minimum

Debt Instrument [Line Items]

Percentage of borrowing base utilization, percent

2.00%

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Line of Credit | Revolving Credit Facility | Base Rate | Maximum

Debt Instrument [Line Items]

Percentage of borrowing base utilization, percent

3.00%

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Line of Credit | Revolving Credit Facility | LIBOR | Minimum

Debt Instrument [Line Items]

Percentage of borrowing base utilization, percent

3.00%

Fifth Amended and Restated Credit Agreement | Bank of America, N.A. | Line of Credit | Revolving Credit Facility | LIBOR | Maximum

Debt Instrument [Line Items]

Percentage of borrowing base utilization, percent

4.00%

7 ½% Senior Second Lien Notes due 2022 | Senior Notes

Debt Instrument [Line Items]

Interest rate

7.50%

7.50%

7.50%

Aggregate principal amount of senior subordinated notes

$ 225,000,000

Outstanding balance on building loan

$ 225,000,000

$ 225,000,000

Accrued interest

$ 9,800,000

Redemption price percentage

107.50%

Percentage of minimum principal amount outstanding

65.00%

Debt default, percentage of principal amount outstanding

25.00%

7 ½% Senior Second Lien Notes due 2022 | Senior Notes | Debt Instrument, Redemption, Period One

Debt Instrument [Line Items]

Percentage of principal amount redeemed (up to)

35.00%

Redemption price percentage

105.625%

7 ½% Senior Second Lien Notes due 2022 | Senior Notes | Debt Instrument, Redemption, Period Two

Debt Instrument [Line Items]

Percentage of principal amount redeemed (up to)

100.00%

Redemption price percentage

105.625%

7 ½% Senior Second Lien Notes due 2022 | Senior Notes | Debt Instrument, Redemption, Period Three

Debt Instrument [Line Items]

Redemption price percentage

100.00%

7 ½% Senior Second Lien Notes due 2022 | Predecessor | Senior Notes

Debt Instrument [Line Items]

Interest rate

7.50%

Outstanding balance on building loan

$ 0

ASSET RETIREMENT OBLIGATIONS -

ASSET RETIREMENT OBLIGATIONS - Changes in Asset Retirement Obligations (Details) - USD ($) $ in Thousands	Feb. 28, 2017	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligations beginning balance					$ 290,100
Liabilities settled					(53,100)
Accretion expense			$ 8,095		19,698
Revision of estimates					11,000
Asset retirement obligations ending balance	$ 290,100	$ 290,100	$ 267,600		267,600
Predecessor
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligations beginning balance		242,000			$ 235,200
Liabilities settled		(3,600)
Divestment of properties		(8,700)
Accretion expense		5,447		$ 10,082		$ 30,147
Fair value fresh start adjustment	54,900
Asset retirement obligations ending balance	$ 235,200	$ 235,200

INCOME TAXES (Details)

INCOME TAXES (Details) $ in Thousands	Sep. 30, 2017USD ($)
Valuation Allowance [Line Items]
Current income tax receivable	$ 27,672
Ceiling Test Write Downs From Decline in Commodity Prices
Valuation Allowance [Line Items]
Valuation allowance	$ 236,700

ACCUMULATED OTHER COMPREHENSI62

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) - Additional Information (Details) - Predecessor $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)	Dec. 31, 2016contract
Accumulated Other Comprehensive Income (Loss) [Line Items]
Number of derivative instruments outstanding | contract		0
Other operational expenses | Foreign Currency Items
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amount reclassified from accumulated other comprehensive income | $	$ 6

FAIR VALUE MEASUREMENTS - Asset

FAIR VALUE MEASUREMENTS - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($)	Sep. 30, 2017	Dec. 31, 2016
Assets
Marketable securities (Other assets)	$ 9,300,000
Derivative contracts	3,600,000
Assets, fair value, total	12,900,000
Liabilities
Derivative contracts, liabilities	500,000
Liabilities, fair value, total	500,000
Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets
Marketable securities (Other assets)	9,300,000
Derivative contracts	0
Assets, fair value, total	9,300,000
Liabilities
Derivative contracts, liabilities	0
Liabilities, fair value, total	0
Significant Other Observable Inputs (Level 2)
Assets
Marketable securities (Other assets)	0
Derivative contracts	500,000
Assets, fair value, total	500,000
Liabilities
Derivative contracts, liabilities	100,000
Liabilities, fair value, total	100,000
Significant Unobservable Inputs (Level 3)
Assets
Marketable securities (Other assets)	0
Derivative contracts	3,100,000
Assets, fair value, total	3,100,000
Liabilities
Derivative contracts, liabilities	400,000
Liabilities, fair value, total	$ 400,000
Predecessor
Assets
Marketable securities (Other assets)		$ 8,700,000
Assets, fair value, total		8,700,000
Liabilities
Liabilities, fair value, total		0
Predecessor | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets
Marketable securities (Other assets)		8,700,000
Assets, fair value, total		8,700,000
Predecessor | Significant Other Observable Inputs (Level 2)
Assets
Marketable securities (Other assets)		0
Assets, fair value, total		0
Predecessor | Significant Unobservable Inputs (Level 3)
Assets
Marketable securities (Other assets)		0
Assets, fair value, total		$ 0

ACCUMULATED OTHER COMPREHENSI64

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) - Schedule of Changes in Accumulated Other Comprehensive Income Loss (Detail) - Predecessor - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016
Cash Flow Hedges
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance, net of tax	$ 7.4	$ 24
Other comprehensive income (loss) before reclassifications:
Change in fair value of derivatives	2.3	(1.7)
Income tax effect	(0.8)	0.6
Net of tax	1.5	(1.1)
Amounts reclassified from accumulated other comprehensive income
Income tax effect	(2.7)	(10.4)
Net of tax	5	19
Other comprehensive loss, net of tax	(3.5)	(20.1)
Ending balance, net of tax	3.9	3.9
Cash Flow Hedges | Operating revenue: oil/natural gas production
Amounts reclassified from accumulated other comprehensive income
Operating revenue: oil/natural gas production	7.7	29.4
Cash Flow Hedges | Other operational expenses
Amounts reclassified from accumulated other comprehensive income
Operating revenue: oil/natural gas production		0
Foreign Currency Items
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance, net of tax		(6)
Other comprehensive income (loss) before reclassifications:
Change in fair value of derivatives		0
Income tax effect		0
Net of tax		0
Amounts reclassified from accumulated other comprehensive income
Income tax effect		0
Net of tax		(6)
Other comprehensive loss, net of tax		6
Ending balance, net of tax	0	0
Foreign Currency Items | Operating revenue: oil/natural gas production
Amounts reclassified from accumulated other comprehensive income
Operating revenue: oil/natural gas production		0
Foreign Currency Items | Other operational expenses
Amounts reclassified from accumulated other comprehensive income
Operating revenue: oil/natural gas production		(6)
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance, net of tax		18
Other comprehensive income (loss) before reclassifications:
Change in fair value of derivatives		(1.7)
Income tax effect		0.6
Net of tax		(1.1)
Amounts reclassified from accumulated other comprehensive income
Income tax effect		(10.4)
Net of tax		13
Other comprehensive loss, net of tax		(14.1)
Ending balance, net of tax	$ 3.9	3.9
Accumulated Other Comprehensive Income (Loss) | Operating revenue: oil/natural gas production
Amounts reclassified from accumulated other comprehensive income
Operating revenue: oil/natural gas production		29.4
Accumulated Other Comprehensive Income (Loss) | Other operational expenses
Amounts reclassified from accumulated other comprehensive income
Operating revenue: oil/natural gas production		$ (6)

FAIR VALUE MEASUREMENTS - Addit

FAIR VALUE MEASUREMENTS - Additional Information (Details) - USD ($)	Sep. 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Liabilities, fair value	$ 500,000
7 ½% Senior Notes due 2022
Debt Instrument [Line Items]
Fair value of notes	$ 220,500,000
Predecessor
Debt Instrument [Line Items]
Liabilities, fair value		$ 0
Predecessor | 1 3⁄4% Senior Convertible Notes due 2017
Debt Instrument [Line Items]
Fair value disclosures		293,500,000
Predecessor | 7 ½% Senior Notes due 2022
Debt Instrument [Line Items]
Fair value of notes		$ 465,000,000

FAIR VALUE MEASUREMENTS - Hedgi

FAIR VALUE MEASUREMENTS - Hedging Contracts (Details) - USD ($) $ in Millions	2 Months Ended	7 Months Ended
	Feb. 28, 2017	Sep. 30, 2017
Hedging Contracts, net
Balance, beginning of the period		$ 3.1
Total gains/(losses) (realized or unrealized):
Included in earnings		(1.3)
Included in other comprehensive income		0
Purchases, sales, issuances and settlements		1
Transfers in and out of Level 3		0
Balance, end of the period	$ 3.1	2.8
The amount of total gains/(losses) for the period included in earnings (derivative income) attributable to the change in unrealized gain/(losses) relating to derivatives still held at September 30, 2017		$ (1.7)
Predecessor
Hedging Contracts, net
Balance, beginning of the period	0
Total gains/(losses) (realized or unrealized):
Included in earnings	(0.6)
Included in other comprehensive income	0
Purchases, sales, issuances and settlements	3.7
Transfers in and out of Level 3	$ 0

FEDERAL ROYALTY RECOVERY (Detai

FEDERAL ROYALTY RECOVERY (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Jul. 31, 2017	Sep. 30, 2017
Royalty Revenues [Line Items]
Federal royalty recovery revenue	$ 14.1
Consulting fees		$ 3.9
Other Revenue, Net
Royalty Revenues [Line Items]
Federal royalty recovery revenue	9.6
Oil And Gas Property, Lease Operating Expense
Royalty Revenues [Line Items]
Federal royalty recovery revenue	$ 4.5

REDUCTION IN WORKFORCE (Details

REDUCTION IN WORKFORCE (Details) $ in Millions	3 Months Ended
	Jun. 30, 2017USD ($)
Restructuring Cost and Reserve [Line Items]
Reduction in total workforce, percent	20.00%
Severance costs	$ 5.7
Payments for restructuring	4.5
Severance payments and related employer payroll taxes	1.2
Appalachia Properties
Restructuring Cost and Reserve [Line Items]
Severance costs	$ 3

OTHER OPERATIONAL EXPENSES (Det

OTHER OPERATIONAL EXPENSES (Details) - USD ($) $ in Thousands	2 Months Ended	3 Months Ended		7 Months Ended	9 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other operational expenses		$ 703		$ 3,292
Stacking charges				$ 2,100
Predecessor
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other operational expenses	$ 530		$ 9,059		$ 49,266
Oil and gas, subsidy charges					15,300
Predecessor | Foreign Currency Items
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other operational loss					6,000
Pompano Rig | Predecessor
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Loss on contract termination					20,000
Appalachian Rig | Predecessor
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Loss on contract termination					$ 7,500

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - Additional Information (Details) - Bureau of Ocean Energy Management - Predecessor - USD ($) $ in Millions	Sep. 12, 2016	Sep. 30, 2017
Loss Contingencies [Line Items]
Percentage of maximum net worth allowed for self insurance	10.00%
Surety bond		$ 118

NEW YORK STOCK EXCHANGE COMPL71

NEW YORK STOCK EXCHANGE COMPLIANCE (Details) - USD ($)	May 17, 2016	Sep. 30, 2017	Dec. 31, 2016
Fresh-Start Adjustment [Line Items]
NASDAQ listing rules, minimum market value of publicly held shares		$ 50,000,000
Stockholders' equity		$ 290,746,000
Predecessor
Fresh-Start Adjustment [Line Items]
NASDAQ listing rules, minimum market value of publicly held shares	$ 50,000,000
NASDAQ listing rules, number of consecutive business days	30 days
Stockholders' equity	$ 50,000,000		$ (637,282,000)