Ranger Oil (ROCC) 10-K 16 Mar 17 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Mar. 10, 2017	Jun. 30, 2016
Document Documentand Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	PVAC
Entity Registrant Name	PENN VIRGINIA CORP
Entity Central Index Key	77,159
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Smaller Reporting Accelerated Filer
Entity Common Stock, Shares Outstanding		14,992,018
Entity Public Float			$ 872,468

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	4 Months Ended	8 Months Ended		12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016		Dec. 31, 2015		Dec. 31, 2014
Revenues
Crude oil	$ 33,157	$ 81,377		$ 220,596		$ 420,286
Natural gas liquids	2,707	6,064		16,905		34,552
Natural gas	2,790	6,208		25,479		58,044
Gain (loss) on sales of assets, net	(49)	1,261		41,335		120,769
Other, net	398	(600)		983		3,122
Total revenues	39,003	94,310		305,298		636,773
Operating expenses
Lease operating	5,331	15,626		42,428		48,298
Gathering, processing and transportation	3,043	13,235		23,815		18,294
Production and ad valorem taxes	2,498	3,490		16,282		27,990
General and administrative	5,088	38,945		43,328		49,005
Exploration	0	10,288		12,583		17,063
Depreciation, depletion and amortization	11,652	33,582		334,479		300,299
Impairments	0	0		1,397,424		791,809
Total operating expenses	27,612	115,166		1,870,339		1,252,758
Operating income (loss)	11,391	(20,856)		(1,565,041)		(615,985)
Other income (expense)
Interest expense	(879)	(58,018)		(90,951)		(88,831)
Derivatives	(16,622)	(8,333)		71,247		162,212
Other, net	814	(3,184)		(3,587)		1,334
Reorganization Items	0	1,144,993		0		0
Income (loss) before income taxes	(5,296)	1,054,602		(1,588,332)		(541,270)
Income tax benefit	0	0		5,371		131,678
Net income (loss)	(5,296)	1,054,602		(1,582,961)		(409,592)
Preferred stock dividends	0	(5,972)	[1]	(22,789)	[1]	(17,148)	[1]
Induced conversion of preferred stock	0	0		0		(4,256)
Net loss attributable to common shareholders	$ (5,296)	$ 1,048,630		$ (1,605,750)		$ (430,996)
Net income (loss) per share:
Basic (in dollars per share)	$ (0.35)	$ 11.91		$ (21.81)		$ (6.26)
Diluted (in dollars per share)	$ (0.35)	$ 8.50		$ (21.81)		$ (6.26)
Weighted average shares outstanding – basic	14,992	88,013		73,639		68,887
Weighted average shares outstanding – diluted	14,992	124,087		73,639		68,887
[1]	Preferred stock dividends were excluded from diluted earnings per share for the years ended December 31, 2015 and 2014, respectively, as the assumed conversion of the outstanding preferred stock would have been anti-dilutive.

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Net income (loss)	$ (5,296)	$ 1,054,602	$ (1,582,961)	$ (409,592)
Other comprehensive income (loss):
Change in pension and postretirement obligations, net of tax of $39 for the Successor period from September 13, 2016 through December 31, 2016, $(226) for the Predecessor period from January 1, 2016 through September 12, 2016, and $93 and $(10), for 2015 and 2014, respectively	73	(421)	173	(18)
Total other comprehensive income (loss), net of tax	73	(421)	173	(18)
Comprehensive income (loss)	$ (5,223)	$ 1,054,181	$ (1,582,788)	$ (409,610)

CONDENSED CONSOLIDATED STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Thousands	8 Months Ended	12 Months Ended
	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Change in pension and postretirement obligations, tax	$ (226)	$ 93	$ (10)

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 6,761	$ 11,955
Accounts receivable, net of allowance for doubtful accounts	29,095	47,965
Derivative assets	0	97,956
Other current assets	3,028	7,104
Total current assets	38,884	164,980
Property and equipment, net	247,473	344,395
Other assets	5,329	8,350
Total assets	291,686	517,725
Current liabilities
Accounts payable and accrued liabilities	49,697	103,525
Derivative Liability, Current	12,932	0
Current portion of long-term debt, net of unamortized issuance costs	0	1,224,383
Total current liabilities	62,629	1,327,908
Other liabilities	4,072	104,938
Derivative Liability, Noncurrent	14,437	0
Deferred income taxes	0	0
Long-term debt	25,000	0
Commitments and contingencies (Note 16)
Shareholders’ equity (deficit):
Predecessor deferred compensation obligation	0	3,440
Total shareholders’ equity (deficit)	185,548	(915,121)
Total liabilities and shareholders’ equity (deficit)	291,686	517,725
Successor [Member]
Shareholders’ equity (deficit):
Predecessor preferred stock of $100 par value – 100,000 shares authorized; Series A – 3,915 shares issued as of December 31, 2015 and Series B – 27,551 shares issued as of December 31, 2015, each with a redemption value of $10,000 per share	0	0
Predecessor common stock of $0.01 par value – 228,000,000 shares authorized; 81,252,676 shares issued as of December 31, 2015	150	0
Predecessor paid-in capital	190,621	0
Predecessor accumulated other comprehensive income	73	0
Predecessor [Member]
Shareholders’ equity (deficit):
Predecessor preferred stock of $100 par value – 100,000 shares authorized; Series A – 3,915 shares issued as of December 31, 2015 and Series B – 27,551 shares issued as of December 31, 2015, each with a redemption value of $10,000 per share	0	3,146
Predecessor common stock of $0.01 par value – 228,000,000 shares authorized; 81,252,676 shares issued as of December 31, 2015	0	628
Predecessor paid-in capital	0	1,211,088
Accumulated deficit	(5,296)	(2,130,271)
Predecessor accumulated other comprehensive income	0	422
Predecessor treasury stock – 455,689 shares of common stock, at cost, as of December 31, 2015	$ 0	$ (3,574)

CONDENSED CONSOLIDATED BALANCE6

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivative Liability, Noncurrent	$ 14,437	$ 0
Preferred stock, par value	$ 0.01	$ 100
Preferred stock, shares authorized	5,000,000	100,000
Preferred stock liquidation preference (in dollars per share)	$ 0	$ 10,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	45,000,000	228,000,000
Common stock, shares issued	14,992,018	81,252,676
Treasury stock, shares	0	455,689
Series A Preferred Stock
Preferred stock, shares issued	0	3,915
Series B Preferred Stock
Preferred stock, shares issued	0	27,551

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivatives Settled to Pay Down Revolver	$ 0	$ 51,979	$ 0	$ 0
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	(5,296)	1,054,602	(1,582,961)	(409,592)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Non-Cash Reorganization Items	0	(1,178,302)	0	0
Depreciation, depletion and amortization	11,652	33,582	334,479	300,299
Impairments	0	0	1,397,424	791,809
Accretion of firm transportation obligation	0	317	942	1,301
Derivative contracts:
Net losses (gains)	16,622	8,333	(71,247)	(162,212)
Cash settlements, net	384	48,008	138,169	(7,424)
Deferred income tax benefit	0	0	(4,712)	(135,227)
Loss (gain) on sales of assets, net	49	(1,261)	(41,335)	(120,769)
Non-cash exploration expense	0	6,038	5,759	10,346
Non-cash interest expense	226	22,189	4,749	4,197
Share-based compensation (equity-classified)	81	1,511	4,540	3,627
Other, net	21	(13)	13	94
Changes in operating assets and liabilities:
Accounts receivable, net	10,791	12,273	137,854	(20,169)
Accounts payable and accrued expenses	(3,887)	22,469	(152,553)	27,362
Other assets and liabilities	131	501	(1,818)	(918)
Net cash provided by operating activities	30,774	30,247	169,303	282,724
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(4,812)	(15,359)	(364,844)	(774,139)
Receipts to settle working capital adjustments assumed in acquisition, net	0	0	0	33,712
Proceeds from sales of assets, net	0	224	85,189	313,933
Other Investing Activities, Net	(104)	1,186	0	0
Net cash used in investing activities	(4,916)	(13,949)	(279,655)	(426,494)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from credit facility borrowings	0	75,350	233,000	412,000
Repayment of credit facility borrowings	(50,350)	(119,121)	(98,000)	(583,000)
Proceeds from the issuance of preferred stock, net	0	0	0	313,330
Payments to induce conversion of preferred stock	0	0	0	(4,256)
Debt issuance costs paid	0	(3,011)	(744)	(151)
Proceeds Received from Rights Offering	0	49,943	0	0
Dividends paid on preferred stock	0	0	(18,201)	(12,803)
Other, net	(161)	0	0	1,428
Net cash (used in) provided by financing activities	(50,511)	3,161	116,055	126,548
Net (decrease) increase in cash and cash equivalents	(24,653)	19,459	5,703	(17,222)
Cash and cash equivalents - beginning of period	31,414	11,955	6,252	23,474
Cash and cash equivalents - end of period	6,761	31,414	11,955	6,252
Cash paid for:
Cash paid for interest (net of amounts capitalized)	598	4,331	86,226	84,797
Cash paid for income taxes (net of refunds)	(7)	(35)	(714)	3,612
Payments for Restructuring	525	30,990	0	0
Common Stock Issued in Exchange for Liabilities	0	140,952	0	0
Changes in accrued liabilities related to capital expenditures	$ (997)	$ (11,301)	$ (55,660)	$ (24,715)

CONSOLIDATED STATEMENTS OF SHAR

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Preferred Stock	Common Stock	Paid-in Capital	Retained Earnings (Accumulated Deficit)	Deferred Compensation Obligation	Accumulated Other Comprehensive Income (Loss)	Treasury Stock	Predecessor [Member]Preferred Stock	Predecessor [Member]Common Stock	Predecessor [Member]Paid-in Capital	Predecessor [Member]Retained Earnings (Accumulated Deficit)	Predecessor [Member]Deferred Compensation Obligation	Predecessor [Member]Accumulated Other Comprehensive Income (Loss)	Predecessor [Member]Treasury Stock
Balance as of beginning of period (in shares) at Dec. 31, 2013			65,307,000
Balance as of beginning of period at Dec. 31, 2013	$ 788,804	$ 1,150	$ 466	$ 891,351	$ (104,180)	$ 2,792	$ 267	$ (3,042)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(409,592)				(409,592)
Dividends declared on preferred stock	0				(17,148)			0
Issuance of stock (in shares)			0
Issuance of common stock	313,330			310,080
Issuance of preferred stock		3,250
Conversion of preferred stock (in shares)			5,926,000
Conversion of preferred stock		(356)	$ 59	297	0
Induced conversion of preferred stock	(4,256)		$ 0	0
Share-based compensation (in shares)			15,000
Payments to induce conversion of preferred stock	3,627		$ 1	3,626
Deferred compensation (in shares)			0
Dividends declared on preferred stock ($600.00 and $348.33 per Series A and Series B preferred share, respectively)	(17,148)			0		(419)		303
Exercise of stock options (in shares)			257,000
Stock Issued During Period, Value, Stock Options Exercised	1,428		$ 3	1,425
Restricted stock unit vesting (in shares)			64,000
Deferred compensation	116		$ 0	(474)
Stock Issued During Period, Value, Restricted Stock Award, Gross	(474)
Exercise of stock options	(18)						(18)
Other	18			0
Balance as of end of period (in shares) at Dec. 31, 2014			71,569,000
Balance as of end of period at Dec. 31, 2014	675,817	4,044	$ 529	1,206,305	(535,176)	3,211	249	(3,345)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(1,582,961)				(1,582,961)
Dividends declared on preferred stock	(12,134)				12,134
Conversion of preferred stock (in shares)			9,414,000
Conversion of preferred stock	0	(898)	$ 94	804
Induced conversion of preferred stock	0				0
Share-based compensation (in shares)			195,000
Payments to induce conversion of preferred stock	4,540		$ 4	4,536
Deferred compensation (in shares)			2,000
Dividends declared on preferred stock ($600.00 and $348.33 per Series A and Series B preferred share, respectively)	0			0		(229)		229
Restricted stock unit vesting (in shares)			73,000
Deferred compensation	(556)		$ 1	(557)
Exercise of stock options	173						173
Balance as of end of period (in shares) at Dec. 31, 2015			81,253,000
Balance as of end of period at Dec. 31, 2015	(915,121)	3,146	$ 628	1,211,088	(2,130,271)	3,440	422	(3,574)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,054,602				1,054,602
Conversion of preferred stock (in shares)			6,965,000
Conversion of preferred stock	(38)
Induced conversion of preferred stock	0
Payments to induce conversion of preferred stock				1,511
Stock Issued During Period, Value, Stock Options Exercised	1,511
Deferred compensation	49,943
Exercise of stock options	(421)
Other		1,266	$ (69)	(1,198)			39
Balance as of end of period (in shares) at Sep. 12, 2016			88,218,000							0
Balance as of end of period at Sep. 12, 2016	0				0				$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Balance as of beginning of period (in shares) at Dec. 31, 2015			81,253,000
Balance as of beginning of period at Dec. 31, 2015	$ (915,121)	3,146	$ 628	1,211,088	(2,130,271)	3,440	422	(3,574)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of stock options (in shares)	0
Balance as of end of period (in shares) at Dec. 31, 2016			14,992,000
Balance as of end of period at Dec. 31, 2016	$ 185,548	0	$ 150	190,621	(5,296)	0	73	0
Issuance of Common Stock, Backstop Fee	9,059
Issuance of Common Stock, Exchange of Claims	$ 131,893
Postconfirmation, Shares outstanding	14,992,000
Postconfirmation, Stockholders' Equity	$ 190,895		150	190,745	0	0	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cancellation of Equity Upon Emergence from Bankruptcy	882,992	(1,880)	(697)	(1,213,797)	1,075,669	(3,440)	(383)	3,574
Cancellation of Total Equity Upon Emergence from Bankruptcy	(140,954)
Preconfirmation, Stockholders' Equity	140,954	1,880	$ 697	1,213,797	(1,075,669)	3,440	383	3,574
Cancellation of Equity Upon Emergence from Bankruptcy, Shares			(88,218,000)
Postconfirmation, Common Stock - Rights Offering			$ 76
Postconfirmation, Additional Paid-in Capital - Rights Offering			49,867
Postconfirmation, Common Stock - Backstop Fee			5
Postconfirmation, Additional paid-in capital - Backstop Fee			$ 9,054
Postconfirmation, Common Stock - Rights Offering, shares			7,634,000
Postconfirmation, Common Stock - Backstop Fee, Shares			473,000
Postconfirmation, Common Stock - Exchange of Claims,Shares			6,885,000
Postconfirmation, Common Stock - Exchange of Claims			$ 69
Postconfirmation, Additional paid-in capital - Exchange of Claims			$ 131,824
Balance as of beginning of period (in shares) at Sep. 12, 2016			88,218,000							0
Balance as of beginning of period at Sep. 12, 2016	0				0				$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(5,296)				(5,296)
Induced conversion of preferred stock	0
Payments to induce conversion of preferred stock				81
Exercise of stock options	73
Other	132			205	0	0	(73)	0
Balance as of end of period (in shares) at Dec. 31, 2016			14,992,000
Balance as of end of period at Dec. 31, 2016	$ 185,548	$ 0	$ 150	$ 190,621	$ (5,296)	$ 0	$ 73	$ 0

CONSOLIDATED STATEMENTS OF SHA9

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Dividends declared on common stock, per share
Series A Preferred Stock
Dividends declared on preferred stock, per share	$ 0	$ 0		300	600
Series B Preferred Stock
Dividends declared on preferred stock, per share	$ 0	$ 0		$ 300	$ 348.33

Nature of Operations

Nature of Operations	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Nature of Operations	Nature of Operations Penn Virginia Corporation (together with its consolidated subsidiaries unless the context otherwise requires, “Penn Virginia,” the “Company,” “we,” “us” or “our”) is an independent oil and gas company engaged in the onshore exploration, development and production of oil, natural gas liquids (“NGLs”) and natural gas. Our current operations consist primarily of drilling unconventional horizontal development wells and operating our producing wells in the Eagle Ford Shale (the “Eagle Ford”) in South Texas. Our operations are substantially concentrated with over 90 percent of our production, revenues and capital expenditures attributable to this region. We also have less significant operations in Oklahoma, primarily consisting of non-operated properties in the Granite Wash. In August 2016, we terminated our remaining operations in the Marcellus Shale in Pennsylvania and are currently in the process of remediating the sites of our former wells in that region.

Basis of Presentation

Basis of Presentation	12 Months Ended
	Dec. 31, 2016
Basis of Presentation [Abstract]
Business Description and Basis of Presentation [Text Block]	2. Basis of Presentation Comparability of Financial Statements to Prior Periods As discussed in further detail in Note 5 below, we have adopted and applied the relevant guidance provided in accounting principles generally accepted in the United States of America (“GAAP”) with respect to the accounting and financial statement disclosures for entities that have emerged from bankruptcy proceedings (“Fresh Start Accounting”). Accordingly, our Consolidated Financial Statements and Notes after September 12, 2016, are not comparable to the Consolidated Financial Statements and Notes through that date. To facilitate our financial statement presentations, we refer to the reorganized company in these Consolidated Financial Statements and Notes as the “Successor” for periods subsequent to September 12, 2016, and the “Predecessor” for periods prior to September 13, 2016. Furthermore, our Consolidated Financial Statements and Notes have been presented with a “black line” division to delineate the lack of comparability between the Predecessor and Successor. In addition, we have adopted the full cost method of accounting for our oil and gas properties effective with our adoption of Fresh Start Accounting. Accordingly, our results of operations and financial position for the Successor periods will be substantially different from our historic trends. We have applied the relevant guidance provided in GAAP with respect to the accounting and financial statement disclosures for entities that have filed petitions with the bankruptcy court and expect to reorganize as going concerns in preparing our Consolidated Financial Statements and Notes through the period ended September 12, 2016, or Predecessor periods. That guidance requires that, for periods subsequent to our bankruptcy filing on May 12, 2016, or post-petition periods, certain transactions and events that were directly related to our reorganization be distinguished from our normal business operations. Accordingly, certain revenues, expenses, realized gains and losses and provisions that were realized or incurred in connection with the bankruptcy proceedings have been included in “Reorganization items, net” in our Consolidated Statement of Operations for the period ended September 12, 2016. In addition, certain liabilities and other obligations incurred prior to May 12, 2016, or pre-petition periods, have been classified in “Liabilities subject to compromise” on our Predecessor Consolidated Balance Sheet through September 12, 2016. Further detail for our “Reorganization items, net” and “Liabilities subject to compromise” are provided in Note 5 below. Going Concern Presumption Our Consolidated Financial Statements for the Successor period have been prepared on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities and other commitments in the normal course of business. Subsequent Events Management has evaluated all of our activities through the issuance date of our Consolidated Financial Statements and has concluded that no subsequent events have occurred that would require recognition in our Consolidated Financial Statements or disclosure in the Notes thereto. Recently Adopted Accounting Pronouncements In March 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”)2016–09, Improvements to Employee Share-based Payment Accounting (“ASU 2016–09”), which simplifies the accounting for share-based compensation. The areas for simplification that are applicable to publicly-held companies are as follows: (i) Accounting for Income Taxes, (ii) Classification of Excess Tax Benefits on the Statement of Cash Flows, (iii) Forfeitures, (iv) Minimum Statutory Tax Withholding Requirements and (v) Classification of Employee Taxes Paid on the Statement of Cash Flows when an employer withholds shares for tax-withholding purposes. The effective date of ASU 2016–09 is January 1, 2017, with early adoption permitted. We adopted ASU 2016–09 on September 12, 2016 effective upon our emergence from bankruptcy. The adoption of ASU 2016–09 did not have a significant impact on our Consolidated Financial Statements and Notes. Recently Issued Accounting Pronouncements Pending Adoption In June 2016, the FASB issued ASU 2016–13, Measurement of Credit Losses on Financial Instruments (“ASU 2016–13”), which changes the recognition model for the impairment of financial instruments, including accounts receivable, loans and held-to-maturity debt securities, among others. ASU 2016–13 is required to be adopted using the modified retrospective method by January 1, 2020, with early adoption permitted for fiscal periods beginning after December 15, 2018. In contrast to current guidance, which considers current information and events and utilizes a probable threshold, (an “incurred loss” model), ASU 2016–13 mandates an “expected loss” model. The expected loss model: (i) estimates the risk of loss even when risk is remote, (ii) estimates losses over the contractual life, (iii) considers past events, current conditions and reasonable supported forecasts and (iv) has no recognition threshold. ASU 2016–13 will have applicability to our accounts receivable portfolio, particularly those receivables attributable to our joint interest partners. At this time, we do not anticipate that the adoption of ASU 2016–13 will have a significant impact on our Consolidated Financial Statements and related disclosures; however, we are currently in the early stages of evaluating the requirements and the period for which we will adopt the standard. In February 2016, the FASB issued ASU 2016–02, Leases (“ASU 2016–02”), which will require organizations that lease assets to recognize on the balance sheet the assets and liabilities for the rights and obligations created by those leases with terms of more than twelve months. Consistent with current GAAP, the recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee primarily will depend on its classification as a finance or operating lease. ASU 2016–02 also will require disclosures regarding the amount, timing, and uncertainty of cash flows arising from leases. The effective date of ASU 2016–02 is January 1, 2019, with early adoption permitted. We believe that ASU 2016–02 will likely be applicable to our oil and natural gas gathering commitment arrangements as described in Note 16, our existing leases for office facilities and certain office equipment and potentially to certain drilling rig and completion contracts with terms in excess of twelve months to the extent we may have such contracts in the future. Our oil and natural gas gathering arrangements are fairly complex and involve multiple elements that could be construed as leases. Accordingly, we are continuing to evaluate the effect that ASU 2016–02 will have on our Consolidated Financial Statements and related disclosures as well as the period for which we will adopt the standard, however, at this time, we believe that we will likely adopt ASU 2016–02 in 2019. In May 2014, the FASB issued ASU 2014–09, Revenues from Contracts with Customers (“ASU 2014–09”), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014–09 will replace most existing revenue recognition guidance in GAAP when it becomes effective on January 1, 2018. The standard permits the use of either the retrospective or cumulative effect transition method upon adoption. While traditional commodity sales transactions, property conveyances and joint interest arrangements in the oil and gas industry are not expected to be significantly impacted by ASU 2014–09, natural gas imbalances and other non-product revenues, including our ancillary marketing, gathering and transportation and water service revenues could be affected. Accordingly, we are continuing to evaluate the effect that ASU 2014–09 will have on our Consolidated Financial Statements and related disclosures, with a more focused analysis on these other revenue sources, which we do not believe are significant. We are also continuing to monitor developments regarding ASU 2014–09 that are unique to our industry. We fully expect to adopt ASU 2014–09 in 2018.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Principles of Consolidation Our Consolidated Financial Statements include the accounts of Penn Virginia and all of its subsidiaries. Intercompany balances and transactions have been eliminated. Use of Estimates Preparation of our Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities in our Consolidated Financial Statements and the reported amounts of revenues and expenses during the reporting period. Such estimates include certain asset and liability valuations as further described in these Notes. Actual results could differ from those estimates. Cash and Cash Equivalents We consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. Derivative Instruments From time to time, we utilize derivative instruments to mitigate our financial exposure to commodity price and interest rate volatility. The derivative instruments, which are placed with financial institutions that we believe are of acceptable credit risk, take the form of collars, swaps and swaptions. All derivative transactions are subject to our risk management policy, which has been reviewed and approved by our Predecessor board of directors. All derivative instruments are recognized in our Consolidated Financial Statements at fair value. The fair values of our derivative instruments are determined based on discounted cash flows derived from quoted forward prices. Our derivative instruments are not formally designated as hedges. We recognize changes in fair value in earnings currently as a component of the Derivatives caption in our Consolidated Statements of Operations. We have experienced and could continue to experience significant changes in the amount of derivative gains or losses recognized due to fluctuations in the value of these commodity derivative contracts, which fluctuate with changes in commodity prices and interest rates. Oil and Gas Properties We have adopted the full cost method of accounting for our oil and gas properties effective with our adoption of Fresh Start Accounting. Under this method, all productive and nonproductive costs incurred in the exploration, development and acquisition of oil and gas reserves are capitalized. Such costs may be incurred both prior to and after the acquisition of a property and include lease acquisitions, geological and geophysical, or seismic, drilling, completion and equipment costs. Internal costs incurred that are directly attributable to exploration, development and acquisition activities undertaken by us for our own account, and which are not attributable to production, general corporate overhead or similar activities are also capitalized. Future development costs are estimated on a property-by-property basis based on current economic conditions and are amortized as a component of depreciation, depletion and amortization (“DD&A”). Unproved properties not being amortized include unevaluated leasehold costs and associated capitalized interest. These costs are reviewed quarterly to determine whether or not and to what extent proved reserves have been assigned to a property or if an impairment has occurred due to lease expirations, general economic conditions and other factors, in which case the related costs along with associated capitalized interest are reclassified to the proved oil and gas properties subject to DD&A. At the end of each quarterly reporting period, the unamortized cost of our oil and gas properties, net of deferred income taxes, is limited to the sum of the estimated discounted future net revenues from proved properties adjusted for costs excluded from amortization and related income taxes (a “Ceiling Test”). The estimated discounted future net revenues are determined using the prior 12-month’s average price based on closing prices on the first day of each month, adjusted for differentials, discounted at 10%. The calculation of the Ceiling Test and provision for DD&A are based on estimates of proved reserves. There are significant uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production, timing and plan of development. For the periods prior to the Effective Date, we applied the successful efforts method of accounting for our oil and gas properties. Under this method, costs of acquiring properties, costs of drilling successful exploration wells and development costs were capitalized. Seismic costs, delay rentals and costs to drill exploratory wells that did not find proved reserves were expensed as oil and gas exploration. We carried the costs of exploratory wells as assets if the wells had found a sufficient quantity of reserves to justify its completion as a producing well and as long as we were making sufficient progress assessing the reserves and the economic and operating viability of the project. For certain projects, it may have taken us more than one year to evaluate the future potential of the exploratory well and make determinations of their economic viability. Our ability to move forward on projects was dependent on gaining access to transportation or processing facilities or obtaining permits and government or partner approval, the timing of which was beyond our control. In such cases, exploratory well costs remained suspended as long as we were actively pursuing access to the necessary facilities or receiving such permits and approvals and believed that they would be obtained. We assessed the status of suspended exploratory well costs on a quarterly basis. Depreciation, Depletion and Amortization DD&A of our oil and gas properties is computed using the units-of-production method. We apply this method by multiplying the unamortized cost of our proved oil and gas properties, net of estimated salvage plus future development costs, by a rate determined by dividing the physical units of oil and gas produced during the period by the total estimated units of proved oil and gas reserves at the beginning of the period. DD&A of our proved properties while we applied the successful efforts method during the Predecessor periods was computed using the units-of-production method. Historically, we adjusted our depletion rate throughout the year as new data became available and in the fourth quarter based on our year-end reserve report through December 31, 2015. Other Property and Equipment Other property and equipment consists primarily of gathering systems and related support equipment. Property and equipment are carried at cost and include expenditures for additions and improvements, such as roads and land improvements, which increase the productive lives of existing assets. Maintenance and repair costs are charged to expense as incurred. Renewals and betterments, which extend the useful life of the properties, are capitalized. We compute depreciation and amortization of property and equipment using the straight-line balance method over the estimated useful life of each asset as follows: Gathering systems – fifteen to twenty years and Other property and equipment – three to twenty years. Impairment of Long-Lived Assets While we applied the successful efforts method of accounting for our oil and gas properties during the Predecessor periods, we reviewed our assets for impairment when events or circumstances indicated a possible decline in the recoverability of the carrying value of the properties. If the carrying value of the asset was determined to be impaired, we reduced the asset to its fair value. Fair value may have been estimated using comparable market data, a discounted cash flow method, or a combination of the two. In the discounted cash flow method, estimated future cash flows were based on management’s expectations for the future and included estimates of future production, commodity prices based on published forward commodity price curves as of the date of the estimate, operating and development costs, intent to develop properties and a risk-adjusted discount rate. We reviewed oil and gas properties for impairment periodically when events and circumstances indicated a decline in the recoverability of the carrying value of such properties, such as a downward revision of the reserve estimates or lower commodity prices. We estimated the future cash flows expected in connection with the properties and compared such future cash flows to the carrying amounts of the properties to determine if the carrying amounts were recoverable. Performing the impairment evaluations required use of judgments and estimates since the results were dependent on future events. Such events included estimates of proved and unproved reserves, future commodity prices, the timing of future production, capital expenditures and intent to develop properties, among others. The costs of unproved leaseholds, including associated interest costs for the period activities were in progress to bring projects to their intended use, were capitalized pending the results of exploration efforts. Unproved properties whose acquisition costs were insignificant to total oil and gas properties were amortized in the aggregate over the lesser of five years or the average remaining lease term and the amortization was charged to exploration expense. We assessed unproved properties whose acquisition costs were relatively significant, if any, for impairment on a stand-alone basis. As exploration work progressed and the reserves on properties were proved, capitalized costs of these properties became subject to depreciation and depletion. If the exploration work was unsuccessful, the capitalized costs of the properties related to the unsuccessful work was charged to exploration expense. The timing of any write-downs of any significant unproved properties depended upon the nature, timing and extent of future exploration and development activities and their results. Asset Retirement Obligations We recognize the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. Associated asset retirement costs are capitalized as part of the carrying cost of the asset. Our AROs relate to the plugging and abandonment of oil and gas wells and the associated asset is recorded as a component of oil and gas properties. After recording these amounts, the ARO is accreted to its future estimated value, and the additional capitalized costs are depreciated over the productive life of the assets. Both the accretion of the ARO and the depreciation of the related long-lived assets are included in the DD&A expense caption in our Consolidated Statements of Operations. Income Taxes We recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in the Company’s financial statements or tax returns. Using this method, deferred tax assets and liabilities are determined based on the difference between the financial statement carrying amounts and tax bases of assets and liabilities using enacted tax rates. In assessing our deferred tax assets, we consider whether a valuation allowance should be recorded for some or all of the deferred tax assets which may not be realized. The ultimate realization of deferred tax assets is assessed at each reporting period and is dependent upon the generation of future taxable income and our ability to utilize tax credits and operating loss carryforwards during the periods in which the temporary differences become deductible. We also consider the scheduled reversal of deferred tax liabilities and available tax planning strategies. We recognize interest attributable to income taxes, to the extent they arise, as a component of interest expense and penalties as a component of income tax expense. We are subject to ongoing tax examinations in numerous domestic jurisdictions. Accordingly, we may record incremental tax expense based upon the more-likely-than-not outcomes of uncertain tax positions. In addition, when applicable, we adjust the previously recorded tax expense to reflect examination results when the position is effectively settled. Our ongoing assessments of the more-likely-than-not outcomes of the examinations and related tax positions require judgment and can increase or decrease our effective tax rate, as well as impact our operating results. The specific timing of when the resolution of each tax position will be reached is uncertain. Revenue Recognition We record revenues associated with sales of crude oil, NGLs and natural gas when title passes to the customer. We recognize natural gas sales revenues from properties in which we have an interest with other producers on the basis of our net revenue interest (“entitlement” method of accounting). Natural gas imbalances occur when we sell more or less than our entitled ownership percentage of natural gas production. We treat any amount received in excess of our share as a liability. If we take less than we are entitled to take, we record the under-delivery as a receivable. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations and distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 60 days following the month of production. Therefore, we make accruals for revenues and accounts receivable based on estimates of our share of production, particularly from properties that are operated by our partners. We record any differences, which historically have not been significant, between the actual amounts ultimately received and the original estimates in the period they become finalized. Share-Based Compensation Our stock compensation plans permit the grant of incentive and nonqualified stock options, common stock, deferred common stock units, restricted stock and restricted stock units to our employees and directors. We measure the cost of employee services received in exchange for an award of equity-classified instruments based on the grant-date fair value of the award. Compensation cost associated with the liability-classified awards is measured at the end of each reporting period and recognized based on the period of time that has elapsed during the applicable performance period.

Bankruptcy Proceedings (Notes)

Bankruptcy Proceedings (Notes)	12 Months Ended
	Dec. 31, 2016
Bankruptcy Proceedings [Abstract]
Reorganization under Chapter 11 of US Bankruptcy Code Disclosure [Text Block]	Bankruptcy Proceedings and Emergence On May 12, 2016 (the “Petition Date”), we and eight of our subsidiaries (the “Chapter 11 Subsidiaries”) filed voluntary petitions ( In re Penn Virginia Corporation, et al, Case No. 16-32395 ) seeking relief under Chapter 11 of Title 11 of the United States Bankruptcy Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Eastern District of Virginia (the “Bankruptcy Court”). On August 11, 2016 (the “Confirmation Date”), the Bankruptcy Court confirmed our Second Amended Joint Chapter 11 Plan of Reorganization of Penn Virginia Corporation and its Debtor Affiliates (the “Plan”), and we subsequently emerged from bankruptcy on September 12, 2016 (the “Effective Date”). Debtors-In-Possession. From the Petition Date through the Effective Date, we and the Chapter 11 Subsidiaries operated our business as debtors-in-possession in accordance with the applicable provisions of the Bankruptcy Code. The Bankruptcy Court granted all “first day” motions filed by us and the Chapter 11 Subsidiaries, which were designed primarily to minimize the impact of the bankruptcy proceedings on our normal day-to-day operations, our customers, regulatory agencies, including taxing authorities, and employees. As a result, we were able to conduct normal business activities and pay all associated obligations for the post-petition period and we were also authorized to pay and have paid (subject to limitations applicable to payments of certain pre-petition obligations) pre-petition employee wages and benefits, pre-petition amounts owed to certain lienholders, amounts due to taxing authorities for production and other related taxes and funds belonging to third parties, including royalty and working interest holders. Pre-Petition Agreements. Immediately prior to the Petition Date, the holders (the “Ad Hoc Committee”) of approximately 86 percent of the $ 1,075 million principal amount of our 7.25% Senior Notes due 2019 (the “2019 Senior Notes”) and 8.50% Senior Notes due 2020 (the “2020 Senior Notes” and, together with the 2019 Senior Notes, the “Senior Notes”) agreed to a restructuring support agreement (the “RSA”) that set forth the general framework of the Plan and the timeline for the bankruptcy proceedings. In addition, we entered into a backstop commitment agreement (the “Backstop Commitment Agreement”) with the parties thereto (collectively, the “Backstop Parties”), pursuant to which the Backstop Parties committed to provide a $ 50 million commitment to backstop a rights offering (the “Rights Offering”) that was conducted in connection with the Plan. Plan of Reorganization . Pursuant to the terms of the Plan, which was supported by us, the holders (the “RBL Lenders”) of 100 percent of the claims attributable to our pre-petition credit agreement (as amended, the “RBL”), the Ad Hoc Committee and the Official Committee of Unsecured Claimholders (the “UCC”), the following transactions were completed subsequent to the Confirmation Date and prior to or at the Effective Date: • the approximately $ 1,122 million of indebtedness, including accrued interest, attributable to our Senior Notes and certain other unsecured claims were exchanged for 6,069,074 shares representing 41 percent of the Successor’s common stock (“New Common Stock”); • a total of $ 50 million of proceeds were received on the Effective Date from the Rights Offering resulting in the issuance of 7,633,588 shares representing 51 percent of New Common Stock to holders of claims arising under the Senior Notes, certain holders of general unsecured claims and to the Backstop Parties; • the Backstop Parties received a backstop fee comprised of 472,902 shares representing three percent of New Common Stock; • an additional 816,454 shares representing five percent of New Common Stock were authorized for disputed general unsecured claims and non-accredited investor holders of the Senior Notes and subsequently, 749,600 shares of New Common Stock were reserved for issuance under a new management incentive plan; • on the Effective Date, we entered into a shareholders agreement and a registration rights agreement and amended our articles of incorporation and bylaws for the authorization of the New Common Stock and to provide customary registration rights thereunder, among other corporate governance actions; • holders of claims arising under the RBL were paid in full from cash on hand, $ 75.4 million from borrowings under our new credit agreement (the “Credit Facility”) (see Note 11 below) and proceeds from the Rights Offering; • the debtor-in-possession credit facility (the “DIP Facility”), under which there were no outstanding borrowings at any time from the Petition Date through the Effective Date, was canceled and less than $ 0.1 million in fees were paid in full in cash; • certain other priority claims were paid in full in cash, reinstated or otherwise treated in a manner acceptable to the creditor claim-holders; • a cash reserve of $ 2.7 million was established for certain other secured, priority or convenience claims pending resolution as of the Effective Date; • an escrow account for professional service fees attributable to our advisers and those of the UCC was funded by us with cash of $ 14.6 million , and we paid $ 7.2 million for professional fees and expenses on behalf of the RBL Lenders, the Ad Hoc Committee and the indenture trustee for the Senior Notes; • on the Effective Date, our previous interim Chief Executive Officer, Edward B. Cloues, resigned and each member of our board of directors resigned and was replaced by new board members: Darin G. Holderness, CPA, Marc McCarthy and Harry Quarls and, in October 2016, Jerry R. Shuyler; • our Predecessor preferred stock and common stock was canceled, extinguished and discharged; and • all of our Predecessor share-based compensation plans and supplemental employee retirement plan (the “SERP”) entitlements were canceled. While our emergence from bankruptcy is effectively complete, certain administrative and claims resolution activities will continue under the authority of the Bankruptcy Court until complete. As of March 10, 2017, certain claims, including secured tax and other priority, administrative and convenience claims were still in the process of resolution. While most of these matters are unsecured claims for which shares of New Common Stock have been allocated, certain of these matters must be settled with cash payments. As of December 31, 2016, we had $ 3.9 million reserved for outstanding claims to be potentially settled in cash. This reserve is included as a component of “Accounts payable and accrued liabilities” on our Consolidated Balance Sheet.

Fresh Start Accounting (Notes)

Fresh Start Accounting (Notes)	12 Months Ended
	Dec. 31, 2016
Fresh Start Accounting [Abstract]
Fresh Start Accounting [Text Block]	Fresh Start Accounting We adopted Fresh Start Accounting on the Effective Date in connection with our emergence from bankruptcy. As referenced below, our reorganization value of $ 334.0 million , immediately prior to emergence was substantially less than our post-petition liabilities and allowed claims. Furthermore and in connection with our reorganization, we experienced a change in control as the outstanding common and preferred shares of the Predecessor were canceled and substantially all of the New Common Stock was issued to the Predecessor’s creditors, primarily former holders of our Senior Notes. Accordingly, the holders of the Predecessor’s common and preferred shares effectively received no shares of the Successor. The adoption of Fresh Start Accounting results in a new reporting entity, the Successor, for financial reporting purposes. The presentation is analogous to that of a new business entity such that the Successor is presented with no beginning retained earnings or deficit on the Effective Date. Reorganization Value Reorganization value represents the fair value of the Successor’s total assets prior to the consideration of liabilities and is intended to approximate the amount a willing buyer would pay for the assets immediately after a restructuring. The reorganization value, which was derived from the Successor’s enterprise value, was allocated to our individual assets based on their estimated fair values. Enterprise value represents the estimated fair value of an entity’s long term debt and shareholders’ equity. The Successor’s enterprise value, as approved by the Bankruptcy Court in support of the Plan, was estimated to be within a range of $ 218 million to $ 382 million with a mid-point value of $ 300 million . Based on the estimates and assumptions utilized in our Fresh Start Accounting process, we estimated the Successor’s enterprise value to be approximately $ 266.2 million after the consideration of cash and cash equivalents on hand at the Effective Date. The following table reconciles the enterprise value, net of cash and cash equivalents, to the estimated fair value of our Successor common stock as of the Effective Date: Enterprise value $ 234,831 Plus: Cash and cash equivalents 31,414 Less: Fair value of debt (75,350 ) Fair value of Successor common stock $ 190,895 Shares outstanding as of September 12, 2016 14,992,018 Per share value $ 12.73 The following table reconciles the enterprise value to the reorganization value of our Successor assets as of the Effective Date: Enterprise value $ 234,831 Plus: Cash and cash equivalents 31,414 Plus: Current liabilities 54,171 Plus: Noncurrent liabilities excluding long-term debt 13,558 Reorganization value $ 333,974 Valuation Process Our valuation analysis was prepared with the assistance of an independent third-party consultant utilizing reserve information prepared by our independent reserve engineers, internal development plans and schedules, other internal financial information and projections and the application of standard valuation techniques including risked net asset value analysis and comparable public company metrics. Our principal assets include the Successor’s oil and gas properties. We determined the fair value of our oil and gas properties based on the discounted cash flows expected to be generated from these assets. Our analyses were based on market conditions and reserves in place as confirmed by our independent petroleum engineers. The proved reserves were segregated into various geographic regions, including sub-regions within the Eagle Ford where a substantial portion of our assets are located, for which separate risk factors were determined based on geological characteristics. Due to the limited drilling plans that we had in place, proved undeveloped locations were risked accordingly. Future cash flows were estimated by using NYMEX forward prices for West Texas Intermediate crude oil and Henry Hub natural gas with inflation adjustments applied to periods beyond a five-year horizon. These prices were adjusted for differentials realized by us for location and product quality. Gathering and transportation costs were estimated based on agreements that we have in place and development and operating costs were based on our most recent experience and adjusted for inflation in future years. The risk-adjusted after-tax cash flows were discounted at a rate of 13.5 %. This rate was determined from a weighted-average cost of capital computation which utilized a blended expected cost of debt and expected returns on equity for similar industry participants. Plugging and abandonment costs were also identified and measured in this process in order to determine the fair value of the Successor’s AROs attributable to our proved developed reserves on the Effective Date. Based on this valuation process, we determined fair values of $ 121.9 million for our proved reserves and $ 2.7 million for the related AROs. With respect to the valuation of our undeveloped acreage, we segregated our current lease holdings in the Eagle Ford into prospect regions in which we have significant developed acreage and those in which we have not yet initiated any significant drilling activity. For those prospects within previously developed regions, we applied a multiple based on recent transactions involving acreage deemed comparable to our acreage for each targeted formation. Based on this valuation process, we determined a fair value of $ 92.5 million for our undeveloped acreage within previously developed regions of the Eagle Ford. For those lease holdings in other areas of the Eagle Ford, we disregarded those prospects for which lease expirations were to occur during 2016 as well as those for which future drilling was considered uneconomical at then current commodity prices. A reduced multiple was then applied to this adjusted undeveloped acreage consistent with recent transactions for acreage deemed comparable to our acreage resulting in a fair value of $ 8.3 million . We attributed no value to our limited undeveloped lease holdings in all areas other than the Eagle Ford. Our remaining equipment and other fixed assets were valued at $ 26.7 million primarily using a cost approach that incorporated depreciation and obsolescence to the extent applicable on an asset-by-asset basis. The most significant of these assets is our water facility in South Texas which is integral to our regional operations. Accordingly, this asset, for which we determined a fair value of $ 23.4 million , is included in our full cost pool for purposes of determining our DD&A attributable to our oil and gas production. Certain assets, particularly personal property including office equipment and vehicles, among others, were valued based on market data for comparable assets to the extent such information was available. The remaining reorganization value is attributable to certain natural gas imbalance receivables, cash and cash equivalents, working capital assets including accounts receivable, prepaid items, current derivative assets and debt issuance costs. Our natural gas imbalance receivables, which are fully attributable to our Mid-Continent operations in the Granite Wash, were valued using NYMEX spot prices for Henry Hub natural gas adjusted for basis differentials for transportation. Our accounts receivable, including amounts receivable from our joint venture partners, were subjected to analysis on an individual basis and reserved to the extent we believe was appropriate. Collectively, these remaining assets, including our current derivative assets which are marked-to-market on a monthly basis, are stated at their fair values on the Effective Date. The reorganization value also includes $ 3.0 million of issuance costs attributable to the Credit Facility under which we initially borrowed $ 75.4 million . This amount has been capitalized in accordance with GAAP as it represents costs attributable to the access to credit over the term of the Credit Facility. Our liabilities on the Effective Date include the aforementioned borrowings under the Credit Facility, working capital liabilities including accounts payable and accrued liabilities, a reserve for certain litigation matters, pension and health care obligations attributable to certain retirees, AROs, and derivative liabilities. As the Credit Facility is current and is a variable-rate financial instrument, it is stated at its fair value. Our working capital liabilities and litigation reserve are ordinary course obligations and their carrying amounts approximate their fair values. We revalued our retiree obligations based on data from our independent actuaries and they have been stated at their fair values. The AROs were valued in connection with the valuation process attributable to our oil and gas reserves as discussed above. Finally, our derivative liabilities have also been stated at their fair value as they are marked-to-market on a monthly basis. Successor Balance Sheet The following table reflects the reorganization and application of Fresh Start Accounting adjustments on our Consolidated Balance Sheet as of September 12, 2016: Reorganization Fresh Start Predecessor Adjustments Adjustments Successor Assets Current assets Cash and cash equivalents $ 48,718 $ (17,304 ) (1 ) $ — $ 31,414 Accounts receivable, net of allowance for doubtful accounts 35,606 4,292 (2 ) — 39,898 Derivative assets 397 — — 397 Other current assets 3,966 (832 ) (3 ) — 3,134 Total current assets 88,687 (13,844 ) — 74,843 Property and equipment, net 309,261 — (55,751 ) (12 ) 253,510 Other assets 6,902 (1,281 ) (4 ) — 5,621 Total assets $ 404,850 $ (15,125 ) $ (55,751 ) $ 333,974 Liabilities and Shareholders’ Deficit Current liabilities Accounts payable and accrued liabilities $ 77,151 $ (21,166 ) (5 ) $ (3,455 ) (13 ) $ 52,530 Derivative liabilities 1,641 — — 1,641 Current maturities of long-term debt 113,653 (113,653 ) (6 ) — — Total current liabilities 192,445 (134,819 ) (3,455 ) 54,171 Other liabilities 84,953 100 (5 ) (80,615 ) (14 ) 4,438 Derivative liabilities 9,120 — — 9,120 Long-term debt — 75,350 (7 ) — 75,350 Liabilities subject to compromise 1,154,163 (1,154,163 ) (8 ) — — Shareholders’ equity (deficit) Preferred stock (Predecessor) 1,880 (1,880 ) (9 ) — — Common stock (Predecessor) 697 (697 ) (9 ) — — Paid-in capital (Predecessor) 1,213,797 (1,213,797 ) (9 ) — — Deferred compensation obligation (Predecessor) 3,440 (3,440 ) (9 ) — — Accumulated other comprehensive income (Predecessor) 383 (383 ) (9 ) — — Treasury stock (Predecessor) (3,574 ) 3,574 (9 ) — — Common stock (Successor) — 150 (10 ) — 150 Paid-in capital (Successor) — 190,745 (10 ) — 190,745 Accumulated deficit (2,252,454 ) 2,224,135 (11 ) 28,319 (15 ) — Total shareholders’ equity (deficit) (1,035,831 ) 1,198,407 28,319 190,895 Total liabilities and shareholders’ equity (deficit) $ 404,850 $ (15,125 ) $ (55,751 ) $ 333,974 Reorganization Adjustments 1. Represents the net cash payments that occurred on the Effective Date: Sources: Proceeds from the Credit Facility $ 75,350 Proceeds from the Rights Offering, net of issuance costs 49,943 Total sources $ 125,293 Uses: Repayment of RBL $ 113,653 Accrued interest payable on RBL 1,374 DIP Facility fees 12 Debt issue costs of the Credit Facility 3,011 Funding of professional fee escrow account 14,575 RBL lender professional fees and expenses 455 Ad Hoc Committee and indenture trustee professional fees and expenses 6,782 Payment of certain allowed claims and settlements 2,735 Total uses 142,597 $ (17,304 ) 2. Represents the reclassification of SERP assets to a current receivable from other noncurrent assets upon the cancellation of the underlying plan and the reversion of the assets to the Successor. 3. Represents the write-off of certain prepaid directors and officers tail insurance. 4. Represents the capitalization of debt issuance costs attributable to the Credit Facility, net of the reclassification of SERP assets as discussed in item (2) above. 5. Represents the payment of professional fees on behalf of the RBL Lenders, the Ad Hoc Committee and the UCC, indenture trustee fees and expenses, interest payable on the RBL as well as certain allowed claims and settlements net of the establishment of reserves and the reinstatement of certain other obligations. 6. Represents the repayment of the RBL in cash in full. 7. Represents the initial borrowings under the Credit Facility. 8. Liabilities subject to compromise were settled as follows in accordance with the Plan: Liabilities subject to compromise prior to the Effective Date: Senior Notes $ 1,075,000 Interest on Senior Notes 47,213 Firm transportation obligation 11,077 Compensation – related 9,733 Deferred compensation 4,676 Trade accounts payable 1,487 Litigation claims 1,092 Other accrued liabilities 3,885 $ 1,154,163 Amounts settled in cash, reinstated or otherwise reserved at emergence (3,915 ) Gain on settlement of liabilities subject to compromise $ 1,150,248 9. Represents the cancellation of our Predecessor preferred and common stock and related components of our Predecessor shareholders’ deficit. 10. Represents the issuance of 14,992,018 shares of New Common Stock with a fair value of $ 12.73 per share. 11. Represents the cumulative impact of the reorganization adjustments described above: Gain on settlement of of liabilities subject to compromise $ 1,150,248 Fair value of equity allocated to: Unsecured creditors on the Effective Date 174,477 Unsecured creditors pending resolution on the Effective Date 10,396 Backstop Parties in the form of a Commitment Premium 6,022 190,895 Cancellation of Predecessor shareholders’ deficit 882,992 Net impact to Predecessor accumulated deficit $ 2,224,135 Fresh Start Adjustments 12. Represents the Fresh Start Accounting valuation adjustments applied to our oil and gas properties and other equipment. 13. Represents the accelerated recognition of the current portion of previously deferred gains on sales of assets attributable to the accounting presentation required by GAAP under the Predecessor. 14. Represents the recognition of Fresh Start Accounting adjustments to: (i) our AROs attributable to the revalued oil and gas properties and (ii) our retiree obligations based on actuarial measurements, as well as the accelerated recognition of the noncurrent portion of previously deferred gains on sales of assets attributable to the accounting presentation required by GAAP under the Predecessor. 15. Represents the cumulative impact of the Fresh Start Accounting adjustments discussed above. Reorganization Items. As described above in Note 2, our Consolidated Statements of Operations for the period ended September 12, 2016 include “Reorganization items, net,” which reflects gains recognized on the settlement of liabilities subject to compromise and costs and other expenses associated with the bankruptcy proceedings, principally professional fees, and the costs associated with the DIP Facility. These post-petition costs for professional fees, as well as administrative fees charged by the U.S. Trustee, have been reported in “Reorganization items, net” in our Consolidated Statement of Operations as described above. Similar costs that were incurred during the pre-petition periods have been reported in “General and administrative” expenses. The following table summarizes the components included in “Reorganization items, net” in our Consolidated Statements of Operations for the period presented: January 1 Through September 12, 2016 Gains on the settlement of liabilities subject to compromise $ 1,150,248 Fresh start accounting adjustments 28,319 Legal and professional fees and expenses (29,976 ) Settlements attributable to contract amendments (2,550 ) DIP Facility costs and commitment fees (170 ) Write-off of prepaid directors and officers insurance (832 ) Other reorganization items (46 ) $ 1,144,993 Fresh Start Accounting We adopted Fresh Start Accounting on the Effective Date in connection with our emergence from bankruptcy. As referenced below, our reorganization value of $ 334.0 million , immediately prior to emergence was substantially less than our post-petition liabilities and allowed claims. Furthermore and in connection with our reorganization, we experienced a change in control as the outstanding common and preferred shares of the Predecessor were canceled and substantially all of the New Common Stock was issued to the Predecessor’s creditors, primarily former holders of our Senior Notes. Accordingly, the holders of the Predecessor’s common and preferred shares effectively received no shares of the Successor. The adoption of Fresh Start Accounting results in a new reporting entity, the Successor, for financial reporting purposes. The presentation is analogous to that of a new business entity such that the Successor is presented with no beginning retained earnings or deficit on the Effective Date. Reorganization Value Reorganization value represents the fair value of the Successor’s total assets prior to the consideration of liabilities and is intended to approximate the amount a willing buyer would pay for the assets immediately after a restructuring. The reorganization value, which was derived from the Successor’s enterprise value, was allocated to our individual assets based on their estimated fair values. Enterprise value represents the estimated fair value of an entity’s long term debt and shareholders’ equity. The Successor’s enterprise value, as approved by the Bankruptcy Court in support of the Plan, was estimated to be within a range of $ 218 million to $ 382 million with a mid-point value of $ 300 million . Based on the estimates and assumptions utilized in our Fresh Start Accounting process, we estimated the Successor’s enterprise value to be approximately $ 266.2 million after the consideration of cash and cash equivalents on hand at the Effective Date. The following table reconciles the enterprise value, net of cash and cash equivalents, to the estimated fair value of our Successor common stock as of the Effective Date: Enterprise value $ 234,831 Plus: Cash and cash equivalents 31,414 Less: Fair value of debt (75,350 ) Fair value of Successor common stock $ 190,895 Shares outstanding as of September 12, 2016 14,992,018 Per share value $ 12.73 The following table reconciles the enterprise value to the reorganization value of our Successor assets as of the Effective Date: Enterprise value $ 234,831 Plus: Cash and cash equivalents 31,414 Plus: Current liabilities 54,171 Plus: Noncurrent liabilities excluding long-term debt 13,558 Reorganization value $ 333,974 Valuation Process Our valuation analysis was prepared with the assistance of an independent third-party consultant utilizing reserve information prepared by our independent reserve engineers, internal development plans and schedules, other internal financial information and projections and the application of standard valuation techniques including risked net asset value analysis and comparable public company metrics. Our principal assets include the Successor’s oil and gas properties. We determined the fair value of our oil and gas properties based on the discounted cash flows expected to be generated from these assets. Our analyses were based on market conditions and reserves in place as confirmed by our independent petroleum engineers. The proved reserves were segregated into various geographic regions, including sub-regions within the Eagle Ford where a substantial portion of our assets are located, for which separate risk factors were determined based on geological characteristics. Due to the limited drilling plans that we had in place, proved undeveloped locations were risked accordingly. Future cash flows were estimated by using NYMEX forward prices for West Texas Intermediate crude oil and Henry Hub natural gas with inflation adjustments applied to periods beyond a five-year horizon. These prices were adjusted for differentials realized by us for location and product quality. Gathering and transportation costs were estimated based on agreements that we have in place and development and operating costs were based on our most recent experience and adjusted for inflation in future years. The risk-adjusted after-tax cash flows were discounted at a rate of 13.5 %. This rate was determined from a weighted-average cost of capital computation which utilized a blended expected cost of debt and expected returns on equity for similar industry participants. Plugging and abandonment costs were also identified and measured in this process in order to determine the fair value of the Successor’s AROs attributable to our proved developed reserves on the Effective Date. Based on this valuation process, we determined fair values of $ 121.9 million for our proved reserves and $ 2.7 million for the related AROs. With respect to the valuation of our undeveloped acreage, we segregated our current lease holdings in the Eagle Ford into prospect regions in which we have significant developed acreage and those in which we have not yet initiated any significant drilling activity. For those prospects within previously developed regions, we applied a multiple based on recent transactions involving acreage deemed comparable to our acreage for each targeted formation. Based on this valuation process, we determined a fair value of $ 92.5 million for our undeveloped acreage within previously developed regions of the Eagle Ford. For those lease holdings in other areas of the Eagle Ford, we disregarded those prospects for which lease expirations were to occur during 2016 as well as those for which future drilling was considered uneconomical at then current commodity prices. A reduced multiple was then applied to this adjusted undeveloped acreage consistent with recent transactions for acreage deemed comparable to our acreage resulting in a fair value of $ 8.3 million . We attributed no value to our limited undeveloped lease holdings in all areas other than the Eagle Ford. Our remaining equipment and other fixed assets were valued at $ 26.7 million primarily using a cost approach that incorporated depreciation and obsolescence to the extent applicable on an asset-by-asset basis. The most significant of these assets is our water facility in South Texas which is integral to our regional operations. Accordingly, this asset, for which we determined a fair value of $ 23.4 million , is included in our full cost pool for purposes of determining our DD&A attributable to our oil and gas production. Certain assets, particularly personal property including office equipment and vehicles, among others, were valued based on market data for comparable assets to the extent such information was available. The remaining reorganization value is attributable to certain natural gas imbalance receivables, cash and cash equivalents, working capital assets including accounts receivable, prepaid items, current derivative assets and debt issuance costs. Our natural gas imbalance receivables, which are fully attributable to our Mid-Continent operations in the Granite Wash, were valued using NYMEX spot prices for Henry Hub natural gas adjusted for basis differentials for transportation. Our accounts receivable, including amounts receivable from our joint venture partners, were subjected to analysis on an individual basis and reserved to the extent we believe was appropriate. Collectively, these remaining assets, including our current derivative assets which are marked-to-market on a monthly basis, are stated at their fair values on the Effective Date. The reorganization value also includes $ 3.0 million of issuance costs attributable to the Credit Facility under which we initially borrowed $ 75.4 million . This amount has been capitalized in accordance with GAAP as it represents costs attributable to the access to credit over the term of the Credit Facility. Our liabilities on the Effective Date include the aforementioned borrowings under the Credit Facility, working capital liabilities including accounts payable and accrued liabilities, a reserve for certain litigation matters, pension and health care obligations attributable to certain retirees, AROs, and derivative liabilities. As the Credit Facility is current and is a variable-rate financial instrument, it is stated at its fair value. Our working capital liabilities and litigation reserve are ordinary course obligations and their carrying amounts approximate their fair values. We revalued our retiree obligations based on data from our independent actuaries and they have been stated at their fair values. The AROs were valued in connection with the valuation process attributable to our oil and gas reserves as discussed above. Finally, our derivative liabilities have also been stated at their fair value as they are marked-to-market on a monthly basis.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2016
Acquisitions and Divestitures [Abstract]
Acquisitions and Divestitures	Divestitures South Texas Properties In October 2015, we sold certain non-core Eagle Ford properties for $12.5 million net of transaction costs and customary closing adjustments. We recognized a loss of $9.5 million on this transaction. Mid-Continent Properties In October 2015, we sold certain properties in Oklahoma that were outside of our core Granite Wash operating region for approximately $ 0.1 million which represented their approximate carrying values. East Texas Properties In August 2015, we sold our Cotton Valley and Haynesville Shale assets in East Texas and received cash proceeds of approximately $73 million , net of transaction costs and customary closing adjustments. The effective date of the sale was May 1, 2015 and we recognized a gain of approximately $43 million . The carrying value of the net assets disposed in this transaction was $29.5 million , including oil and gas properties and other assets of $33.3 million , net of related AROs of $3.8 million . The net pre-tax operating income (loss), excluding the gain on sale and impairment charges, attributable to the East Texas assets was $1.3 million and $(27.5) million for the years ended December 31, 2015 and 2014, respectively. The net proceeds from this transaction were used to pay down a portion of our outstanding borrowings under the RBL. Oil Gathering System Construction Rights In July 2014, we sold the rights to construct a crude oil gathering and intermediate transportation system in South Texas to Republic Midstream, LLC (“Republic Midstream”) for proceeds of $147.1 million , net of transaction costs. Concurrent with the sale, we entered into long-term agreements with Republic Midstream to provide us gathering and intermediate transportation services for a substantial portion of our South Texas crude oil and condensate production. We realized a gain of $147.1 million , of which $63.0 million was recognized upon the closing of the transaction and the remaining $84.1 million was deferred. In September 2015, the gathering agreement with Republic was amended to reduce the number of wells initially required to be connected to the pipeline system, provide for alternative transportation in areas that would not be served by the pipeline and also reduce the gathering fees. As a result of this amendment, we recognized $ 8.4 million of the deferred gain in September 2015. We recognized $ 1.7 million of the deferred gain in the Predecessor period of 2016 prior to emergence. Prior to the Effective Date, the Bankruptcy Court approved a settlement and we entered into certain amendments to the agreements with Republic (see Note 16). These actions did not impact the amortization of any gain prior to the Effective Date. In connection with our adoption of Fresh Start Accounting, we accelerated the recognition of the remaining deferred gain of $ 74.1 million as a Fresh Start Accounting adjustment included in Reorganization items, net in our Predecessor Statement of Operations for the 2016 period. Mississippi Properties In July 2014, we sold our Selma Chalk assets in Mississippi for proceeds of $67.9 million , net of transaction costs and customary closing adjustments. An impairment charge of $117.9 million was recognized in the second quarter of 2014 with respect to these assets. Natural Gas Gathering and Gas Lift Assets In January 2014, we sold our natural gas gathering and gas lift assets in South Texas to American Midstream Partners, LP (“AMID”) for proceeds of approximately $96 million , net of transaction costs. Concurrent with the sale, we entered into a long-term agreement with AMID to provide us natural gas gathering, compression and gas lift services for a substantial portion of our South Texas natural gas production. We realized a gain of $67.3 million , of which $56.7 million was recognized upon the closing of the transaction and the remainder was deferred and was being amortized over a twenty-five year period. We recognized $0.4 million of the deferred gain in both 2015 and 2014. We recognized $ 0.3 million of the deferred gain in the Predecessor period of 2016 prior to our emergence from bankruptcy. In connection with our adoption of Fresh Start Accounting, we accelerated the recognition of the remaining deferred gain of $ 9.5 million as a Fresh Start Accounting adjustment included in Reorganization items, net in our Predecessor Statement of Operations for the 2016 period. Other Assets During 2014, we also received net proceeds of $2.9 million and recognized net gains of $0.2 million from the sale of various non-core oil and gas properties and tubular inventory and well materials.

Accounts Receivable and Major C

Accounts Receivable and Major Customers	12 Months Ended
	Dec. 31, 2016
Receivables [Abstract]
Accounts Receivable and Major Customers	Accounts Receivable and Major Customers The following table summarizes our accounts receivable by type as of the dates presented: Successor Predecessor December 31, 2016 2015 Customers $ 20,489 $ 23,481 Joint interest partners 7,238 18,381 Other 3,789 7,658 31,516 49,520 Less: Allowance for doubtful accounts (2,421 ) (1,555 ) $ 29,095 $ 47,965 For the year ended December 31, 2016 , three customers accounted for $122.7 million , or approximately 93% of our consolidated product revenues. The revenues generated from these customers during 2016 were $93.5 million , $15.7 million and $13.5 million or 71% , 12% , and 10% of the consolidated total, respectively. As of December 31, 2016 , $16.7 million , or approximately 81% of our consolidated accounts receivable from customers was related to these customers. For the year ended December 31, 2015 , three customers accounted for $168.9 million , or approximately 64% of our consolidated product revenues. The revenues generated from these customers during 2015 were $74.5 million , $63.5 million and $30.9 million , or approximately 28% , 24% and 12% of the consolidated total, respectively. As of December 31, 2015 , $21.1 million , or approximately 90% of our consolidated accounts receivable from customers was related to these customers. No significant uncertainties exist related to the collectability of amounts owed to us by any of these customers.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments We utilize derivative instruments to mitigate our financial exposure to crude oil and natural gas price volatility. Our derivative instruments are not formally designated as hedges in the context of U.S. GAAP. Commodity Derivatives We typically utilize collars, swaps and swaptions, which are placed with financial institutions that we believe are acceptable credit risks, to hedge against the variability in cash flows associated with anticipated sales of our future oil and gas production. While the use of derivative instruments limits the risk of adverse price movements, such use may also limit future revenues from favorable price movements. The counterparty to a collar or swap contract is required to make a payment to us if the settlement price for any settlement period is below the floor or swap price for such contract. We are required to make a payment to the counterparty if the settlement price for any settlement period is above the ceiling or swap price for such contract. Neither party is required to make a payment to the other party if the settlement price for any settlement period is equal to or greater than the floor price and equal to or less than the ceiling price for such collar contract. We determine the fair values of our commodity derivative instruments based on discounted cash flows derived from third-party quoted forward prices for NYMEX Henry Hub gas and West Texas Intermediate crude oil closing prices as of the end of the reporting period. The discounted cash flows utilize discount rates adjusted for the credit risk of our counterparties if the derivative is in an asset position, and our own credit risk if the derivative is in a liability position. We terminated all of our pre-petition derivative contracts from March 2016 through May 2016 for $63.0 million and reduced our amounts outstanding under the RBL by $52.0 million . In connection with these transactions, the counterparties to the derivative contracts, which were also affiliates of lenders under the RBL, transferred the cash proceeds that were used for RBL repayments directly to the administrative agent under the RBL. Accordingly, all of these RBL repayments have been presented as non-cash financing activities in our Consolidated Statement of Cash Flows for the period January 1, 2016 through September 12, 2016. On May 13, 2016, the Bankruptcy Court approved our motion to enter into new commodity derivative contracts. Accordingly, we hedged a substantial portion of our future crude oil production through the end of 2019, as required in the RSA, at a weighted-average price of approximately $49.12 per barrel. We are currently unhedged with respect to natural gas as well as NGL production. The following table sets forth our commodity derivative positions as of December 31, 2016 : Average Volume Per Weighted Average Price Fair Value Instrument Day Floor/Swap Ceiling Asset Liability Crude Oil: (barrels) ($/barrel) First quarter 2017 Swaps 4,408 $ 48.62 — $ — $ 2,454 Second quarter 2017 Swaps 4,408 $ 48.62 — — 3,110 Third quarter 2017 Swaps 4,408 $ 48.62 — — 3,290 Fourth quarter 2017 Swaps 4,408 $ 48.62 — — 3,260 First quarter 2018 Swaps 3,476 $ 49.12 — — 2,267 Second quarter 2018 Swaps 3,476 $ 49.12 — — 2,193 Third quarter 2018 Swaps 3,476 $ 49.12 — — 2,140 Fourth quarter 2018 Swaps 3,476 $ 49.12 — — 2,091 First quarter 2019 Swaps 2,916 $ 49.90 — — 1,471 Second quarter 2019 Swaps 2,916 $ 49.90 — — 1,438 Third quarter 2019 Swaps 2,916 $ 49.90 — — 1,423 Fourth quarter 2019 Swaps 2,916 $ 49.90 — — 1,414 Settlements to be paid in subsequent period 818 Financial Statement Impact of Derivatives The impact of our derivatives activities on income is included in the “Derivatives” caption on our Consolidated Statements of Operations. The following table summarizes the effects of our derivative activities for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Derivative gains (losses) $ (16,622 ) $ (8,333 ) $ 71,247 $ 162,212 The effects of derivative gains and (losses) and cash settlements (except for those cash settlements attributable to the aforementioned termination transactions) are reported as adjustments to reconcile net income (loss) to net cash provided by operating activities. These items are recorded in the “Derivative contracts” section of our Consolidated Statements of Cash Flows under the “Net losses (gains)” and “Cash settlements, net.” The following table summarizes the fair value of our derivative instruments, as well as the locations of these instruments, on our Consolidated Balance Sheets as of the dates presented: Successor Predecessor Fair Values December 31, 2016 December 31, 2015 Derivative Derivative Derivative Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Commodity contracts Derivative assets/liabilities – current $ — $ 12,932 $ 97,956 $ — Commodity contracts Derivative assets/liabilities – noncurrent — 14,437 — — $ — $ 27,369 $ 97,956 $ — As of December 31, 2016 , we reported a commodity derivative liability of $27.4 million . The net and gross amounts for our derivative assets and liabilities are the same for both periods presented above. The contracts associated with this position are with three counterparties, all of which are investment grade financial institutions. This concentration may impact our overall credit risk, either positively or negatively, in that these counterparties may be similarly affected by changes in economic or other conditions. We have neither paid to, nor received from, our counterparties any cash collateral in connection with our derivative positions. Furthermore, our derivative contracts are not subject to margin calls or similar accelerations. No significant uncertainties exist related to the collectability of amounts that may be owed to us by these counterparties.

Property and Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property and Equipment	Property and Equipment The following table summarizes our property and equipment as of the dates presented: Successor Predecessor December 31, 2016 2015 Oil and gas properties: Proved $ 251,083 $ 2,678,415 Unproved 1 4,719 6,881 Total oil and gas properties 255,802 2,685,296 Other property and equipment 3,575 31,365 Total property and equipment 259,377 2,716,661 Accumulated depreciation, depletion and amortization 1 (11,904 ) (2,372,266 ) $ 247,473 $ 344,395 ______________________ 1 See Note 19 for information regarding impairments to our property and equipment while we applied the successful efforts method of accounting. As discussed in Note 3, we adopted the full cost method of accounting for oil and gas properties on the Effective Date. Our unproved property costs of $ 4.7 million as of December 31, 2016 have been excluded from amortization. These costs are anticipated to be included in the full cost pool for amortization in 2017. These unproved property costs, excluding capitalized interest, were incurred during the Predecessor periods and were adjusted to their fair value in connection with the application of Fresh Start Accounting. During the Successor period in 2016, we transferred $ 3.8 million of undeveloped leasehold costs, including capitalized interest, from unproved properties to the full cost pool due primarily to expiring acreage. We capitalized internal costs of $ 0.5 million and interest of less than $ 0.1 million during the Successor period in 2016 in accordance with our accounting policies. Average DD&A per BOE of proved oil and gas properties was $ 11.20 for the Successor period ended December 31, 2016, $ 10.04 for the Predecessor period ended September 12, 2016 and $ 42.22 and $ 37.85 for the years ended December 31, 2015 and 2014, respectively.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The following table reconciles our AROs as of the dates presented, which are included in the “Other liabilities” caption on our Consolidated Balance Sheets: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 December 31, Through December 31, 2016 Through September 12, 2016 2015 Balance at beginning of period $ 2,687 $ 2,621 $ 5,890 Fresh Start Accounting adjustment — (754 ) — Changes in estimates 27 176 172 Liabilities incurred — 469 110 Liabilities settled (311 ) — — Sale of properties — — (3,932 ) Accretion expense 56 175 381 Balance at end of period $ 2,459 $ 2,687 $ 2,621

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt The following table summarizes our long-term debt as of the dates presented: Successor Predecessor December 31, 2016 December 31, 2015 Principal Unamortized Issuance Costs 1 Principal Unamortized Issuance Costs 1 Credit facility 2 $ 25,000 $ — Pre-petition credit facility 3 170,000 Senior notes due 2019 — $ — 300,000 $ 3,295 Senior notes due 2020 — — 775,000 17,322 Totals 25,000 $ — 1,245,000 $ 20,617 Less: Unamortized issuance costs — (20,617 ) Less: Current portion — (1,224,383 ) Long-term debt, net of unamortized issuance costs $ 25,000 $ — ____________________ 1 Issuance costs attributable to the Senior Notes were subject to an accelerated write-off in advance of our bankruptcy filing during the three months ended June 30, 2016. 2 Issuance costs attributable to the Credit Facility, which represent costs attributable to the access to credit over the Credit Facility’s contractual term, have been presented as a component of Other assets (see Note 14). 3 Issuance costs attributable to the RBL were presented as a component of Other assets (see Note 14) prior to the accelerated write-off in advance of our bankruptcy filing during the three months ended June 30, 2016. Credit Facility On the Effective Date, we entered into the Credit Facility. The Credit Facility provides for a $200 million revolving commitment and has an initial borrowing base of $128 million . The Credit Facility also includes a $5.0 million sublimit for the issuance of letters of credit, of which $0.8 million were outstanding as of December 31, 2016 . The Credit Facility is governed by a borrowing base calculation, which is redetermined semi-annually, and the availability under the Credit Facility may not exceed the lesser of the aggregate commitments and the borrowing base. The Credit Facility is scheduled for its initial redetermination in April 2017. After April 1, 2017, the Credit Facility lenders may, at their discretion, initiate a redetermination at any time during the six-month period between scheduled redeterminations. The Credit Facility is available to us to pay expenses associated with our bankruptcy proceedings and for general corporate purposes including working capital. The Credit Facility matures in September 2020. The outstanding borrowings under the Credit Facility bear interest at a rate equal to, at our option, either (a) a customary reference rate plus an applicable margin ranging from 2.00% to 3.00% , determined based on the average availability under the Credit Facility or (b) a customary London interbank offered rate (“LIBOR”) plus an applicable margin ranging from 3.00% to 4.00% , determined based on the average availability under the Credit Facility. Interest on reference rate borrowings is payable quarterly in arrears and is computed on the basis of a year of 365/366 days, and interest on eurocurrency borrowings is payable every one , three or six months, at the election of the borrower, and is computed on the basis of a year of 360 days. As of December 31, 2016 , the actual interest rate on the outstanding borrowings under the Credit Facility was 3.67% . Unused commitment fees are charged at a rate of 0.50% . The Credit Facility is guaranteed by us and all of our subsidiaries (the “Guarantor Subsidiaries”). The guarantees under the Credit Facility are full and unconditional and joint and several. Substantially all of our consolidated assets are held by the Guarantor Subsidiaries. The parent company has no material independent assets or operations. There are no significant restrictions on the ability of the parent company or any of the Guarantor Subsidiaries to obtain funds through dividends, advances or loans. The obligations under the Credit Facility are secured by a first priority lien on substantially all of our assets. The Credit Facility requires us to maintain (1) a minimum interest coverage ratio (adjusted earnings before interest, taxes, depreciation, depletion, amortization and exploration expenses as defined in the Credit Facility (“EBITDAX”) to adjusted interest expense), measured as of the last day of each fiscal quarter, of 3.00 to 1.00, (2) a minimum current ratio (as defined in the Credit Facility, which considers the unused portion of the total commitment as a current asset), measured as of the last day of each fiscal quarter of 1.00 to 1.00, and (3) a maximum leverage ratio (consolidated indebtedness to adjusted EBITDAX), measured as of the last day of each fiscal quarter, initially of 4.00 to 1.00, decreasing on December 31, 2017 to 3.75 to 1.00 and on March 31, 2018 and thereafter to 3.50 to 1.00. The Credit Facility also contains customary affirmative and negative covenants, including as to compliance with laws (including environmental laws, ERISA and anti-corruption laws), maintenance of required insurance, delivery of quarterly and annual financial statements, oil and gas engineering reports and budgets, maintenance and operation of property (including oil and gas properties), restrictions on the incurrence of liens and indebtedness, merger, consolidation or sale of assets, payment of dividends, and transactions with affiliates and other customary covenants. As of December 31, 2016, and through the date upon which the Consolidated Financial Statements were issued, we were in compliance with all of these covenants. Pre-Petition Credit Facility As described in Notes 4 and 5, our principal and interest obligations outstanding under the RBL as well as certain associated fees and expenses were satisfied in cash in full on the Effective Date. These obligations were funded from a combination of cash on hand, proceeds from the Rights Offering and proceeds from initial borrowings under the Credit Facility. 2019 Senior Notes and 2020 Senior Notes The Senior Notes were included in “Liabilities subject to compromise” on the Consolidated Balance Sheet of the Predecessor as of September 12, 2016 (see Note 5) and were included in “Current liabilities” as of December 31, 2015. As described in Notes 4 and 5, the Senior Notes were canceled upon our emergence from bankruptcy.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The following table summarizes our provision for income taxes for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Current income taxes (benefit) Federal $ — $ — $ (660 ) $ 2,045 State — — 1 1,504 — — (659 ) 3,549 Deferred income tax benefit Federal — — (261 ) (130,693 ) State — — (4,451 ) (4,534 ) — — (4,712 ) (135,227 ) $ — $ — $ (5,371 ) $ (131,678 ) The following table reconciles the difference between the income tax benefit computed by applying the statutory tax rate to our loss before income taxes and our reported income tax benefit for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Computed at federal statutory rate $ (1,854 ) 35.0 % $ 369,111 35.0 % $ (555,916 ) 35.0 % $ (189,445 ) 35.0 % State income taxes, net of federal income tax benefit 197 (3.7 )% 1,989 0.2 % (4,438 ) 0.3 % (3,556 ) 0.6 % Change in valuation allowance 1,657 (31.3 )% (384,692 ) (36.5 )% 554,879 (35.0 )% 61,104 (11.3 )% Reorganization adjustments — — % 13,572 1.3 % — — % — — % Other, net — — % 20 — % 104 — % 219 — % $ — — % $ — — % $ (5,371 ) 0.3 % $ (131,678 ) 24.3 % The following table summarizes the principal components of our deferred income tax assets and liabilities as of the dates presented: Successor Predecessor December 31, 2016 2015 Deferred tax assets: Property and equipment $ 183,303 $ 417,535 Pension and postretirement benefits 710 2,276 Share-based compensation 28 7,393 Net operating loss (“NOL”) carryforwards 87,622 222,971 Fair value of derivative instruments 9,579 — Deferred gains — 30,382 Other 7,166 16,637 288,408 697,194 Less: Valuation allowance (288,408 ) (662,909 ) Total net deferred tax assets — 34,285 Deferred tax liabilities: Fair value of derivative instruments — 34,285 Total net deferred tax liabilities — 34,285 Net deferred tax liabilities $ — $ — As of December 31, 2016 , we had federal NOL carryforwards of approximately $120.3 million , which, if not utilized, expire between 2032 and 2036 , and tax-effected state NOL carryforwards of approximately $69.6 million , which expire between 2024 and 2036 . Because of the change in ownership provisions of the Tax Reform Act of 1986, use of a portion of our federal and state NOL may be limited in future periods. As of December 31, 2015 , we carried a valuation allowance against our federal and state deferred tax assets of $662.9 million . We incurred a pre-tax loss in 2015 which, when aggregated with the prior two years, resulted in a pre-tax loss for the three year period ended December 31, 2015. We considered both the positive and negative evidence in determining whether it was more likely than not that some portion or all of our deferred tax assets will be realized. Due to the reorganization and subsequent emergence from bankruptcy, our NOL carryforwards were reduced under Internal Revenue Code Section 108(b), as well as a corresponding decrease in the valuation allowance of $374.5 million which resulted in an ending balance of $288.4 million as of December 31, 2016 . The amount of deferred tax asset considered realizable could, however, be adjusted if estimates of future taxable income during the carryforward period are reduced or increased or if objective negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence such as our projections for growth. We had no liability for unrecognized tax benefits as of December 31, 2016 and 2015 . There were no interest and penalty charges recognized during the years ended December 31, 2016 , 2015 and 2014 . Tax years from 2012 forward remain open for examination by the Internal Revenue Service and various state jurisdictions.

Exit Activities

Exit Activities	12 Months Ended
	Dec. 31, 2016
Restructuring and Related Activities [Abstract]
Firm Transportation Obligation	We have committed to a number of actions, or exit activities, consistent with our current business plans for which we have continuing financial commitments. The most significant of these activities are attributable to an overall reduction in the scope and scale of our organization and require payments to satisfy obligations associated with the underlying commitments. The following summarizes our most significant exit activities. Reductions in Force In connection with efforts to reduce our administrative costs, we took certain actions to reduce our total employee headcount. In 2016, we reduced our total employee headcount by 53 employees. We paid a total of $ 2.1 million , including $ 1.4 million in severance and termination benefits and $ 0.7 million in retention bonuses during the year ended December 31, 2016 . The costs associated with these reduction-in-force and retention actions are included as a component of our “General and administrative” expenses in our Consolidated Statements of Operations. The related obligations are included in “Accounts payable and accrued liabilities” on our Consolidated Balance Sheet. Drilling Rig Termination In connection with the suspension of our 2016 drilling program in the Eagle Ford, we terminated our one remaining drilling rig contract and incurred $ 1.7 million in early termination charges. As this obligation represented a pre-petition liability of the Predecessor, it was included in “Reorganization items, net” in our Consolidated Statements of Operations. Firm Transportation Obligation We had a contractual obligation with a carrying value of $ 10.8 million for certain firm transportation capacity in the Appalachian region that was scheduled to expire in 2022 and, as a result of the sale of our natural gas assets in this region in 2012, we no longer had production available to satisfy this commitment. We originally recognized a liability in 2012 representing this obligation for the estimated discounted future net cash outflows over the remaining term of the contract. The accretion of the obligation through the Petition Date, net of any recoveries from periodic sales of our contractual capacity, was charged as an offset to Other revenue. In connection with our emergence from bankruptcy, we rejected the underlying contract and the obligation was included in “Reorganization items, net” in our Consolidated Statements of Operations.

Additional Balance Sheet Detail

Additional Balance Sheet Detail	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Additional Balance Sheet Detail	Additional Balance Sheet Detail The following table summarizes components of selected balance sheet accounts as of the dates presented: Successor Predecessor December 31, 2016 2015 Other current assets: Tubular inventory and well materials $ 2,125 $ 2,878 Prepaid expenses 903 4,184 Other — 42 $ 3,028 $ 7,104 Other assets: Deferred issuance costs of the credit facilities 1 $ 2,785 $ 1,572 Assets of the SERP 2 — 4,123 Other 2,544 2,655 $ 5,329 $ 8,350 Accounts payable and accrued liabilities: Trade accounts payable $ 9,825 $ 11,603 Drilling costs 2,479 12,074 Royalties and revenue - related 26,116 39,119 Compensation - related 2,557 9,904 Interest 55 15,531 Deferred gains on sales of assets — 2,593 Firm transportation obligation — 2,756 Reserve for bankruptcy claims 3,922 — Other 4,743 9,945 $ 49,697 $ 103,525 Other liabilities: Deferred gains on sales of assets $ — $ 82,943 Firm transportation obligation — 10,705 Asset retirement obligations 2,459 2,621 Defined benefit pension obligations 1,025 1,129 Postretirement health care benefit obligations 488 731 Compensation - related — 1,447 Deferred compensation - SERP obligations and other — 4,434 Other 100 928 $ 4,072 $ 104,938 ____________________ 1 The balance as of December 31, 2016 includes those costs, net of amortization, attributable to the the Credit Facility. Deferred issuance costs attributable to the RBL, which represents the amounts outstanding as of December 31, 2015, were charged in full to interest expense during the three months ended June 30, 2016 in advance of our bankruptcy filing. 2 In connection with our emergence from bankruptcy, the assets of the SERP reverted to us upon the release of claims by our employees attributable to certain deferred compensation arrangements in September 2016. The SERP assets were liquidated by the plan trustee in October 2016 and the cash value was transferred to us (See Notes 4 and 5).

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	15. Fair Value Measurements We apply the authoritative accounting provisions for measuring fair value of both our financial and nonfinancial assets and liabilities. Fair value is an exit price representing the expected amount we would receive upon the sale of an asset or that we would expect to pay to transfer a liability in an orderly transaction with market participants at the measurement date. We use a hierarchy that prioritizes the inputs we use to measure fair value into three distinct categories based upon whether such inputs are observable in active markets or unobservable. We classify assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our methodology for categorizing assets and liabilities that are measured at fair value pursuant to this hierarchy gives the highest priority to unadjusted quoted prices in active markets and the lowest level to unobservable inputs as outlined below. Fair value measurements are classified and disclosed in one of the following three categories: • Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 1 inputs generally provide the most reliable evidence of fair value. • Level 2: Quoted prices in markets that are not active or inputs, which are observable, either directly or indirectly, for substantially the full term of the asset or liability. • Level 3: Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity). Our financial instruments that are subject to fair value disclosure consist of cash and cash equivalents, accounts receivable, accounts payable, derivatives and long-term debt. As of December 31, 2016 , the carrying values of all of these financial instruments approximated fair value. The following table summarizes the fair value of our long-term debt with fixed interest rates, which is estimated based on the published market prices for these debt obligations as of the dates presented: Successor Predecessor December 31, 2016 December 31, 2015 Fair Value Carrying Value Fair Value Carrying Value Senior Notes due 2019 1 $ — $ — $ 40,830 $ 300,000 Senior Notes due 2020 1 — — 125,473 775,000 $ — $ — $ 166,303 $ 1,075,000 ____________________ 1 The Senior Notes were canceled upon our emergence from bankruptcy. Recurring Fair Value Measurements Certain financial assets and liabilities are measured at fair value on a recurring basis on our Consolidated Balance Sheets. The following tables summarize the valuation of those assets and (liabilities) as of the dates presented: Successor December 31, 2016 Fair Value Fair Value Measurement Classification Description Measurement Level 1 Level 2 Level 3 Liabilities: Commodity derivative liabilities – current $ (12,932 ) $ — $ (12,932 ) $ — Commodity derivative liabilities – noncurrent (14,437 ) — (14,437 ) — Predecessor December 31, 2015 Fair Value Fair Value Measurement Classification Description Measurement Level 1 Level 2 Level 3 Assets: Commodity derivative assets – current $ 97,956 $ — $ 97,956 $ — Assets of the SERP 4,123 4,123 — — Liabilities: Deferred compensation – SERP obligation (4,125 ) (4,125 ) — — Changes in economic conditions or model-based valuation techniques may require the transfer of financial instruments from one level of the fair value hierarchy to another level. In such instances, the transfer is deemed to have occurred at the beginning of the quarterly period in which the event or change in circumstances that caused the transfer occurred. There were no transfers during any period in the years ended December 31, 2016 , 2015 and 2014 . We used the following methods and assumptions to estimate fair values for the financial assets and liabilities described below: • Commodity derivatives : We determine the fair values of our commodity derivative instruments based on discounted cash flows derived from third-party quoted forward prices for West Texas Intermediate crude oil and NYMEX Henry Hub gas closing prices as of the end of the reporting periods. We generally use the income approach, using valuation techniques that convert future cash flows to a single discounted value. Each of these is a level 2 input. • Assets of SERP : During the Predecessor periods, we held various publicly traded equity securities in a Rabbi Trust as assets for funding certain deferred compensation obligations. The fair values were based on quoted market prices, which were level 1 inputs. • Deferred compensation - SERP obligations : Certain of our deferred compensation obligations in the Predecessor periods were ultimately to be settled in cash based on the underlying fair value of certain assets, including those held in the Rabbi Trust. The fair values were based on quoted market prices, which were level 1 inputs. Non-Recurring Fair Value Measurements The most significant non-recurring fair value measurements utilized in the preparation of our Consolidated Financial Statements are those attributable to the recognition and measurement of the Successor’s net assets with respect to the application of Fresh Start Accounting. Those measurements are more fully described in Note 5. In addition, we utilize non-recurring fair value measurements with respect to the recognition and measurement of asset impairments, particularly during our Predecessor periods during which time we applied the successful efforts method to our oil and gas properties, as well as the initial determination of AROs associated with the ongoing development of new oil and gas properties. The factors used to determine fair value for purposes of recognizing and measuring asset impairments while we applied the successful efforts method to our oil and gas properties during our Predecessor periods included, but were not limited to, estimates of proved and risk-adjusted probable reserves, future commodity prices, indicative sales prices for properties, the timing of future production and capital expenditures and a discount rate commensurate with the risk reflective of the lives remaining for the respective oil and gas properties. Because these significant fair value inputs were typically not observable, we have categorized the amounts as level 3 inputs. Under the full cost method, which we have applied since the Effective Date, we apply a ceiling test determination utilizing prescribed procedures as described in Note 3. The full cost method is substantially different from the successful efforts method which relies upon fair value measurements. The determination of the fair value of AROs is based upon regional market and facility specific information. The amount of an ARO and the costs capitalized represent the estimated future cost to satisfy the abandonment obligation using current prices that are escalated by an assumed inflation factor after discounting the future cost back to the date that the abandonment obligation was incurred using a rate commensurate with the risk, which approximates our cost of funds. Because these significant fair value inputs are typically not observable, we have categorized the initial estimates as level 3 inputs.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies The following table sets forth our significant commitments as of December 31, 2016 , by category, for the next five years and thereafter: Year Minimum Rentals Gathering and Intermediate Transportation Derivatives Other Commitments 2017 $ 264 $ 9,646 $ 12,932 $ 596 2018 190 10,376 8,691 71 2019 70 11,702 5,746 — 2020 41 12,962 — — 2021 — 12,962 — — Thereafter — 76,674 — — Total $ 565 $ 134,322 $ 27,369 $ 667 Rental Commitments Operating lease rental expense was $0.2 million , $2.4 million , $7.2 million and $8.7 million , for the Successor period from September 13, 2016 through December 31, 2016, the Predecessor period from January 1, 2016 through September 12, 2016, and the Predecessor years ended December 31, 2015 and 2014 , respectively, related primarily to field equipment, office equipment and office leases. Gathering and Intermediate Transportation Commitments We have long-term agreements with Republic Midstream and Republic Midstream Marketing, LLC (“Republic Marketing” and, together with Republic Midstream, collectively, “Republic”) to provide gathering and intermediate pipeline transportation services for a substantial portion of our crude oil and condensate production in the South Texas region as well as volume capacity support for certain downstream interstate pipeline transportation. In August 2016, the Bankruptcy Court approved a settlement with Republic and authorized the assumption of certain amended agreements with Republic (the “Amended Agreements”). We paid Republic $ 0.3 million in connection with the settlement which is included in “Reorganization items, net” in our Consolidated Statements of Operations. Under the terms of the Amended Agreements, Republic is obligated to gather and transport our crude oil and condensate from within a dedicated area in the Eagle Ford (the “Dedication Area”) via a gathering system and intermediate takeaway pipeline connecting to a downstream interstate pipeline operated by a third party. The amended gathering agreement reduced our minimum volume commitment from 15,000 to 8,000 gross barrels of oil per day. The term of the amended gathering agreement runs through 2041, with the term of the minimum volume commitment extended from 10 to 15 years. The gathering portion of these minimum commitments are being recognized as a component of our gathering, processing and transportation expense while the intermediate transportation and pipeline support commitments are recognized as a reduction to the index-based price that we receive for crude oil sold to Republic in accordance with Amended Agreements. Under the amended marketing agreement, we have a 10 -year commitment to sell 8,000 barrels per day of crude oil to Republic, or any third party, utilizing Republic Marketing’s capacity on a certain downstream interstate pipeline. Other Commitments We have entered into certain contractual arrangements for other products and services. We have minimum commitments under information technology licensing, service agreements and employment agreements, among others. Legal We are involved, from time to time, in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, our management believes that these claims will not have a material effect on our financial position, results of operations or cash flows. During 2016, we reduced our reserve for a litigation matter to $0.1 million from $0.9 million due to our dismissal from the subject litigation. Environmental Compliance Extensive federal, state and local laws govern oil and gas operations, regulate the discharge of materials into the environment or otherwise relate to the protection of the environment. Numerous governmental departments issue rules and regulations to implement and enforce such laws that are often difficult and costly to comply with and which carry substantial administrative, civil and even criminal penalties for failure to comply. Some laws, rules and regulations relating to protection of the environment may, in certain circumstances, impose “strict liability” for environmental contamination, rendering a person liable for environmental and natural resource damages and cleanup costs without regard to negligence or fault on the part of such person. Other laws, rules and regulations may restrict the rate of oil and gas production below the rate that would otherwise exist or even prohibit exploration or production activities in sensitive areas. In addition, state laws often require some form of remedial action to prevent pollution from former operations, such as plugging of abandoned wells. As of December 31, 2016 , we have recorded AROs of $2.5 million attributable to these activities. The regulatory burden on the oil and gas industry increases its cost of doing business and consequently affects its profitability. These laws, rules and regulations affect our operations, as well as the oil and gas exploration and production industry in general. We believe that we are in substantial compliance with current applicable environmental laws, rules and regulations and that continued compliance with existing requirements will not have a material impact on our financial condition or results of operations. Nevertheless, changes in existing environmental laws or the adoption of new environmental laws, including any significant limitation on the use of hydraulic fracturing, have the potential to adversely affect our operations.

Shareholders' Equity

Shareholders' Equity	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Shareholders' Equity	Shareholders’ Equity Preferred Stock As discussed in Note 4, all of our Predecessor preferred stock was canceled upon our emergence from bankruptcy on the Effective Date. As of December 31, 2016, there were 5,000,000 Successor shares of preferred stock authorized with none issued or outstanding. Common Stock As discussed in Note 4, all our Predecessor common stock was canceled upon our emergence from bankruptcy on the Effective Date and 14,992,018 shares of New Common Stock were issued with a par value of $ 0.01 per share. We have a total of 45,000,000 shares authorized. We do not anticipate that cash dividends or other distributions will be paid with respect to our common stock in the foreseeable future. In addition, our Credit Facility has restrictive covenants that limit our ability to pay dividends. Accumulated Other Comprehensive Income Accumulated other comprehensive income and losses are entirely attributable to our pension and postretirement health care benefit obligations. The accumulated other comprehensive income, net of tax, was $0.1 million , less than $ 0.1 million , $0.4 million and $0.2 million as of December 31, 2016, September 12, 2016 and December 31, 2015 and 2014, respectively. Treasury Stock Shares of our Predecessor common stock held by the SERP and Predecessor deferred common stock units that had not been converted into Predecessor common stock were previously presented for financial reporting purposes as treasury stock carried at cost. A total of 455,689 Predecessor shares were recorded as treasury stock as of December 31, 2015 . As discussed above, all of the Predecessor common stock held by the SERP and Predecessor deferred common stock units were canceled upon our emergence from bankruptcy on the Effective Date.

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation and Other Benefit Plans We recognize share-based compensation expense related to our share-based compensation plans as a component of “General and administrative” expense in our Consolidated Statements of Operations. We reserved 749,600 shares of New Common Stock for issuance under the Penn Virginia Corporation Management Incentive Plan for future share-based compensation awards. A total of 107,563 shares of time-vested restricted stock units had been granted as of December 31, 2016 . In the Predecessor periods in 2016, 2015 and 2014, we had outstanding equity-classified awards in the form of stock options, restricted stock units and deferred stock units. As discussed in Notes 4 and 5, all remaining equity-classified share-based compensation awards were canceled in connection with our emergence from bankruptcy. With the exception of our Predecessor performance-based restricted stock units (“PBRSUs”), all of our Successor and Predecessor share-based compensation awards are classified as equity instruments because they result in the issuance of common stock on the date of grant, upon exercise or are otherwise payable in common stock upon vesting, as applicable. The compensation cost attributable to these awards has been measured at the grant date and recognized over the applicable vesting period as a non-cash item of expense. Because the Predecessor PBRSUs were payable in cash, they were typically considered liability-classified awards and were included in “Accounts payable and accrued liabilities” (current portion) and “Other liabilities” (noncurrent portion) on the Consolidated Balance Sheets of the Predecessor. Compensation cost associated with the Predecessor PBRSUs was measured at the end of each reporting period and recognized based on the period of time that had elapsed during each of the individual performance periods. The following tables summarize our share-based compensation expense (benefit) recognized for the periods presented: Successor Predecessor Period From Period From September 13, 2016 Through January 1, 2016 Through Year Ended December 31, December 31, 2016 September 12, 2016 2015 2014 Equity-classified awards $ 81 $ 1,511 $ 4,540 $ 3,627 Liability-classified awards — (19 ) (711 ) 4,520 $ 81 $ 1,492 $ 3,829 $ 8,147 Stock Option s The exercise price of all stock options granted under our Predecessor incentive compensation plans was equal to the fair value of our common stock on the date of the grant. Options could be exercised at any time after vesting and prior to ten years following the date of grant. Options vested upon terms established by the compensation and benefits committee of our board of directors (the “Committee”). Generally, options vested over a three -year period, with one-third vesting in each year. The fair value of each option award was estimated on the date of grant using the Black-Scholes-Merton option-pricing formula. Expected volatilities were based on historical changes in the market value of our stock. Separate groups of employees that had similar historical exercise behavior were considered separately to estimate expected lives. Options granted had a maximum term of ten years. We based the risk-free interest rate on the U.S. Treasury rate for the week of the grant having a term equal to the expected life of the option. The ranges for the assumptions used in the Black-Scholes-Merton pricing formula for the Predecessor stock options granted in the periods presented were as follows: Predecessor Year Ended December 31, 2015 2014 Expected volatility 64.6% to 69.4% 56.2% to 63.7% Dividend yield 0.00% to 0.00% 0.00% to 0.00% Expected life 3.5 to 4.6 years 3.5 to 4.6 years Risk-free interest rate 0.87% to 1.54% 0.82% to 1.63% The following table summarizes activity for our most recent fiscal year with respect to stock options: Shares Under Options Weighted- Average Exercise Price Weighted- Average Remaining Contractual Term Aggregate Intrinsic Value Balance as of January 1, 2016 (Predecessor) 3,083,821 $ 16.05 Granted — — Exercised — — Forfeited or expired — — Canceled (3,083,821 ) $ 16.05 Balance as of December 31, 2016 (Successor) — $ — — $ — Exercisable as of end of year (Successor) — $ — — $ — The weighted-average grant-date fair value of options granted during the Predecessor years ended December 31, 2015 and 2014 , respectively, was $3.15 and $7.46 per option. The total intrinsic value of options exercised during the Predecessor year ended December 31, 2014 was $2.3 million . There were no options exercised during 2015 and 2016. The total grant-date fair values of stock options that vested in Predecessor years 2015 and 2014 were $1.3 million and $1.8 million , respectively. In connection with our emergence from bankruptcy, all stock options outstanding as of September 12, 2016 were canceled. Common Stock A portion of the compensation paid to certain non-employee members of our Predecessor board of directors was paid in common stock. Each share of common stock granted as compensation vested immediately upon issuance. In 2015 and 2014 respectively, we granted 195,395 and 15,501 shares of common stock to our non-employee directors at a weighted-average grant date fair value of $1.33 and $11.61 per share. No shares were granted during the Successor or Predecessor periods in 2016. In connection with our emergence from bankruptcy, all shares granted to the non-employee members of our Predecessor board of directors as of September 12, 2016 were canceled. Deferred Common Stock Units A portion of the compensation paid to certain non-employee members of our Predecessor board of directors was paid in deferred common stock units. Each deferred common stock unit represented one share of common stock, vested immediately upon issuance, and was available to the holder upon termination or retirement from our board of directors. Deferred common stock units awarded to directors received all cash or other dividends we paid on shares of our common stock. The following table summarizes activity for our most recent fiscal year with respect to awarded deferred common stock units: Deferred Common Stock Units Weighted-Average Grant Date Fair Value Balance as of January 1, 2016 (Predecessor) 447,498 $ 7.75 Granted — — Converted — — Canceled (447,498 ) $ 7.75 Balance as of December 31, 2016 (Successor) — $ — As of December 31, 2015 , our Predecessor shareholders’ deficit included deferred compensation obligations of $3.4 million and corresponding amounts for treasury stock. In connection with our emergence from bankruptcy, all deferred common stock units outstanding as of September 12, 2016 were canceled. Time-Vested Restricted Stock Units A restricted stock unit entitles the grantee to receive a share of common stock upon the vesting of the restricted stock unit. The grant date fair value of our time-vested restricted stock unit awards are recognized on a straight-line basis over the applicable vesting period. The following table summarizes activity for our most recent fiscal year with respect to awarded restricted stock units: Restricted Stock Units Weighted-Average Grant Date Fair Value Balance as of January 1, 2016 (Predecessor) 468,986 $ 6.97 Granted 107,563 23.15 Vested — — Forfeited — — Canceled (468,986 ) $ 6.97 Balance as of December 31, 2016 (Successor) 107,563 $ 23.15 As of December 31, 2016 , we had $2.4 million of unrecognized compensation cost attributable to Successor unvested restricted stock units. We expect that cost to be recognized over a weighted-average period of 1.5 years. The Predecessor total grant-date fair values of restricted stock units that vested in 2015 and 2014 were $2.2 million and $0.6 million , respectively. No restricted stock units vested during 2016. In connection with our emergence from bankruptcy, all outstanding restricted stock units as of September 12, 2016 were canceled. Predecessor Performance-Based Restricted Stock Units In May 2015, May 2014 and May 2013, we granted PBRSUs to certain executive officers. Vested PBRSUs were payable solely in cash on the third anniversary of the date of grant based upon the achievement of specified market-based performance metrics with respect to each of a one -year, two -year and three -year performance period, in each case commencing on the date of grant. The number of PBRSUs vested ranged from 0% to 200% of the initial grant. The PBRSUs did not have voting rights and did not participate in dividends. The compensation cost of the PBRSUs was based on the fair value derived from a Monte Carlo model. The Monte Carlo model is a binomial valuation model that utilizes certain assumptions, including expected volatility, dividend yield, risk-free interest rates and a measure of total shareholder return. The ranges for the assumptions used in the Monte Carlo model for the Predecessor PBRSUs granted in the periods presented were as follows: Predecessor Year Ended December 31, 2015 2014 Expected volatility 66.5% to 97.7% 52.6% to 72.3% Dividend yield 0.0% to 0.0% 0.0% to 0.0% Risk-free interest rate 0.01% to 1.31% 0.02% to 1.07% The following table summarizes activity for our most recent fiscal year with respect to PBRSUs: Performance-Based Restricted Stock Units Weighted-Average Fair Value Balance as of January 1, 2016 (Predecessor) 941,097 $ 9.19 Granted — — Forfeited — — Canceled (941,097 ) $ 9.19 Balance as of December 31, 2016 (Successor) — $ — In connection with our emergence of bankruptcy, all outstanding PBRSUs as of September 12, 2016 were canceled. Defined Contribution Plan We maintain the Penn Virginia Corporation and Affiliated Companies Employees 401(k) Plan (the “401(k) Plan”), a defined contribution plan, which covers substantially all of our employees. We provide matching contributions on our employees’ elective deferral contributions up to six percent of compensation up to the maximum statutory limits. The 401(k) Plan also provides for discretionary employer contributions. The expense recognized with respect to the 401(k) Plan was $0.1 million , $0.5 million , $0.9 million and $1.7 million for the Successor period from September 13, 2016 through December 31, 2016, the Predecessor period from January 1, 2016 through September 12, 2016, and the Predecessor years ended December 31, 2015 , and 2014 , respectively, and is included as a component of “General and administrative expenses” in our Statements of Operations. Amounts representing accrued obligations to the 401(k) Plan of $0.1 million and $0.2 million are included in the “Accounts payable and accrued expenses” caption on our Consolidated Balance Sheets as of December 31, 2016 and 2015 , respectively. Defined Benefit Pension and Postretirement Health Care Plans We maintain unqualified legacy defined benefit pension and defined benefit postretirement health care plans which cover a limited population of former employees that retired prior to 2000. The combined expense recognized with respect to these plans was less than $0.1 million , less than $0.1 million , $0.1 million and $0.1 million for the Successor period from September 13, 2016 through December 31, 2016, the Predecessor period from January 1, 2016 through September 12, 2016, and the Predecessor years ended December 31, 2015 and 2014 , respectively, and is included as a component of “General and administrative expenses” in our Statements of Operations. The combined unfunded benefit obligations under these plans were $1.7 million and $2.1 million and are included within the “Accounts payable and accrued expenses” (current portion) and “Other liabilities” (noncurrent) captions on our Consolidated Balance Sheets as of December 31, 2016 and 2015 , respectively.

Impairments

Impairments	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Impairments	Impairments The following table summarizes impairment charges recorded during the periods presented: Successor Predecessor Period From Period From September 13, 2016 Through January 1, 2016 Through Year Ended December 31, December 31, 2016 September 12,2016 2015 2014 Oil and gas properties $ — $ — $ 1,396,340 $ 791,809 Other – tubular inventory and well materials — — 1,084 — $ — $ — $ 1,397,424 $ 791,809 The following table summarizes the aggregate fair values of the assets described below, by asset category and the classification of inputs within the fair value measurement hierarchy, at the respective dates of impairment: Fair Value Measurement Level 1 Level 2 Level 3 Year Ended December 31, 2015 Long-lived assets held for use $ 311,886 $ — $ — $ 311,886 Year Ended December 31, 2014 Long-lived assets held for use $ 65,203 $ — $ — $ 65,203 We recorded no impairment charges during 2016. The significant deterioration of commodity prices in 2015, as reflected in the future strip pricing as of December 31, 2015, triggered an impairment of approximately $ 1.4 billion to our proved and unproved Eagle Ford properties, which required us to reduce their carrying value to a fair value of approximately $ 312 million . In 2015, we also recorded an impairment charge of $ 1.1 million attributable to surplus tubular inventory and well materials. In 2014, we recognized oil and gas asset impairments of: (i) $667.8 million in the East Texas, Granite Wash and Marcellus regions due to the decline in commodity prices in the fourth quarter of 2014, (ii) $6.1 million in connection with an uneconomic field drilled in the Mid-Continent region and (iii) $117.9 million to write-down our Selma Chalk assets in Mississippi triggered by the disposition of those properties.

Interest Expense

Interest Expense	12 Months Ended
	Dec. 31, 2016
Banking and Thrift [Abstract]
Interest Expense	Interest Expense The following table summarizes the components of interest expense for the periods presented: Successor Predecessor Period From January 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Interest on borrowings and related fees 1 $ 678 $ 36,012 $ 92,490 $ 91,866 Amortization of debt issuance costs 2 226 22,189 4,749 4,197 Capitalized interest (25 ) (183 ) (6,288 ) (7,232 ) $ 879 $ 58,018 $ 90,951 $ 88,831 ______________________ 1 Absent the bankruptcy proceedings and the corresponding suspension of the accrual of interest on unsecured debt, we would have recorded total contractual interest expense of $ 66.1 million for the period from January 1, 2016 through September 12, 2016, including $ 15.3 million attributable to the 2019 Senior Notes and $ 46.3 million attributable to the 2020 Senior Notes. 2 Includes $ 20.5 million related to the accelerated write-off of unamortized debt issuance costs associated with the RBL and Senior Notes (see Note 11).

Earnings per Share

Earnings per Share	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Earnings per Share	Earnings per Share The following table provides a reconciliation of the components used in the calculation of basic and diluted earnings per share utilizing the two-class method for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Net income (loss) $ (5,296 ) $ 1,054,602 $ (1,582,961 ) $ (409,592 ) Less: Preferred stock dividends 1 — (5,972 ) (22,789 ) (17,148 ) Less: Induced conversion of preferred stock — — — (4,256 ) Net income (loss) attributable to common shareholders – basic and diluted $ (5,296 ) $ 1,048,630 $ (1,605,750 ) $ (430,996 ) Weighted-average shares – basic 14,992 88,013 73,639 68,887 Effect of dilutive securities 2 — 36,074 — — Weighted-average shares – diluted 14,992 124,087 73,639 68,887 ______________________ 1 Preferred stock dividends were excluded from diluted earnings per share for the years ended December 31, 2015 and 2014 , respectively, as the assumed conversion of the outstanding preferred stock would have been anti-dilutive. 2 For the period from September 13, 2016 through December 31, 2016, less than 0.1 million potentially dilutive securities, represented by restricted stock units, had the effect of being anti-dilutive and were excluded from the calculation of diluted earnings per common share. For 2015 and 2014 , respectively, approximately 30.2 million and 26.6 million potentially dilutive securities, including the Series A and Series B Preferred Stock, stock options and restricted stock units had the effect of being anti-dilutive and were excluded from the calculation of diluted earnings per common share.

Basis of Presentation New Accou

Basis of Presentation New Accounting Pronouncements (Policies)	12 Months Ended
	Dec. 31, 2016
Text Block [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	Recently Adopted Accounting Pronouncements In March 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”)2016–09, Improvements to Employee Share-based Payment Accounting (“ASU 2016–09”), which simplifies the accounting for share-based compensation. The areas for simplification that are applicable to publicly-held companies are as follows: (i) Accounting for Income Taxes, (ii) Classification of Excess Tax Benefits on the Statement of Cash Flows, (iii) Forfeitures, (iv) Minimum Statutory Tax Withholding Requirements and (v) Classification of Employee Taxes Paid on the Statement of Cash Flows when an employer withholds shares for tax-withholding purposes. The effective date of ASU 2016–09 is January 1, 2017, with early adoption permitted. We adopted ASU 2016–09 on September 12, 2016 effective upon our emergence from bankruptcy. The adoption of ASU 2016–09 did not have a significant impact on our Consolidated Financial Statements and Notes. Recently Issued Accounting Pronouncements Pending Adoption In June 2016, the FASB issued ASU 2016–13, Measurement of Credit Losses on Financial Instruments (“ASU 2016–13”), which changes the recognition model for the impairment of financial instruments, including accounts receivable, loans and held-to-maturity debt securities, among others. ASU 2016–13 is required to be adopted using the modified retrospective method by January 1, 2020, with early adoption permitted for fiscal periods beginning after December 15, 2018. In contrast to current guidance, which considers current information and events and utilizes a probable threshold, (an “incurred loss” model), ASU 2016–13 mandates an “expected loss” model. The expected loss model: (i) estimates the risk of loss even when risk is remote, (ii) estimates losses over the contractual life, (iii) considers past events, current conditions and reasonable supported forecasts and (iv) has no recognition threshold. ASU 2016–13 will have applicability to our accounts receivable portfolio, particularly those receivables attributable to our joint interest partners. At this time, we do not anticipate that the adoption of ASU 2016–13 will have a significant impact on our Consolidated Financial Statements and related disclosures; however, we are currently in the early stages of evaluating the requirements and the period for which we will adopt the standard. In February 2016, the FASB issued ASU 2016–02, Leases (“ASU 2016–02”), which will require organizations that lease assets to recognize on the balance sheet the assets and liabilities for the rights and obligations created by those leases with terms of more than twelve months. Consistent with current GAAP, the recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee primarily will depend on its classification as a finance or operating lease. ASU 2016–02 also will require disclosures regarding the amount, timing, and uncertainty of cash flows arising from leases. The effective date of ASU 2016–02 is January 1, 2019, with early adoption permitted. We believe that ASU 2016–02 will likely be applicable to our oil and natural gas gathering commitment arrangements as described in Note 16, our existing leases for office facilities and certain office equipment and potentially to certain drilling rig and completion contracts with terms in excess of twelve months to the extent we may have such contracts in the future. Our oil and natural gas gathering arrangements are fairly complex and involve multiple elements that could be construed as leases. Accordingly, we are continuing to evaluate the effect that ASU 2016–02 will have on our Consolidated Financial Statements and related disclosures as well as the period for which we will adopt the standard, however, at this time, we believe that we will likely adopt ASU 2016–02 in 2019. In May 2014, the FASB issued ASU 2014–09, Revenues from Contracts with Customers (“ASU 2014–09”), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014–09 will replace most existing revenue recognition guidance in GAAP when it becomes effective on January 1, 2018. The standard permits the use of either the retrospective or cumulative effect transition method upon adoption. While traditional commodity sales transactions, property conveyances and joint interest arrangements in the oil and gas industry are not expected to be significantly impacted by ASU 2014–09, natural gas imbalances and other non-product revenues, including our ancillary marketing, gathering and transportation and water service revenues could be affected. Accordingly, we are continuing to evaluate the effect that ASU 2014–09 will have on our Consolidated Financial Statements and related disclosures, with a more focused analysis on these other revenue sources, which we do not believe are significant. We are also continuing to monitor developments regarding ASU 2014–09 that are unique to our industry. We fully expect to adopt ASU 2014–09 in 2018.

Summary of Significant Accoun32

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Schedule of Policies [Line Items]
Principles of Consolidation	Principles of Consolidation Our Consolidated Financial Statements include the accounts of Penn Virginia and all of its subsidiaries. Intercompany balances and transactions have been eliminated.
Use of Estimates	Use of Estimates Preparation of our Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities in our Consolidated Financial Statements and the reported amounts of revenues and expenses during the reporting period. Such estimates include certain asset and liability valuations as further described in these Notes. Actual results could differ from those estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents We consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.
Derivative Instruments	Derivative Instruments From time to time, we utilize derivative instruments to mitigate our financial exposure to commodity price and interest rate volatility. The derivative instruments, which are placed with financial institutions that we believe are of acceptable credit risk, take the form of collars, swaps and swaptions. All derivative transactions are subject to our risk management policy, which has been reviewed and approved by our Predecessor board of directors. All derivative instruments are recognized in our Consolidated Financial Statements at fair value. The fair values of our derivative instruments are determined based on discounted cash flows derived from quoted forward prices. Our derivative instruments are not formally designated as hedges. We recognize changes in fair value in earnings currently as a component of the Derivatives caption in our Consolidated Statements of Operations. We have experienced and could continue to experience significant changes in the amount of derivative gains or losses recognized due to fluctuations in the value of these commodity derivative contracts, which fluctuate with changes in commodity prices and interest rates.
Oil and Gas Properties	Oil and Gas Properties We have adopted the full cost method of accounting for our oil and gas properties effective with our adoption of Fresh Start Accounting. Under this method, all productive and nonproductive costs incurred in the exploration, development and acquisition of oil and gas reserves are capitalized. Such costs may be incurred both prior to and after the acquisition of a property and include lease acquisitions, geological and geophysical, or seismic, drilling, completion and equipment costs. Internal costs incurred that are directly attributable to exploration, development and acquisition activities undertaken by us for our own account, and which are not attributable to production, general corporate overhead or similar activities are also capitalized. Future development costs are estimated on a property-by-property basis based on current economic conditions and are amortized as a component of depreciation, depletion and amortization (“DD&A”). Unproved properties not being amortized include unevaluated leasehold costs and associated capitalized interest. These costs are reviewed quarterly to determine whether or not and to what extent proved reserves have been assigned to a property or if an impairment has occurred due to lease expirations, general economic conditions and other factors, in which case the related costs along with associated capitalized interest are reclassified to the proved oil and gas properties subject to DD&A. At the end of each quarterly reporting period, the unamortized cost of our oil and gas properties, net of deferred income taxes, is limited to the sum of the estimated discounted future net revenues from proved properties adjusted for costs excluded from amortization and related income taxes (a “Ceiling Test”). The estimated discounted future net revenues are determined using the prior 12-month’s average price based on closing prices on the first day of each month, adjusted for differentials, discounted at 10%. The calculation of the Ceiling Test and provision for DD&A are based on estimates of proved reserves. There are significant uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production, timing and plan of development. For the periods prior to the Effective Date, we applied the successful efforts method of accounting for our oil and gas properties. Under this method, costs of acquiring properties, costs of drilling successful exploration wells and development costs were capitalized. Seismic costs, delay rentals and costs to drill exploratory wells that did not find proved reserves were expensed as oil and gas exploration. We carried the costs of exploratory wells as assets if the wells had found a sufficient quantity of reserves to justify its completion as a producing well and as long as we were making sufficient progress assessing the reserves and the economic and operating viability of the project. For certain projects, it may have taken us more than one year to evaluate the future potential of the exploratory well and make determinations of their economic viability. Our ability to move forward on projects was dependent on gaining access to transportation or processing facilities or obtaining permits and government or partner approval, the timing of which was beyond our control. In such cases, exploratory well costs remained suspended as long as we were actively pursuing access to the necessary facilities or receiving such permits and approvals and believed that they would be obtained. We assessed the status of suspended exploratory well costs on a quarterly basis. Depreciation, Depletion and Amortization DD&A of our oil and gas properties is computed using the units-of-production method. We apply this method by multiplying the unamortized cost of our proved oil and gas properties, net of estimated salvage plus future development costs, by a rate determined by dividing the physical units of oil and gas produced during the period by the total estimated units of proved oil and gas reserves at the beginning of the period. DD&A of our proved properties while we applied the successful efforts method during the Predecessor periods was computed using the units-of-production method. Historically, we adjusted our depletion rate throughout the year as new data became available and in the fourth quarter based on our year-end reserve report through December 31, 2015.
Other Property and Equipment	Other Property and Equipment Other property and equipment consists primarily of gathering systems and related support equipment. Property and equipment are carried at cost and include expenditures for additions and improvements, such as roads and land improvements, which increase the productive lives of existing assets. Maintenance and repair costs are charged to expense as incurred. Renewals and betterments, which extend the useful life of the properties, are capitalized. We compute depreciation and amortization of property and equipment using the straight-line balance method over the estimated useful life of each asset as follows: Gathering systems – fifteen to twenty years and Other property and equipment – three to twenty years.
Impairment of Long-Lived and Other Assets	Impairment of Long-Lived Assets While we applied the successful efforts method of accounting for our oil and gas properties during the Predecessor periods, we reviewed our assets for impairment when events or circumstances indicated a possible decline in the recoverability of the carrying value of the properties. If the carrying value of the asset was determined to be impaired, we reduced the asset to its fair value. Fair value may have been estimated using comparable market data, a discounted cash flow method, or a combination of the two. In the discounted cash flow method, estimated future cash flows were based on management’s expectations for the future and included estimates of future production, commodity prices based on published forward commodity price curves as of the date of the estimate, operating and development costs, intent to develop properties and a risk-adjusted discount rate. We reviewed oil and gas properties for impairment periodically when events and circumstances indicated a decline in the recoverability of the carrying value of such properties, such as a downward revision of the reserve estimates or lower commodity prices. We estimated the future cash flows expected in connection with the properties and compared such future cash flows to the carrying amounts of the properties to determine if the carrying amounts were recoverable. Performing the impairment evaluations required use of judgments and estimates since the results were dependent on future events. Such events included estimates of proved and unproved reserves, future commodity prices, the timing of future production, capital expenditures and intent to develop properties, among others. The costs of unproved leaseholds, including associated interest costs for the period activities were in progress to bring projects to their intended use, were capitalized pending the results of exploration efforts. Unproved properties whose acquisition costs were insignificant to total oil and gas properties were amortized in the aggregate over the lesser of five years or the average remaining lease term and the amortization was charged to exploration expense. We assessed unproved properties whose acquisition costs were relatively significant, if any, for impairment on a stand-alone basis. As exploration work progressed and the reserves on properties were proved, capitalized costs of these properties became subject to depreciation and depletion. If the exploration work was unsuccessful, the capitalized costs of the properties related to the unsuccessful work was charged to exploration expense. The timing of any write-downs of any significant unproved properties depended upon the nature, timing and extent of future exploration and development activities and their results.
Asset Retirement Obligations	Asset Retirement Obligations We recognize the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. Associated asset retirement costs are capitalized as part of the carrying cost of the asset. Our AROs relate to the plugging and abandonment of oil and gas wells and the associated asset is recorded as a component of oil and gas properties. After recording these amounts, the ARO is accreted to its future estimated value, and the additional capitalized costs are depreciated over the productive life of the assets. Both the accretion of the ARO and the depreciation of the related long-lived assets are included in the DD&A expense caption in our Consolidated Statements of Operations.
Income Taxes	Income Taxes We recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in the Company’s financial statements or tax returns. Using this method, deferred tax assets and liabilities are determined based on the difference between the financial statement carrying amounts and tax bases of assets and liabilities using enacted tax rates. In assessing our deferred tax assets, we consider whether a valuation allowance should be recorded for some or all of the deferred tax assets which may not be realized. The ultimate realization of deferred tax assets is assessed at each reporting period and is dependent upon the generation of future taxable income and our ability to utilize tax credits and operating loss carryforwards during the periods in which the temporary differences become deductible. We also consider the scheduled reversal of deferred tax liabilities and available tax planning strategies. We recognize interest attributable to income taxes, to the extent they arise, as a component of interest expense and penalties as a component of income tax expense. We are subject to ongoing tax examinations in numerous domestic jurisdictions. Accordingly, we may record incremental tax expense based upon the more-likely-than-not outcomes of uncertain tax positions. In addition, when applicable, we adjust the previously recorded tax expense to reflect examination results when the position is effectively settled. Our ongoing assessments of the more-likely-than-not outcomes of the examinations and related tax positions require judgment and can increase or decrease our effective tax rate, as well as impact our operating results. The specific timing of when the resolution of each tax position will be reached is uncertain.
Revenue Recognition	Revenue Recognition We record revenues associated with sales of crude oil, NGLs and natural gas when title passes to the customer. We recognize natural gas sales revenues from properties in which we have an interest with other producers on the basis of our net revenue interest (“entitlement” method of accounting). Natural gas imbalances occur when we sell more or less than our entitled ownership percentage of natural gas production. We treat any amount received in excess of our share as a liability. If we take less than we are entitled to take, we record the under-delivery as a receivable. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations and distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 60 days following the month of production. Therefore, we make accruals for revenues and accounts receivable based on estimates of our share of production, particularly from properties that are operated by our partners. We record any differences, which historically have not been significant, between the actual amounts ultimately received and the original estimates in the period they become finalized.
Share-Based Compensation	Share-Based Compensation Our stock compensation plans permit the grant of incentive and nonqualified stock options, common stock, deferred common stock units, restricted stock and restricted stock units to our employees and directors. We measure the cost of employee services received in exchange for an award of equity-classified instruments based on the grant-date fair value of the award. Compensation cost associated with the liability-classified awards is measured at the end of each reporting period and recognized based on the period of time that has elapsed during the applicable performance period.
Fair Value of Financial Instruments, Policy [Policy Text Block]	We apply the authoritative accounting provisions for measuring fair value of both our financial and nonfinancial assets and liabilities. Fair value is an exit price representing the expected amount we would receive upon the sale of an asset or that we would expect to pay to transfer a liability in an orderly transaction with market participants at the measurement date. We use a hierarchy that prioritizes the inputs we use to measure fair value into three distinct categories based upon whether such inputs are observable in active markets or unobservable. We classify assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our methodology for categorizing assets and liabilities that are measured at fair value pursuant to this hierarchy gives the highest priority to unadjusted quoted prices in active markets and the lowest level to unobservable inputs as outlined below. Fair value measurements are classified and disclosed in one of the following three categories: • Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 1 inputs generally provide the most reliable evidence of fair value. • Level 2: Quoted prices in markets that are not active or inputs, which are observable, either directly or indirectly, for substantially the full term of the asset or liability. • Level 3: Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).
Fair Value, Measurements, Recurring
Schedule of Policies [Line Items]
Fair Value of Financial Instruments, Policy [Policy Text Block]	We used the following methods and assumptions to estimate fair values for the financial assets and liabilities described below: • Commodity derivatives : We determine the fair values of our commodity derivative instruments based on discounted cash flows derived from third-party quoted forward prices for West Texas Intermediate crude oil and NYMEX Henry Hub gas closing prices as of the end of the reporting periods. We generally use the income approach, using valuation techniques that convert future cash flows to a single discounted value. Each of these is a level 2 input. • Assets of SERP : During the Predecessor periods, we held various publicly traded equity securities in a Rabbi Trust as assets for funding certain deferred compensation obligations. The fair values were based on quoted market prices, which were level 1 inputs. • Deferred compensation - SERP obligations : Certain of our deferred compensation obligations in the Predecessor periods were ultimately to be settled in cash based on the underlying fair value of certain assets, including those held in the Rabbi Trust. The fair values were based on quoted market prices, which were level 1 inputs.

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value of Financial Instruments, Policy (Policies)	12 Months Ended
	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Financial Instruments, Policy [Policy Text Block]	We apply the authoritative accounting provisions for measuring fair value of both our financial and nonfinancial assets and liabilities. Fair value is an exit price representing the expected amount we would receive upon the sale of an asset or that we would expect to pay to transfer a liability in an orderly transaction with market participants at the measurement date. We use a hierarchy that prioritizes the inputs we use to measure fair value into three distinct categories based upon whether such inputs are observable in active markets or unobservable. We classify assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our methodology for categorizing assets and liabilities that are measured at fair value pursuant to this hierarchy gives the highest priority to unadjusted quoted prices in active markets and the lowest level to unobservable inputs as outlined below. Fair value measurements are classified and disclosed in one of the following three categories: • Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 1 inputs generally provide the most reliable evidence of fair value. • Level 2: Quoted prices in markets that are not active or inputs, which are observable, either directly or indirectly, for substantially the full term of the asset or liability. • Level 3: Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Financial Instruments, Policy [Policy Text Block]	We used the following methods and assumptions to estimate fair values for the financial assets and liabilities described below: • Commodity derivatives : We determine the fair values of our commodity derivative instruments based on discounted cash flows derived from third-party quoted forward prices for West Texas Intermediate crude oil and NYMEX Henry Hub gas closing prices as of the end of the reporting periods. We generally use the income approach, using valuation techniques that convert future cash flows to a single discounted value. Each of these is a level 2 input. • Assets of SERP : During the Predecessor periods, we held various publicly traded equity securities in a Rabbi Trust as assets for funding certain deferred compensation obligations. The fair values were based on quoted market prices, which were level 1 inputs. • Deferred compensation - SERP obligations : Certain of our deferred compensation obligations in the Predecessor periods were ultimately to be settled in cash based on the underlying fair value of certain assets, including those held in the Rabbi Trust. The fair values were based on quoted market prices, which were level 1 inputs.

Fresh Start Accounting Fresh St

Fresh Start Accounting Fresh Start Accounting (Tables)	12 Months Ended
	Dec. 31, 2016
Fresh-Start Balance Sheet [Abstract]
Schedule of Cumulative impact of Reorganization Adjustments [Table Text Block]	Represents the cumulative impact of the reorganization adjustments described above: Gain on settlement of of liabilities subject to compromise $ 1,150,248 Fair value of equity allocated to: Unsecured creditors on the Effective Date 174,477 Unsecured creditors pending resolution on the Effective Date 10,396 Backstop Parties in the form of a Commitment Premium 6,022 190,895 Cancellation of Predecessor shareholders’ deficit 882,992 Net impact to Predecessor accumulated deficit $ 2,224,135
Schedule of Fresh-Start Adjustments [Table Text Block]	The following table reflects the reorganization and application of Fresh Start Accounting adjustments on our Consolidated Balance Sheet as of September 12, 2016: Reorganization Fresh Start Predecessor Adjustments Adjustments Successor Assets Current assets Cash and cash equivalents $ 48,718 $ (17,304 ) (1 ) $ — $ 31,414 Accounts receivable, net of allowance for doubtful accounts 35,606 4,292 (2 ) — 39,898 Derivative assets 397 — — 397 Other current assets 3,966 (832 ) (3 ) — 3,134 Total current assets 88,687 (13,844 ) — 74,843 Property and equipment, net 309,261 — (55,751 ) (12 ) 253,510 Other assets 6,902 (1,281 ) (4 ) — 5,621 Total assets $ 404,850 $ (15,125 ) $ (55,751 ) $ 333,974 Liabilities and Shareholders’ Deficit Current liabilities Accounts payable and accrued liabilities $ 77,151 $ (21,166 ) (5 ) $ (3,455 ) (13 ) $ 52,530 Derivative liabilities 1,641 — — 1,641 Current maturities of long-term debt 113,653 (113,653 ) (6 ) — — Total current liabilities 192,445 (134,819 ) (3,455 ) 54,171 Other liabilities 84,953 100 (5 ) (80,615 ) (14 ) 4,438 Derivative liabilities 9,120 — — 9,120 Long-term debt — 75,350 (7 ) — 75,350 Liabilities subject to compromise 1,154,163 (1,154,163 ) (8 ) — — Shareholders’ equity (deficit) Preferred stock (Predecessor) 1,880 (1,880 ) (9 ) — — Common stock (Predecessor) 697 (697 ) (9 ) — — Paid-in capital (Predecessor) 1,213,797 (1,213,797 ) (9 ) — — Deferred compensation obligation (Predecessor) 3,440 (3,440 ) (9 ) — — Accumulated other comprehensive income (Predecessor) 383 (383 ) (9 ) — — Treasury stock (Predecessor) (3,574 ) 3,574 (9 ) — — Common stock (Successor) — 150 (10 ) — 150 Paid-in capital (Successor) — 190,745 (10 ) — 190,745 Accumulated deficit (2,252,454 ) 2,224,135 (11 ) 28,319 (15 ) — Total shareholders’ equity (deficit) (1,035,831 ) 1,198,407 28,319 190,895 Total liabilities and shareholders’ equity (deficit) $ 404,850 $ (15,125 ) $ (55,751 ) $ 333,974
Reconcile Enterprise Value to FV of Successor CS [Table Text Block]	The following table reconciles the enterprise value, net of cash and cash equivalents, to the estimated fair value of our Successor common stock as of the Effective Date: Enterprise value $ 234,831 Plus: Cash and cash equivalents 31,414 Less: Fair value of debt (75,350 ) Fair value of Successor common stock $ 190,895 Shares outstanding as of September 12, 2016 14,992,018 Per share value $ 12.73
Reconciliation of Enterprise Value to Reorganization Value [Table Text Block]	The following table reconciles the enterprise value to the reorganization value of our Successor assets as of the Effective Date: Enterprise value $ 234,831 Plus: Cash and cash equivalents 31,414 Plus: Current liabilities 54,171 Plus: Noncurrent liabilities excluding long-term debt 13,558 Reorganization value $ 333,974
Schedule of Net Cash Payments [Table Text Block]	Represents the net cash payments that occurred on the Effective Date: Sources: Proceeds from the Credit Facility $ 75,350 Proceeds from the Rights Offering, net of issuance costs 49,943 Total sources $ 125,293 Uses: Repayment of RBL $ 113,653 Accrued interest payable on RBL 1,374 DIP Facility fees 12 Debt issue costs of the Credit Facility 3,011 Funding of professional fee escrow account 14,575 RBL lender professional fees and expenses 455 Ad Hoc Committee and indenture trustee professional fees and expenses 6,782 Payment of certain allowed claims and settlements 2,735 Total uses 142,597 $ (17,304 )
Schedule of Liabilities Subject to Compromise Settled [Table Text Block]	Liabilities subject to compromise were settled as follows in accordance with the Plan: Liabilities subject to compromise prior to the Effective Date: Senior Notes $ 1,075,000 Interest on Senior Notes 47,213 Firm transportation obligation 11,077 Compensation – related 9,733 Deferred compensation 4,676 Trade accounts payable 1,487 Litigation claims 1,092 Other accrued liabilities 3,885 $ 1,154,163 Amounts settled in cash, reinstated or otherwise reserved at emergence (3,915 ) Gain on settlement of liabilities subject to compromise $ 1,150,248
Schedule of Reorganization Items [Table Text Block]	The following table summarizes the components included in “Reorganization items, net” in our Consolidated Statements of Operations for the period presented: January 1 Through September 12, 2016 Gains on the settlement of liabilities subject to compromise $ 1,150,248 Fresh start accounting adjustments 28,319 Legal and professional fees and expenses (29,976 ) Settlements attributable to contract amendments (2,550 ) DIP Facility costs and commitment fees (170 ) Write-off of prepaid directors and officers insurance (832 ) Other reorganization items (46 ) $ 1,144,993

Accounts Receivable and Major35

Accounts Receivable and Major Customers (Tables)	12 Months Ended
	Dec. 31, 2016
Receivables [Abstract]
Summary of Accounts Receivable	The following table summarizes our accounts receivable by type as of the dates presented: Successor Predecessor December 31, 2016 2015 Customers $ 20,489 $ 23,481 Joint interest partners 7,238 18,381 Other 3,789 7,658 31,516 49,520 Less: Allowance for doubtful accounts (2,421 ) (1,555 ) $ 29,095 $ 47,965

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Positions	The following table sets forth our commodity derivative positions as of December 31, 2016 : Average Volume Per Weighted Average Price Fair Value Instrument Day Floor/Swap Ceiling Asset Liability Crude Oil: (barrels) ($/barrel) First quarter 2017 Swaps 4,408 $ 48.62 — $ — $ 2,454 Second quarter 2017 Swaps 4,408 $ 48.62 — — 3,110 Third quarter 2017 Swaps 4,408 $ 48.62 — — 3,290 Fourth quarter 2017 Swaps 4,408 $ 48.62 — — 3,260 First quarter 2018 Swaps 3,476 $ 49.12 — — 2,267 Second quarter 2018 Swaps 3,476 $ 49.12 — — 2,193 Third quarter 2018 Swaps 3,476 $ 49.12 — — 2,140 Fourth quarter 2018 Swaps 3,476 $ 49.12 — — 2,091 First quarter 2019 Swaps 2,916 $ 49.90 — — 1,471 Second quarter 2019 Swaps 2,916 $ 49.90 — — 1,438 Third quarter 2019 Swaps 2,916 $ 49.90 — — 1,423 Fourth quarter 2019 Swaps 2,916 $ 49.90 — — 1,414 Settlements to be paid in subsequent period 818
Impact of Derivative Activities on Condensed Consolidated Statements of Income	The impact of our derivatives activities on income is included in the “Derivatives” caption on our Consolidated Statements of Operations. The following table summarizes the effects of our derivative activities for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Derivative gains (losses) $ (16,622 ) $ (8,333 ) $ 71,247 $ 162,212
Fair Value of Derivative Instruments on Condensed Consolidated Balance Sheets	The following table summarizes the fair value of our derivative instruments, as well as the locations of these instruments, on our Consolidated Balance Sheets as of the dates presented: Successor Predecessor Fair Values December 31, 2016 December 31, 2015 Derivative Derivative Derivative Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Commodity contracts Derivative assets/liabilities – current $ — $ 12,932 $ 97,956 $ — Commodity contracts Derivative assets/liabilities – noncurrent — 14,437 — — $ — $ 27,369 $ 97,956 $ —

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Summary of Property and Equipment	The following table summarizes our property and equipment as of the dates presented: Successor Predecessor December 31, 2016 2015 Oil and gas properties: Proved $ 251,083 $ 2,678,415 Unproved 1 4,719 6,881 Total oil and gas properties 255,802 2,685,296 Other property and equipment 3,575 31,365 Total property and equipment 259,377 2,716,661 Accumulated depreciation, depletion and amortization 1 (11,904 ) (2,372,266 ) $ 247,473 $ 344,395

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Reconciliation of Asset Retirement Obligations which are Included in Other Liabilities	The following table reconciles our AROs as of the dates presented, which are included in the “Other liabilities” caption on our Consolidated Balance Sheets: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 December 31, Through December 31, 2016 Through September 12, 2016 2015 Balance at beginning of period $ 2,687 $ 2,621 $ 5,890 Fresh Start Accounting adjustment — (754 ) — Changes in estimates 27 176 172 Liabilities incurred — 469 110 Liabilities settled (311 ) — — Sale of properties — — (3,932 ) Accretion expense 56 175 381 Balance at end of period $ 2,459 $ 2,687 $ 2,621

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Interest Expense	Interest Expense The following table summarizes the components of interest expense for the periods presented: Successor Predecessor Period From January 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Interest on borrowings and related fees 1 $ 678 $ 36,012 $ 92,490 $ 91,866 Amortization of debt issuance costs 2 226 22,189 4,749 4,197 Capitalized interest (25 ) (183 ) (6,288 ) (7,232 ) $ 879 $ 58,018 $ 90,951 $ 88,831 ______________________ 1 Absent the bankruptcy proceedings and the corresponding suspension of the accrual of interest on unsecured debt, we would have recorded total contractual interest expense of $ 66.1 million for the period from January 1, 2016 through September 12, 2016, including $ 15.3 million attributable to the 2019 Senior Notes and $ 46.3 million attributable to the 2020 Senior Notes. 2 Includes $ 20.5 million related to the accelerated write-off of unamortized debt issuance costs associated with the RBL and Senior Notes (see Note 11).
Carrying Amount of Components of Long-term Debt	The following table summarizes our long-term debt as of the dates presented: Successor Predecessor December 31, 2016 December 31, 2015 Principal Unamortized Issuance Costs 1 Principal Unamortized Issuance Costs 1 Credit facility 2 $ 25,000 $ — Pre-petition credit facility 3 170,000 Senior notes due 2019 — $ — 300,000 $ 3,295 Senior notes due 2020 — — 775,000 17,322 Totals 25,000 $ — 1,245,000 $ 20,617 Less: Unamortized issuance costs — (20,617 ) Less: Current portion — (1,224,383 ) Long-term debt, net of unamortized issuance costs $ 25,000 $ —
Components of Interest Expense	The following table summarizes the components of interest expense for the periods presented: Successor Predecessor Period From January 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Interest on borrowings and related fees 1 $ 678 $ 36,012 $ 92,490 $ 91,866 Amortization of debt issuance costs 2 226 22,189 4,749 4,197 Capitalized interest (25 ) (183 ) (6,288 ) (7,232 ) $ 879 $ 58,018 $ 90,951 $ 88,831 ______________________ 1 Absent the bankruptcy proceedings and the corresponding suspension of the accrual of interest on unsecured debt, we would have recorded total contractual interest expense of $ 66.1 million for the period from January 1, 2016 through September 12, 2016, including $ 15.3 million attributable to the 2019 Senior Notes and $ 46.3 million attributable to the 2020 Senior Notes. 2 Includes $ 20.5 million related to the accelerated write-off of unamortized debt issuance costs associated with the RBL and Senior Notes (see Note 11).

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Summary of Provision for Income Taxes from Continuing Operations	The following table summarizes our provision for income taxes for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Current income taxes (benefit) Federal $ — $ — $ (660 ) $ 2,045 State — — 1 1,504 — — (659 ) 3,549 Deferred income tax benefit Federal — — (261 ) (130,693 ) State — — (4,451 ) (4,534 ) — — (4,712 ) (135,227 ) $ — $ — $ (5,371 ) $ (131,678 )
Income Taxes Reconciliation	The following table reconciles the difference between the income tax benefit computed by applying the statutory tax rate to our loss before income taxes and our reported income tax benefit for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Computed at federal statutory rate $ (1,854 ) 35.0 % $ 369,111 35.0 % $ (555,916 ) 35.0 % $ (189,445 ) 35.0 % State income taxes, net of federal income tax benefit 197 (3.7 )% 1,989 0.2 % (4,438 ) 0.3 % (3,556 ) 0.6 % Change in valuation allowance 1,657 (31.3 )% (384,692 ) (36.5 )% 554,879 (35.0 )% 61,104 (11.3 )% Reorganization adjustments — — % 13,572 1.3 % — — % — — % Other, net — — % 20 — % 104 — % 219 — % $ — — % $ — — % $ (5,371 ) 0.3 % $ (131,678 ) 24.3 %
Summary of Principal Components of Net Deferred Income Tax Liability	The following table summarizes the principal components of our deferred income tax assets and liabilities as of the dates presented: Successor Predecessor December 31, 2016 2015 Deferred tax assets: Property and equipment $ 183,303 $ 417,535 Pension and postretirement benefits 710 2,276 Share-based compensation 28 7,393 Net operating loss (“NOL”) carryforwards 87,622 222,971 Fair value of derivative instruments 9,579 — Deferred gains — 30,382 Other 7,166 16,637 288,408 697,194 Less: Valuation allowance (288,408 ) (662,909 ) Total net deferred tax assets — 34,285 Deferred tax liabilities: Fair value of derivative instruments — 34,285 Total net deferred tax liabilities — 34,285 Net deferred tax liabilities $ — $ —

Additional Balance Sheet Deta41

Additional Balance Sheet Detail (Tables)	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Components of Selected Balance Sheet Accounts	The following table summarizes components of selected balance sheet accounts as of the dates presented: Successor Predecessor December 31, 2016 2015 Other current assets: Tubular inventory and well materials $ 2,125 $ 2,878 Prepaid expenses 903 4,184 Other — 42 $ 3,028 $ 7,104 Other assets: Deferred issuance costs of the credit facilities 1 $ 2,785 $ 1,572 Assets of the SERP 2 — 4,123 Other 2,544 2,655 $ 5,329 $ 8,350 Accounts payable and accrued liabilities: Trade accounts payable $ 9,825 $ 11,603 Drilling costs 2,479 12,074 Royalties and revenue - related 26,116 39,119 Compensation - related 2,557 9,904 Interest 55 15,531 Deferred gains on sales of assets — 2,593 Firm transportation obligation — 2,756 Reserve for bankruptcy claims 3,922 — Other 4,743 9,945 $ 49,697 $ 103,525 Other liabilities: Deferred gains on sales of assets $ — $ 82,943 Firm transportation obligation — 10,705 Asset retirement obligations 2,459 2,621 Defined benefit pension obligations 1,025 1,129 Postretirement health care benefit obligations 488 731 Compensation - related — 1,447 Deferred compensation - SERP obligations and other — 4,434 Other 100 928 $ 4,072 $ 104,938 ____________________ 1 The balance as of December 31, 2016 includes those costs, net of amortization, attributable to the the Credit Facility. Deferred issuance costs attributable to the RBL, which represents the amounts outstanding as of December 31, 2015, were charged in full to interest expense during the three months ended June 30, 2016 in advance of our bankruptcy filing. 2 In connection with our emergence from bankruptcy, the assets of the SERP reverted to us upon the release of claims by our employees attributable to certain deferred compensation arrangements in September 2016. The SERP assets were liquidated by the plan trustee in October 2016 and the cash value was transferred to us (See Notes 4 and 5).

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Summary of Long-Term Debt with Fixed Interest Rates	The following table summarizes the fair value of our long-term debt with fixed interest rates, which is estimated based on the published market prices for these debt obligations as of the dates presented: Successor Predecessor December 31, 2016 December 31, 2015 Fair Value Carrying Value Fair Value Carrying Value Senior Notes due 2019 1 $ — $ — $ 40,830 $ 300,000 Senior Notes due 2020 1 — — 125,473 775,000 $ — $ — $ 166,303 $ 1,075,000
Assets and Liabilities Measured at Fair Value on Recurring Basis	The following tables summarize the valuation of those assets and (liabilities) as of the dates presented: Successor December 31, 2016 Fair Value Fair Value Measurement Classification Description Measurement Level 1 Level 2 Level 3 Liabilities: Commodity derivative liabilities – current $ (12,932 ) $ — $ (12,932 ) $ — Commodity derivative liabilities – noncurrent (14,437 ) — (14,437 ) — Predecessor December 31, 2015 Fair Value Fair Value Measurement Classification Description Measurement Level 1 Level 2 Level 3 Assets: Commodity derivative assets – current $ 97,956 $ — $ 97,956 $ — Assets of the SERP 4,123 4,123 — — Liabilities: Deferred compensation – SERP obligation (4,125 ) (4,125 ) — —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Loss Contingencies by Contingency	The following table sets forth our significant commitments as of December 31, 2016 , by category, for the next five years and thereafter: Year Minimum Rentals Gathering and Intermediate Transportation Derivatives Other Commitments 2017 $ 264 $ 9,646 $ 12,932 $ 596 2018 190 10,376 8,691 71 2019 70 11,702 5,746 — 2020 41 12,962 — — 2021 — 12,962 — — Thereafter — 76,674 — — Total $ 565 $ 134,322 $ 27,369 $ 667

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summary of Share-Based Compensation Expense	Successor Predecessor Period From Period From September 13, 2016 Through January 1, 2016 Through Year Ended December 31, December 31, 2016 September 12, 2016 2015 2014 Equity-classified awards $ 81 $ 1,511 $ 4,540 $ 3,627 Liability-classified awards — (19 ) (711 ) 4,520 $ 81 $ 1,492 $ 3,829 $ 8,147
Fair Value of Each Option Award Estimated on Date of Grant Using Black-Scholes-Merton Option-Pricing Formula	The fair value of each option award was estimated on the date of grant using the Black-Scholes-Merton option-pricing formula. Expected volatilities were based on historical changes in the market value of our stock. Separate groups of employees that had similar historical exercise behavior were considered separately to estimate expected lives. Options granted had a maximum term of ten years. We based the risk-free interest rate on the U.S. Treasury rate for the week of the grant having a term equal to the expected life of the option. The ranges for the assumptions used in the Black-Scholes-Merton pricing formula for the Predecessor stock options granted in the periods presented were as follows: Predecessor Year Ended December 31, 2015 2014 Expected volatility 64.6% to 69.4% 56.2% to 63.7% Dividend yield 0.00% to 0.00% 0.00% to 0.00% Expected life 3.5 to 4.6 years 3.5 to 4.6 years Risk-free interest rate 0.87% to 1.54% 0.82% to 1.63%
Activity of Awarded Options	The following table summarizes activity for our most recent fiscal year with respect to stock options: Shares Under Options Weighted- Average Exercise Price Weighted- Average Remaining Contractual Term Aggregate Intrinsic Value Balance as of January 1, 2016 (Predecessor) 3,083,821 $ 16.05 Granted — — Exercised — — Forfeited or expired — — Canceled (3,083,821 ) $ 16.05 Balance as of December 31, 2016 (Successor) — $ — — $ — Exercisable as of end of year (Successor) — $ — — $ —
Activity of Awarded Deferred Common Stock Units	The following table summarizes activity for our most recent fiscal year with respect to awarded deferred common stock units: Deferred Common Stock Units Weighted-Average Grant Date Fair Value Balance as of January 1, 2016 (Predecessor) 447,498 $ 7.75 Granted — — Converted — — Canceled (447,498 ) $ 7.75 Balance as of December 31, 2016 (Successor) — $ —
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Activity of Awarded Restricted Stock Units	The following table summarizes activity for our most recent fiscal year with respect to awarded restricted stock units: Restricted Stock Units Weighted-Average Grant Date Fair Value Balance as of January 1, 2016 (Predecessor) 468,986 $ 6.97 Granted 107,563 23.15 Vested — — Forfeited — — Canceled (468,986 ) $ 6.97 Balance as of December 31, 2016 (Successor) 107,563 $ 23.15
Performance Based Restricted Stock Units (PBRSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Share-based Payment Award, Equity Instruments Other than Options, Valuation Assumptions	The ranges for the assumptions used in the Monte Carlo model for the Predecessor PBRSUs granted in the periods presented were as follows: Predecessor Year Ended December 31, 2015 2014 Expected volatility 66.5% to 97.7% 52.6% to 72.3% Dividend yield 0.0% to 0.0% 0.0% to 0.0% Risk-free interest rate 0.01% to 1.31% 0.02% to 1.07%
Activity of Awarded Performance-based RSUs	The following table summarizes activity for our most recent fiscal year with respect to PBRSUs: Performance-Based Restricted Stock Units Weighted-Average Fair Value Balance as of January 1, 2016 (Predecessor) 941,097 $ 9.19 Granted — — Forfeited — — Canceled (941,097 ) $ 9.19 Balance as of December 31, 2016 (Successor) — $ —

Impairments (Tables)

Impairments (Tables)	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Details of Impairment of Long-Lived Assets Held and Used by Asset	The following table summarizes impairment charges recorded during the periods presented: Successor Predecessor Period From Period From September 13, 2016 Through January 1, 2016 Through Year Ended December 31, December 31, 2016 September 12,2016 2015 2014 Oil and gas properties $ — $ — $ 1,396,340 $ 791,809 Other – tubular inventory and well materials — — 1,084 — $ — $ — $ 1,397,424 $ 791,809
Fair Value Measurements, Nonrecurring	The following table summarizes the aggregate fair values of the assets described below, by asset category and the classification of inputs within the fair value measurement hierarchy, at the respective dates of impairment: Fair Value Measurement Level 1 Level 2 Level 3 Year Ended December 31, 2015 Long-lived assets held for use $ 311,886 $ — $ — $ 311,886 Year Ended December 31, 2014 Long-lived assets held for use $ 65,203 $ — $ — $ 65,203

Interest Expense (Tables)

Interest Expense (Tables)	12 Months Ended
	Dec. 31, 2016
Banking and Thrift [Abstract]
Components of Interest Expense	The following table summarizes the components of interest expense for the periods presented: Successor Predecessor Period From January 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Interest on borrowings and related fees 1 $ 678 $ 36,012 $ 92,490 $ 91,866 Amortization of debt issuance costs 2 226 22,189 4,749 4,197 Capitalized interest (25 ) (183 ) (6,288 ) (7,232 ) $ 879 $ 58,018 $ 90,951 $ 88,831 ______________________ 1 Absent the bankruptcy proceedings and the corresponding suspension of the accrual of interest on unsecured debt, we would have recorded total contractual interest expense of $ 66.1 million for the period from January 1, 2016 through September 12, 2016, including $ 15.3 million attributable to the 2019 Senior Notes and $ 46.3 million attributable to the 2020 Senior Notes. 2 Includes $ 20.5 million related to the accelerated write-off of unamortized debt issuance costs associated with the RBL and Senior Notes (see Note 11).

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Components of Calculation of Basic and Diluted Earnings Per Share	The following table provides a reconciliation of the components used in the calculation of basic and diluted earnings per share utilizing the two-class method for the periods presented: Successor Predecessor Period From September 13, 2016 Period From January 1, 2016 Year Ended December 31, Through December 31, 2016 Through September 12, 2016 2015 2014 Net income (loss) $ (5,296 ) $ 1,054,602 $ (1,582,961 ) $ (409,592 ) Less: Preferred stock dividends 1 — (5,972 ) (22,789 ) (17,148 ) Less: Induced conversion of preferred stock — — — (4,256 ) Net income (loss) attributable to common shareholders – basic and diluted $ (5,296 ) $ 1,048,630 $ (1,605,750 ) $ (430,996 ) Weighted-average shares – basic 14,992 88,013 73,639 68,887 Effect of dilutive securities 2 — 36,074 — — Weighted-average shares – diluted 14,992 124,087 73,639 68,887 ______________________ 1 Preferred stock dividends were excluded from diluted earnings per share for the years ended December 31, 2015 and 2014 , respectively, as the assumed conversion of the outstanding preferred stock would have been anti-dilutive. 2 For the period from September 13, 2016 through December 31, 2016, less than 0.1 million potentially dilutive securities, represented by restricted stock units, had the effect of being anti-dilutive and were excluded from the calculation of diluted earnings per common share. For 2015 and 2014 , respectively, approximately 30.2 million and 26.6 million potentially dilutive securities, including the Series A and Series B Preferred Stock, stock options and restricted stock units had the effect of being anti-dilutive and were excluded from the calculation of diluted earnings per common share.

Summary of Significant Accoun48

Summary of Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016Boe
Property, Plant and Equipment [Line Items]
Barrel of liquids equivalents of natural gas	0.006
Oil And Gas Unproved Properties
Property, Plant and Equipment [Line Items]
Useful lives	over the lesser of five years or the average remaining lease term
Useful life	5 years
Minimum | Gathering systems
Property, Plant and Equipment [Line Items]
Useful life	15 years
Minimum | Other property and equipment
Property, Plant and Equipment [Line Items]
Useful life	3 years
Maximum
Property, Plant and Equipment [Line Items]
Revenue collection period	60 days
Maximum | Gathering systems
Property, Plant and Equipment [Line Items]
Useful life	20 years
Maximum | Other property and equipment
Property, Plant and Equipment [Line Items]
Useful life	20 years

Bankruptcy Proceedings (Details

Bankruptcy Proceedings (Details)	May 12, 2016subsidiary	Sep. 12, 2016USD ($)shares	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)shares	Aug. 11, 2016	May 11, 2016	May 10, 2016USD ($)	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Bankruptcy Claims, amount reserved for outstanding claims			$ 3,922,000					$ 0
Liabilities Subject to Compromise, Senior Notes		$ 1,075,000,000
Backstop Commitment Agreement, Backstop Commitment		6,022,000					$ 50,000,000
Number of Subsidiaries Filing Chapter 11 Bankruptcy | subsidiary	8
Percentage of Common Stock Holders agreed to RSA				86.00%
Plan of Reorganization, Percent of Claims Attributable to Pre-Petition Completed					100.00%
Liabilities Subject to Compromise, Debt and Accrued Interest		$ 1,122,000,000
Plan of Reorganization, Senior Notes and Unsecured Claims Common Stock Exchanged | shares				6,069,074
Plan of Reorganization, percentage of commons stock lenders to receive net of backstop fee		41.00%
Rights Offering, Rights Offering Amount		$ 49,943,000
Plan of Reorganization, Rights Offering Issuance of Common Stock | shares		7,633,588
Plan of Reorganization, Percentage of Common Stock to holders of claims arising under the Senior Notes, general unsecured claims and to the Backstop Parties		51.00%
Plan of Reorganization, Backstop Parties Common Shares Received | shares		472,902
Plan Of Reorganization, Backstop Parties Common Shares Received, Percent Of Common Stock		3.00%
Plan of Reorganization, CS authorized for Disputed General Unsecured Claims and Non-Accredited Investor Holders of Senior Notes | shares		816,454
Plan of Reorganization, Common Stock reserved for Issuance of Management Incentive Plan | shares		749,600
Plan of Reorganization, Line of Credit Facility, Initial Borrowing		$ 75,400,000		$ 75,400,000
Plan of Reorganization, DIP Fees		100,000
Plan of Reorganization, Cash Reserve		2,700,000
Plan of Reorganization, Escrow Account for Professional Fees		14,575,000
Debtor Reorganization Items, Legal and Advisory Professional Fees		7,200,000
DIP Facility [Member]
Debt Instrument [Line Items]
Debtor-in-Possession Financing, Borrowings Outstanding		$ 0
Senior Notes [Member] | Senior Notes Due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						7.25%
Senior Notes [Member] | Senior Notes Due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						8.50%
Share-based Compensation Award, Tranche One [Member]
Debt Instrument [Line Items]
Plan Of Reorganization, Shares Authorized, Percent Of Common Stock		5.00%

Fresh Start Accounting Fresh 50

Fresh Start Accounting Fresh Start Accounting (Details) - USD ($) $ / shares in Units, $ in Thousands	8 Months Ended
	Sep. 12, 2016	Dec. 31, 2016	Sep. 30, 2016	Sep. 13, 2016	May 10, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fresh-Start Adjustment [Line Items]
Common stock, shares issued	14,992,018	14,992,018		14,992,018		81,252,676
Proceeds from Long-term Lines of Credit	$ 75,350
Fresh Start Valuation - Discount Rate for Gathering and Transportation Costs	1350.00%
Reorganization Value	$ 333,974
Fresh-Start Adjustment, Enterprise Value	234,831		$ 266,200
Cash and cash equivalents	31,414	$ 6,761				$ 11,955	$ 6,252	$ 23,474
Short-term Debt, Fair Value	(75,350)
Fair Value of Successor Common Stock	$ 190,895
Common Stock, Shares, Outstanding	14,992,018,000
Common stock, par value	$ 12.73	$ 0.01		$ 0.01		$ 0.01
Postconfirmation, Current Liabilities	$ 54,171
Postconfirmation, Noncurrent Liabilities Excluding Long-term Debt	13,558
Fair Value of Proved Reserves	121,900
Asset Retirement Obligation	2,687	$ 2,459				$ 2,621	$ 5,890
Fair Value of Undeveloped Acreage - Eagle Ford	92,500
Fair Value of Undeveloped Acreage - Other than Eagle Ford	8,300
Fair Value of Other Fixed Assets	26,700
Fair Value of South Texas Water Facility	23,400
Debt Issuance Costs, Line of Credit Arrangements, Gross	3,011
Plan of Reorganization, Line of Credit Facility, Initial Borrowing	75,400		75,400
Postconfirmation, Additional Paid-in Capital	190,895
Fresh-Start Adjustment, Increase (Decrease), Retained Earnings (Deficit)	28,319
Preconfirmation, Stockholders' Equity	140,954
Fresh-Start Adjustment, Increase (Decrease), Stockholders' Equity	28,319
Postconfirmation, Stockholders' Equity	190,895
Fresh-Start Adjustment, Increase (Decrease), Liabilities and Stockholders' Equity	(55,751)
Rights Offering, Rights Offering Amount	49,943
Total Reorganization Proceeds	125,293
Repayments of Long-term Debt	113,653
Interest Paid	1,374
Liabilities Subject to Compromise, Senior Notes	1,075,000
Liabilities Subject to Compromise, Interest on Senior Notes	47,213
Liabilities Subject to Compromise, Firm Transportation Obligation	11,077
Liabilities Subject to Compromise, Compensation	9,733
Liabilities Subject to Compromise, Deferred Compensation	4,676
Liabilities Subject to Compromise, Accounts Payable	1,487
Liabilities Subject to Compromise, Litigation claims	1,092
Liabilities Subject to Compromise, Other accrued liabilities	3,885
Liabilities Subject to Compromise	1,154,163
Cash settlements paid or reserved at emergence	3,915
Liabilities subject to compromise, gain	1,150,248
DIP Facility Fees Paid	12
Plan of Reorganization, Escrow Account for Professional Fees	14,575
RBL lender fees and expenses	455
Ad Hoc Committee and indenture trustee fees and expenses	6,782
Payment of certain allowed claims and settlements	2,735
Total Reorganization Uses	142,597
Net Cash Payments off Reorganization Adjustments	(17,304)
Fair Value of Equity Allocated to Unsecured Creditors	174,477
Fair Value of Unsecured Creditors Pending Resolution	10,396
Backstop Commitment Agreement, Backstop Commitment	6,022				$ 50,000
Cancellation of Equity Upon Emergence from Bankruptcy	$ 882,992
Fresh-Start Adjustment, Description	28,319
Reorganization items, legal and professional fees	$ (29,976)
Reorganization items, Settlements related to contract amendments	(2,550)
Debtor Reorganization Items, DIP Facility Costs and Commitment fees	(170)
Reorganization Items, Write-off Prepaid D&O Insurance	(832)
Debtor Reorganization Items, Other Expense (Income)	(46)
Debtor Reorganization Items	1,144,993
Minimum
Fresh-Start Adjustment [Line Items]
Fresh-Start Adjustment, Enterprise Value			218,000
Maximum
Fresh-Start Adjustment [Line Items]
Fresh-Start Adjustment, Enterprise Value			382,000
Weighted Average [Member]
Fresh-Start Adjustment [Line Items]
Fresh-Start Adjustment, Enterprise Value			$ 300,000
Restatement Adjustment [Member]
Fresh-Start Adjustment [Line Items]
Fresh-Start Adjustment, Increase (Decrease), Cash and Cash Equivalents	(17,304)
Fresh-Start Adjustment, Increase (Decrease), Receivables, Net	4,292
Fresh-Start Adjustment, Increase (Decrease), Other Current Liabilities	(832)
Fresh-Start Adjustment, Increase (Decrease), Current Assets	(13,844)
Fresh-Start Adjustment, Increase (Decrease), Property and Equipment, Net	0
Fresh-Start Adjustment, Increase (Decrease), Other Assets, Noncurrent	(1,281)
Fresh-Start Adjustment, Increase (Decrease), Assets	(15,125)
Fresh-Start Adjustments, Increase (Decrease), Accounts Payable and Accrued Liabilities	(21,166)
Fresh-Start Adjustment, Increase (Decrease), Current Maturities of Long-term Debt	(113,653)
Fresh-Start Adjustment, Increase (Decrease), Current Liabilities	(134,819)
Fresh-Start Adjustment, Increase (Decrease), Long-term Debt	75,350
Fresh-Start Adjustment, Increase (Decrease), Liabilities Subject to Compromise	(1,154,163)
Fresh-Start Adjustment, Increase (Decrease), Preferred Stock	(1,880)
Fresh-Start Adjustment, Increase (Decrease) Other Deferred Compensation	(3,440)
Fresh-Start Adjustment, Increase (Decrease), Accumulated Other Comprehensive Income (Loss)	(383)
Fresh-Start Adjustment, Increase (Decrease) Treasury Stock	3,574
Fresh-Start Adjustment, Increase (Decrease), Retained Earnings (Deficit)	2,224,135
Fresh-Start Adjustment, Increase (Decrease), Stockholders' Equity	1,198,407
Fresh-Start Adjustment, Increase (Decrease), Liabilities and Stockholders' Equity	(15,125)
Successor [Member]
Fresh-Start Adjustment [Line Items]
Postconfirmation, Cash and Cash Equivalents	31,414
Postconfirmation, Current Liabilities	54,171
Postconfirmation, Receivables, Net	39,898
Postconfirmation, Derivative Assets	397
Postconfirmation, Prepaid and Other Current Assets	3,134
Postconfirmation, Current Assets	74,843
Postconfirmation, Property and Equipment, Net	253,510
Postconfirmation, Other Assets, Noncurrent	5,621
Postconfirmation, Assets	333,974
Postconfirmation, Accounts Payable and Accrued Liabilities	52,530
Postconfirmation, Current Derivative Liabilities	1,641
Postconfirmation, Other Noncurrent Obligations	4,438
Postconfirmation, Noncurrent Derivative Liabilities	9,120
Postconfirmation, Long-term Debt	75,350
Fresh-Start Adjustment, Increase (Decrease), Common Stock	150
Postconfirmation, Common Stock	150
Fresh-Start Adjustment, Increase (Decrease), Additional Paid-in Capital	190,745
Postconfirmation, Additional Paid-in Capital	190,745
Postconfirmation, Stockholders' Equity	190,895
Postconfirmation, Liabilities and Stockholders' Equity	333,974
Predecessor [Member]
Fresh-Start Adjustment [Line Items]
Preconfirmation, Cash and Cash Equivalents	48,718
Preconfirmation, Receivables, Net	35,606
Preconfirmation, Derivative Assets	397
Preconfirmation, Prepaid and Other Current Assets	3,966
Preconfirmation, Current Assets	88,687
Preconfirmation, Property and Equipment, Net	309,261
Preconfirmation, Other Assets, Noncurrent	6,902
Preconfirmation, Assets	404,850
Preconfirmation, Accounts Payable and Accrued Liabilities	77,151
Preconfirmation, Current Derivative Liabilities	1,641
Preconfirmation, Current Maturities of Long-term Debt	113,653
Preconfirmation, Current Liabilities	192,445
Preconfirmation, Other Noncurrent Obligations	84,953
Preconfirmation, Noncurrent Derivative Liabilities	9,120
Preconfirmation, Liabilities Subject to Compromise	1,154,163
Preconfirmation, Preferred Stock	1,880
Preconfirmation, Common Stock	697
Fresh-Start Adjustment, Increase (Decrease), Common Stock	(697)
Preconfirmation, Additional Paid-in Capital	1,213,797
Fresh-Start Adjustment, Increase (Decrease), Additional Paid-in Capital	(1,213,797)
Preconfirmation, Other Deferred Compensation	3,440
Preconfirmation, Accumulated Other Comprehensive Income (Loss)	383
Preconfirmation, Treasury Stock	(3,574)
Preconfirmation, Retained Earnings (Deficit)	(2,252,454)
Preconfirmation, Stockholders' Equity	(1,035,831)
Preconfirmation, Liabilities and Stockholders' Equity	404,850
Revaluation of Assets [Member]
Fresh-Start Adjustment [Line Items]
Fresh-Start Adjustment, Increase (Decrease), Property and Equipment, Net	(55,751)
Fresh-Start Adjustment, Increase (Decrease), Assets	(55,751)
Revaluation of Liabilities [Member]
Fresh-Start Adjustment [Line Items]
Fresh-Start Adjustments, Increase (Decrease), Accounts Payable and Accrued Liabilities	(3,455)
Fresh-Start Adjustment, Increase (Decrease), Current Liabilities	(3,455)
Fresh-Start Adjustment, Increase (Decrease), Deferred Income Tax Assets, Noncurrent	$ (80,615)

Acquisitions and Divestitures -

Acquisitions and Divestitures - Additional Information (Detail) - USD ($) $ in Thousands

1 Months Ended

3 Months Ended

4 Months Ended

8 Months Ended

12 Months Ended

Oct. 31, 2015

Sep. 30, 2015

Aug. 31, 2015

May 31, 2015

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2016

Sep. 12, 2016

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Significant Acquisitions and Disposals

Loss (gain) on sales of assets, net

$ 49

$ (1,261)

$ (41,335)

$ (120,769)

Eagle Ford Shale, Lavaca County [Member]

Significant Acquisitions and Disposals

Proceeds from Sale of Oil and Gas Property and Equipment

$ 12,500

Gain on sale of oil and gas property

$ 9,500

Granite Wash [Member]

Significant Acquisitions and Disposals

Proceeds from Sale of Oil and Gas Property and Equipment

$ 100

East Texas [Member]

Significant Acquisitions and Disposals

Proceeds from Sale of Oil and Gas Property and Equipment

$ 73,000

Gain on sale of oil and gas property

$ 43,000

Disposal Group, Including Discontinued Operation, Property, Plant and Equipment

29,500

Disposal Group, Including Discontinued Operation, Assets

33,300

Disposal Group, Including Discontinued Operation, Asset Retirement Obligation

$ 3,800

Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax

1,300

(27,500)

South Texas Oil Gathering Sys. Development Rights

Significant Acquisitions and Disposals

Proceeds from Sale of Intangible Assets

$ 147,100

Gain (Loss) on Disposition of Assets

147,100

Sale Leaseback Transaction, Recognized Gain, Net

63,000

Amount of the deferred gain recognized in the current period

$ 8,400

1,700

74,100

Sale Leaseback Transaction, Deferred Gain, Gross

84,100

Selma Chalk, MS Assets

Significant Acquisitions and Disposals

Proceeds from Sale of Oil and Gas Property and Equipment

$ 67,900

Impairment of property

$ 117,900

$ 117,900

South Texas Natural Gas Gathering Assets

Significant Acquisitions and Disposals

Sale Leaseback Transaction, Recognized Gain, Net

$ 56,700

Amount of the deferred gain recognized in the current period

400

400

Proceeds from Sale of Oil and Gas Property and Equipment

96,000

Loss (gain) on sales of assets, net

$ (67,300)

$ (300)

$ (9,500)

Non-core assets

Significant Acquisitions and Disposals

Proceeds from Sale of Oil and Gas Property and Equipment

2,900

Loss (gain) on sales of assets, net

$ (200)

Summary of Accounts Receivable

Summary of Accounts Receivable (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Accounts Receivable and Major Customers [Line Items]
Customers	$ 20,489	$ 23,481
Joint interest partners	7,238	18,381
Other	3,789	7,658
Accounts Receivable, Gross, Current, Total	31,516	49,520
Less: Allowance for doubtful accounts	(2,421)	(1,555)
Accounts receivable, net of allowance for doubtful accounts	$ 29,095	$ 47,965

Accounts Receivable and Major53

Accounts Receivable and Major Customers - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)Customer	Dec. 31, 2015USD ($)Customer
Sales Revenue | Customer Concentration Risk
Accounts, Notes, Loans and Financing Receivable [Line Items]
Number of major customers | Customer	3	3
Revenues, major customers	$ 122.7	$ 168.9
Concentration risk, percentage	93.00%	64.00%
Sales Revenue | Customer Concentration Risk | Major Customer 1
Accounts, Notes, Loans and Financing Receivable [Line Items]
Revenues, major customers	$ 93.5	$ 74.5
Concentration risk, percentage	71.00%	28.00%
Sales Revenue | Customer Concentration Risk | Major Customer 2
Accounts, Notes, Loans and Financing Receivable [Line Items]
Revenues, major customers	$ 15.7	$ 63.5
Concentration risk, percentage	12.00%	24.00%
Sales Revenue | Customer Concentration Risk | Major Customer 3
Accounts, Notes, Loans and Financing Receivable [Line Items]
Revenues, major customers	$ 13.5	$ 30.9
Concentration risk, percentage	10.00%	12.00%
Accounts Receivable | Credit Concentration Risk
Accounts, Notes, Loans and Financing Receivable [Line Items]
Concentration risk, percentage	81.00%	90.00%
Accounts receivable, major customers	$ 16.7	$ 21.1

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail) $ in Thousands	4 Months Ended	8 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016USD ($)counterparty$ / bbl	Sep. 12, 2016USD ($)	Sep. 30, 2016USD ($)	Dec. 31, 2016USD ($)counterparty$ / bbl	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative assets	$ 27,369			$ 27,369	$ 0
Derivatives Settled			$ 63,000
Derivatives Settled to Pay Down Revolver	$ 0	$ 51,979	$ 52,000		$ 0	$ 0
Crude Oil
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.12			49.12
Commodity contracts
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative assets	$ 27,400			$ 27,400
Number Of Derivative Counterparty | counterparty	3			3
Commodity contracts | Natural Gas
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Third-party quoted forward prices				NYMEX Henry Hub gas
Commodity contracts | Crude Oil
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Third-party quoted forward prices				West Texas Intermediate crude oil

Commodity Derivative Positions

Commodity Derivative Positions (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)bblcounterparty$ / bbl$ / bbl
Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.12
Settlement Agreement [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Fair Value Liability	$ 818
Fourth Quarter 2019 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	2,916
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.90
Fair Value Asset	$ 0
Fair Value Liability	$ 1,414
Third Quarter 2019 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	2,916
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.90
Fair Value Asset	$ 0
Fair Value Liability	$ 1,423
Second Quarter 2019 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	2,916
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.90
Fair Value Asset	$ 0
Fair Value Liability	$ 1,438
First Quarter 2019 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	2,916
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.90
Fair Value Asset	$ 0
Fair Value Liability	$ 1,471
Fourth Quarter 2018 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	3,476
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.12
Fair Value Asset	$ 0
Fair Value Liability	$ 2,091
Third Quarter 2018 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	3,476
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.12
Fair Value Asset	$ 0
Fair Value Liability	$ 2,140
Second Quarter 2018 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	3,476
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.12
Fair Value Asset	$ 0
Fair Value Liability	$ 2,193
First Quarter 2018 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	3,476
Derivative, Swap Type, Average Fixed Price | $ / bbl	49.12
Fair Value Asset	$ 0
Fair Value Liability	$ 2,267
Fourth Quarter 2017 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	4,408
Derivative, Swap Type, Average Fixed Price | $ / bbl	48.62
Fair Value Asset	$ 0
Fair Value Liability	$ 3,260
Third Quarter 2017 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	4,408
Derivative, Swap Type, Average Fixed Price | $ / bbl	48.62
Fair Value Asset	$ 0
Fair Value Liability	$ 3,290
Second Quarter 2017 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	4,408
Derivative, Swap Type, Average Fixed Price | $ / bbl	48.62
Fair Value Asset	$ 0
Fair Value Liability	$ 3,110
First Quarter 2017 [Member] | Crude Oil
Derivative Instruments Related to Oil and Gas Production [Line Items]
Instrument	Swaps
Notional Volume, per day | bbl	4,408
Derivative, Swap Type, Average Fixed Price | $ / bbl	48.62
Fair Value Asset	$ 0
Fair Value Liability	$ 2,454
Commodity contracts
Derivative Instruments Related to Oil and Gas Production [Line Items]
Number Of Derivative Counterparty | counterparty	3

Impact of Derivative Activities

Impact of Derivative Activities on Condensed Consolidated Statements of Income (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives	$ (16,622)	$ (8,333)	$ 71,247	$ 162,212

Fair Value of Derivative Instru

Fair Value of Derivative Instruments on Condensed Consolidated Balance Sheets (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative assets, current	$ 0	$ 97,956
Derivative assets	0	97,956
Derivative liabilities, noncurrent	14,437	0
Derivative liabilities, current	12,932	0
Derivative liabilities	27,369	0
Commodity contracts
Derivatives, Fair Value [Line Items]
Derivative liabilities	27,400
Commodity contracts | Derivative assets/liabilities - current
Derivatives, Fair Value [Line Items]
Derivative assets, current	0	97,956
Derivative liabilities, current	12,932	0
Commodity contracts | Derivative assets/liabilities - noncurrent
Derivatives, Fair Value [Line Items]
Derivative assets, noncurrent	0	0
Derivative liabilities, noncurrent	$ 14,437	$ 0

Summary of Property and Equipme

Summary of Property and Equipment (Detail) $ in Thousands	4 Months Ended	8 Months Ended
	Dec. 31, 2016USD ($)$ / bbl	Sep. 12, 2016USD ($)$ / bbl	Dec. 31, 2015USD ($)$ / bbl	Dec. 31, 2014$ / bbl
Property, Plant and Equipment [Line Items]
Proved Oil and Gas Property, Full Cost Method	$ 251,083
Undeveloped Leasehold Costs Transferred	$ 3,800
Capitalized Costs, Proved Properties		$ 500
Interest Costs Capitalized		$ 100
Amortization Expense Per Physical Unit of Production | $ / bbl	11.20	10.04	42.22	37.85
Oil and gas properties:
Proved			$ 2,678,415
Unproved Oil and Gas Property, Full Cost Method	$ 4,719
Unproved 1	4,700		6,881
Oil and Gas Property, Full Cost Method, Gross	255,802
Total oil and gas properties			2,685,296
Other property and equipment	3,575		31,365
Total property and equipment	259,377		2,716,661
Accumulated depreciation, depletion and amortization 1	(11,904)		(2,372,266)
Property and equipment, net (successful efforts method)	$ 247,473		$ 344,395

Reconciliation of Asset Retirem

Reconciliation of Asset Retirement Obligations which are Included in Other Liabilities (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Asset Retirement Obligation, Fresh Start Adjustment	$ 0	$ (754)	$ 0
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	2,687	2,621	5,890
Changes in estimates	27	176	172
Liabilities incurred	0	469	110
Liabilities settled	(311)	0	0
Sale of properties	0	0	(3,932)
Accretion expense	56	175	381
Balance at end of period	$ 2,459	$ 2,687	$ 2,621

Summary of Long-Term Debt (Deta

Summary of Long-Term Debt (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Amortization of debt issuance costs 2	$ 226	$ 22,189	$ 4,749	$ 4,197
Credit facility 2	25,000		0
Long-term debt	25,000		0
Debt Instrument, Unamortized Discount	0		(20,617)
Long-term Debt	25,000		1,245,000
Long-term Debt, Current Maturities	0		(1,224,383)
Senior Notes Due 2019 [Member]
Debt Instrument [Line Items]
Senior notes	0		300,000
Debt Instrument, Unamortized Discount	0		(3,295)
Senior Notes Due 2020 [Member]
Debt Instrument [Line Items]
Senior notes	0		775,000
Debt Instrument, Unamortized Discount	$ 0		$ (17,322)

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail)	4 Months Ended	8 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 12, 2016USD ($)	Sep. 30, 2016	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Disclosure [Line Items]
Interest on borrowings and related fees 1	$ 678,000	$ 36,012,000			$ 92,490,000	$ 91,866,000
Amortization of debt issuance costs 2	226,000	22,189,000			4,749,000	4,197,000
Interest Paid, Capitalized	(25,000)	(183,000)			(6,288,000)	(7,232,000)
Interest Expense	$ 879,000	58,018,000			$ 90,951,000	$ 88,831,000
Maximum borrowing capacity		128,000,000
Required covenant, current ratio	1			1
Interest Coverage Ratio, Maximum	3			3
Revolving Credit Facility [Member]
Debt Disclosure [Line Items]
Maximum borrowing capacity		$ 200,000,000
Revolving Credit Facility [Member] | Minimum
Debt Disclosure [Line Items]
Credit facility interest rate option one, applicable margin rate over Adjusted LIBOR	2.00%
Revolving Credit Facility [Member] | Maximum
Debt Disclosure [Line Items]
Credit facility interest rate option one, applicable margin rate over Adjusted LIBOR	3.00%
Credit facility interest rate option two, applicable margin rate		4.00%
Revolving Credit Facility [Member] | Future Period [Member]
Debt Disclosure [Line Items]
Required covenant, debt to EBITDAX ratio	4			4
Revolving Credit Facility [Member] | Future Period Two [Member]
Debt Disclosure [Line Items]
Required covenant, debt to EBITDAX ratio	3.75			3.75
Revolving Credit Facility [Member] | through maturity
Debt Disclosure [Line Items]
Required covenant, debt to EBITDAX ratio	3.50			3.50
Revolving credit facility
Debt Disclosure [Line Items]
Letter of credit amount outstanding	$ 800,000			$ 800,000
Line of Credit Facility, Interest Rate at Period End	3.67%			3.67%
Commitment fees for undrawn credit facility				0.50%
Revolving credit facility | Letter of Credit
Debt Disclosure [Line Items]
Maximum borrowing capacity	$ 5,000,000			$ 5,000,000
Interest Payable One [Member] | Revolving Credit Facility [Member]
Debt Disclosure [Line Items]
Debt Instrument, Interest Payable Period			1 month
Interest Payable Two [Member] | Revolving Credit Facility [Member]
Debt Disclosure [Line Items]
Debt Instrument, Interest Payable Period			3 months
Interest Payable Three [Member] | Revolving Credit Facility [Member]
Debt Disclosure [Line Items]
Debt Instrument, Interest Payable Period			6 months

Summary of Provision for Income

Summary of Provision for Income Taxes from Continuing Operations (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Current income taxes (benefit)
Federal	$ 0	$ 0	$ (660)	$ 2,045
State	0	0	1	1,504
Current income tax expense (benefit), total	0	0	(659)	3,549
Deferred income tax benefit
Federal	0	0	(261)	(130,693)
State	0	0	(4,451)	(4,534)
Deferred income tax benefit, total	0	0	(4,712)	(135,227)
Income tax benefit	$ 0	$ 0	$ (5,371)	$ (131,678)

Income Taxes Reconciliation (De

Income Taxes Reconciliation (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Expense (Benefit), Continuing Operations, Income Tax Reconciliation [Abstract]
Computed at federal statutory rate	$ (1,854)	$ 369,111	$ (555,916)	$ (189,445)
State income taxes, net of federal income tax benefit	197	1,989	(4,438)	(3,556)
Change in valuation allowance	1,657	(384,692)	554,879	61,104
Effective Income Tax Rate Reconciliation, Reorganization Adjustments, Amount	0	13,572	0	0
Other, net	0	20	104	219
Income tax benefit	$ 0	$ 0	$ (5,371)	$ (131,678)
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Abstract]
Computed at federal statutory rate	35.00%	35.00%	35.00%	35.00%
State income taxes, net of federal income tax benefit	(3.71%)	0.19%	0.30%	0.60%
Valuation allowance	(31.29%)	(36.48%)	(35.00%)	(11.30%)
Effective Income Tax Rate Reconciliation, Reorganization Adjustments, Percent	0.00%	1.29%	0.00%	0.00%
Other, net	0.00%	0.00%	0.00%	0.00%
Effective Income Tax Rate, Continuing Operations, Total	0.00%	0.00%	0.30%	24.30%

Summary of Principal Components

Summary of Principal Components of Net Deferred Income Tax Liability (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Deferred tax assets:
Property and equipment	$ 183,303	$ 417,535
Pension and postretirement benefits	710	2,276
Share-based compensation	28	7,393
Net operating loss (“NOL”) carryforwards	87,622	222,971
Deferred Tax Assets, Derivative Instruments	9,579
Deferred gains	0	30,382
Other	7,166	16,637
Deferred tax assets, gross	288,408	697,194
Less: Valuation allowance	(288,408)	(662,909)
Total net deferred tax assets	0	34,285
Deferred tax liabilities:
Fair value of derivative instruments	0	34,285
Deferred tax liabilities, gross	0	34,285
Deferred tax liabilities, net	$ 0	$ 0

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Valuation Allowance [Line Items]
Deferred tax assets, valuation allowance	$ 288,408	$ 662,909
Liabilities for unrecognized tax benefits	0	0	$ 0
Interest and penalty charges	0	0	$ 0
Federal
Valuation Allowance [Line Items]
Operating loss carryforwards	$ 120,300
Federal | Minimum
Valuation Allowance [Line Items]
Operating loss carryforward expiration year	2,032
Federal | Maximum
Valuation Allowance [Line Items]
Operating loss carryforward expiration year	2,036
State and Local Jurisdiction
Valuation Allowance [Line Items]
Operating loss carryforwards	$ 69,600
Operating loss carryforwards, valuation allowance	$ 288,400
State and Local Jurisdiction | Minimum
Valuation Allowance [Line Items]
Operating loss carryforward expiration year	2,024
State and Local Jurisdiction | Maximum
Valuation Allowance [Line Items]
Operating loss carryforward expiration year	2,036
Federal, State and Local Tax Jurisdictions
Valuation Allowance [Line Items]
Deferred tax assets, valuation allowance		$ 662,900
Federal and state valuation allowance established against net deferred tax assets	$ 374,500

Exit Activities - Exit Activiti

Exit Activities - Exit Activities (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 12, 2016USD ($)
Restructuring and Related Activities [Abstract]
Restructuring and Related Cost, Number of Positions Eliminated	53
Severance and Termination Benefits Paid	$ 2.1
Severance and Termination Benefits	1.4
Retention Bonuses	0.7
Liabilities Subject to Compromise, Early Contract Termination Fees	$ 1.7
Restructuring Reserve		$ 10.8

Components of Selected Balance

Components of Selected Balance Sheet Accounts (Detail) - USD ($) $ in Thousands		Dec. 31, 2016	Dec. 31, 2015
Other current assets:
Tubular inventory and well materials		$ 2,125	$ 2,878
Prepaid expenses		903	4,184
Other		0	42
Other current assets		3,028	7,104
Other assets:
Deferred issuance costs of the credit facilities 1	[1]	2,785	1,572
Assets of supplemental employee retirement plan	[2]	0	4,123
Other		2,544	2,655
Accounts payable and accrued liabilities:
Trade accounts payable		9,825	11,603
Drilling costs		2,479	12,074
Royalties and revenue - related		26,116	39,119
Compensation-related		2,557	9,904
Interest		55	15,531
Sale Leaseback Transaction, Deferred Gain, Current		0	2,593
Restructuring Reserve, Current		0	2,756
Bankruptcy Claims, amount reserved for outstanding claims		3,922	0
Other		4,743	9,945
Other liabilities:
Deferred gains on sales of assets		0	82,943
Firm transportation obligation		0	10,705
Asset retirement obligations		2,459	2,621
Defined benefit pension obligations		1,025	1,129
Postretirement health care benefit obligations		488	731
Compensation-related		0	1,447
Deferred compensation - supplemental employee retirement plan obligation and other		0	4,434
Other		$ 100	$ 928
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOjJlMjQ0OWRiZTA3NzQ1ZDQ4YzViMDgxZTZiODEzYmJhfFRleHRTZWxlY3Rpb246MjEwNkE2MEE4OUZGNDE2NzhBMEJENEQyQjg0RDNFQ0QM}
[2]	.

Fair Value Summary of Long-Term

Fair Value Summary of Long-Term Debt with Fixed Interest Rates (Detail) - USD ($) $ in Thousands	Dec. 31, 2016		Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 25,000		$ 0
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt with fixed interest rates	0		166,303
Fair Value | Senior Notes Due 2019 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt with fixed interest rates	0	[1]	40,830
Fair Value | Senior Notes Due 2020 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt with fixed interest rates	0	[1]	125,473
Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0		1,075,000
Carrying Value | Senior Notes Due 2019 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	[1]	300,000
Carrying Value | Senior Notes Due 2020 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 0		$ 775,000
[1]	1 The Senior Notes were canceled upon our emergence from bankruptcy.

Assets and Liabilities Measured

Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Assets:
Commodity derivative assets – current	$ 0	$ 97,956,000
Liabilities:
Derivative liabilities, current	12,932,000	0
Derivative liabilities, noncurrent	14,437,000	0
Fair Value, Measurements, Recurring
Assets:
Assets of SERP		4,123
Liabilities:
Deferred compensation – SERP obligation		4,125,000
Fair Value, Measurements, Recurring | Level 1
Assets:
Assets of SERP		4,123
Liabilities:
Deferred compensation – SERP obligation		(4,125,000)
Fair Value, Measurements, Recurring | Level 2
Assets:
Assets of SERP		0
Liabilities:
Deferred compensation – SERP obligation		0
Fair Value, Measurements, Recurring | Level 3
Assets:
Assets of SERP		0
Liabilities:
Deferred compensation – SERP obligation		0
Fair Value, Measurements, Recurring | Commodity contracts
Assets:
Commodity derivative assets – current		97,956,000
Liabilities:
Derivative liabilities, current	(12,932,000)
Derivative liabilities, noncurrent	(14,437,000)
Fair Value, Measurements, Recurring | Commodity contracts | Level 1
Assets:
Commodity derivative assets – current		0
Liabilities:
Derivative liabilities, current	0
Derivative liabilities, noncurrent	0
Fair Value, Measurements, Recurring | Commodity contracts | Level 2
Assets:
Commodity derivative assets – current		97,956,000
Liabilities:
Derivative liabilities, current	(12,932,000)
Derivative liabilities, noncurrent	(14,437,000)
Fair Value, Measurements, Recurring | Commodity contracts | Level 3
Assets:
Commodity derivative assets – current		$ 0
Liabilities:
Derivative liabilities, current	0
Derivative liabilities, noncurrent	$ 0

Significant Commitments by Cate

Significant Commitments by Category (Detail) $ in Thousands	Dec. 31, 2016USD ($)
Minimum Rental Commitments
2,017	$ 264
2,018	190
2,019	70
2,020	41
2,021	0
Thereafter	0
Total	565
Gathering and Intermediate Transportation [Member]
Commitments
Contractual Commitments Future Minimum Payments Due Current	9,646
2,018	10,376
2,019	11,702
2,020	12,962
2,021	12,962
Thereafter	76,674
Total	134,322
Drilling carry [Member]
Commitments
Contractual Commitments Future Minimum Payments Due Current	12,932
2,018	8,691
2,019	5,746
2,020	0
2,021	0
Thereafter	0
Total	27,369
Other Commitments
Commitments
Contractual Commitments Future Minimum Payments Due Current	596
2,018	71
2,019	0
2,020	0
2,021	0
Thereafter	0
Total	$ 667

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) $ in Thousands	2 Months Ended	4 Months Ended	8 Months Ended	9 Months Ended	12 Months Ended
	Sep. 12, 2016USD ($)	Dec. 31, 2016USD ($)	Sep. 12, 2016USD ($)	Sep. 30, 2016USD ($)bbl	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2010USD ($)
Commitments and Contingencies Disclosure [Line Items]
Operating lease rental expense		$ 200	$ 2,400		$ 7,200	$ 8,700
Reorganization items, Settlements related to contract amendments			2,550
Long-term Purchase Commitment, Minimum Volume Required | bbl				8,000
Crude Oil Gathering Agreement				10
Asset retirement obligations	$ 2,687	2,459	$ 2,687		$ 2,621	$ 5,890
Environmental Compliance
Commitments and Contingencies Disclosure [Line Items]
Asset retirement obligations		2,500
Legal Reserve
Commitments and Contingencies Disclosure [Line Items]
Reserve established for contingency matters				$ 100			$ 900
Gathering and Intermediate Transportation [Member]
Commitments and Contingencies Disclosure [Line Items]
Contractual Commitments Future Minimum Payments Due		134,322
Contractual Commitments Future Minimum Payments Due Current		9,646
Drilling carry [Member]
Commitments and Contingencies Disclosure [Line Items]
Contractual Commitments Future Minimum Payments Due		27,369
Contractual Commitments Future Minimum Payments Due Current		$ 12,932
Crude Oil Gathering And Transportation Services [Member]
Commitments and Contingencies Disclosure [Line Items]
Reorganization items, Settlements related to contract amendments	$ 300
Original Volume Required [Domain]
Commitments and Contingencies Disclosure [Line Items]
Long-term Purchase Commitment, Minimum Volume Required | bbl				15,000
Term in Years [Domain]
Commitments and Contingencies Disclosure [Line Items]
Crude Oil Gathering Agreement				15
Marketing Agreement				10

Shareholders' Equity - Addition

Shareholders' Equity - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2016	Sep. 13, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Class of Stock [Line Items]
Preferred stock, shares authorized	5,000,000			100,000
Common stock, shares issued	14,992,018	14,992,018	14,992,018	81,252,676
Common stock, par value	$ 0.01	$ 0.01	$ 12.73	$ 0.01
Common stock, shares authorized	45,000,000			228,000,000
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Accumulated other comprehensive losses attributable to pension and postretirement benefit obligations, net of tax	$ 0.1		$ 0.1	$ 0.4	$ 0.2
Treasury stock (in shares)	0			455,689

Share-Based Compensation - Addi

Share-Based Compensation - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation (equity-classified)	$ 81	$ 1,511		$ 4,540	$ 3,627
Exercised (in shares)			0
Deferred compensation obligation				0	17,148
Recognized expense	100	500		900	1,700
Compensation	2,557		$ 2,557	9,904
Liability-classified awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation (equity-classified)	0	$ (19)		$ (711)	$ 4,520
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expiration period		10 years
Vesting period			3 years
Weighted-average grant-date fair value of options granted during period (per share)				$ 3.15	$ 7.46
Total intrinsic value of options exercised				$ 2,300
Exercised (in shares)				0
Unrecognized compensation cost weighted-average recognition period			1 year 6 months
Total grant-date fair values of options vested during period				$ 1,300	$ 1,800
Deferred Common Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)			0
Granted (in dollars per share)			$ 0
Deferred compensation obligation				3,400
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost	$ 2,400		$ 2,400
Granted (in shares)			107,563
Granted (in dollars per share)			$ 23.15
Total grant-date fair values of RSUs that vested during period				$ 2,200	$ 600
Performance Based Restricted Stock Units (PBRSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)			0
Granted (in dollars per share)			$ 0
Performance Based Restricted Stock Units (PBRSUs) | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares expected to vest at grant date		0.00%
Performance Based Restricted Stock Units (PBRSUs) | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares expected to vest at grant date		200.00%
Vests ratably over 3 years | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting description			One-third vesting in each year
Award vesting rights percentage		33.33%
Vests ratably over 3 years | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting description			One-third vesting in each year
Award vesting rights percentage		33.33%
Vests ratably over 3 years | Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting description			One-third vesting in each year
Award vesting rights percentage		33.33%
Performance Period 1 | Performance Based Restricted Stock Units (PBRSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance period		1 year
Performance Period 2 | Performance Based Restricted Stock Units (PBRSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance period		2 years
Performance Period 3 | Performance Based Restricted Stock Units (PBRSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance period		3 years
Employees and Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance	749,600		749,600
Non-employee Director | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Exercised (in shares)			0	0
Granted (in shares)				195,395	15,501
Granted (in dollars per share)				$ 1.33	$ 11.61
Other Pension Plan, Postretirement or Supplemental Plans [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pension and Other Postretirement Benefit Expense	$ 100	$ 100		$ 100	$ 100
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	1,700		$ 1,700	2,100
Pension Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay			6.00%
Compensation	$ 100		$ 100	$ 200

Summary of Share-Based Compensa

Summary of Share-Based Compensation Expense (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Share-based compensation (equity-classified)	$ 81	$ 1,511	$ 4,540	$ 3,627
Allocated Share-based Compensation Expense	81	1,492	3,829	8,147
Liability-classified awards
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Share-based compensation (equity-classified)	$ 0	$ (19)	$ (711)	$ 4,520

Fair Value of Each Award Estima

Fair Value of Each Award Estimated on Date of Grant Using Black-Scholes-Merton Option-Pricing Formula (Detail)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock Options
Schedule of Benefit Obligations Weighted Average Assumptions [Line Items]
Expected volatility, min		64.60%	56.20%
Expected volatility, max		69.40%	63.70%
Dividend yield, min		0.00%	0.00%
Dividend yield, max		0.00%	0.00%
Risk-free interest rate, min		0.87%	0.82%
Risk-free interest rate, max		1.54%	1.63%
Stock Options | Minimum
Schedule of Benefit Obligations Weighted Average Assumptions [Line Items]
Expected life		3 years 6 months	3 years 6 months
Stock Options | Maximum
Schedule of Benefit Obligations Weighted Average Assumptions [Line Items]
Expected life		4 years 7 months	4 years 7 months
Performance Based Restricted Stock Units (PBRSUs)
Schedule of Benefit Obligations Weighted Average Assumptions [Line Items]
Expected volatility, min	66.50%	52.60%
Expected volatility, max	97.70%	72.30%
Dividend yield, min	0.00%	0.00%
Dividend yield, max	0.00%	0.00%
Risk-free interest rate, min	1.00%	0.02%
Risk-free interest rate, max	1.31%	1.07%

Activity of Awarded Options (De

Activity of Awarded Options (Detail) - USD ($)	8 Months Ended	12 Months Ended
	Sep. 12, 2016	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangements by Share-based Payment Award, Options, Cancelled	$ (3,083,821)
Share-based Compensation Arrangement by Share-by Payment Awards, Options, Weighted Average Price of Shares Canceled	$ 16.05
Shares Under Options
Outstanding at beginning of year (in shares)	3,083,821	3,083,821
Granted (in shares)		0
Exercised (in shares)		0
Forfeited (in shares)		0
Outstanding at end of year (in shares)		0	3,083,821
Exercisable at end of year (in shares)		0
Weighted- Average Exercise Price
Outstanding at beginning of year (in dollars per share)	$ 16.05	$ 16.05
Granted (in dollars per share)		0
Exercised (in dollars per share)		0
Forfeited (in dollars per share)		0
Outstanding at end of year (in dollars per share)		0	$ 16.05
Exercisable at end of year (in dollars per share)		$ 0
Aggregate Intrinsic Value
Balance as of December 31, 2016 (Successor)		$ 0
Exercisable as of end of year (Successor)		$ 0
Non-employee Director | Common Stock [Member]
Shares Under Options
Exercised (in shares)		0	0

Activity of Awarded Deferred Co

Activity of Awarded Deferred Common Stock Units (Detail) - USD ($)	8 Months Ended	12 Months Ended
	Sep. 12, 2016	Dec. 31, 2016
Number of shares
Share-based Compensation Arrangements by Share-based Payment Award, Options, Cancelled	$ 3,083,821
Weighted-Average Grant Date Fair Value
Share-based Compensation Arrangement by Share-by Payment Awards, Options, Weighted Average Price of Shares Canceled	$ 16.05
Deferred Common Stock Units
Number of shares
Balance at beginning of year (in shares)	447,498	447,498
Granted (in shares)		0
Converted (in shares)		0
Share-based Compensation Arrangements by Share-based Payment Award, Options, Cancelled		$ (447,498)
Balance at end of year (in shares)		0
Weighted-Average Grant Date Fair Value
Balance at beginning of year (in dollars per share)	$ 7.75	$ 7.75
Granted (in dollars per share)		0
Converted (in dollars per share)		0
Share-based Compensation Arrangement by Share-by Payment Awards, Options, Weighted Average Price of Shares Canceled		7.75
Balance at end of year (in dollars per share)		$ 0

Activity of Awarded Restricted

Activity of Awarded Restricted Stock Units (Detail) - USD ($)	8 Months Ended	12 Months Ended
	Sep. 12, 2016	Dec. 31, 2016
Weighted-Average Grant Date Fair Value
Share-based Compensation Arrangements by Share-based Payment Award, Options, Cancelled	$ 3,083,821
Share-based Compensation Arrangement by Share-by Payment Awards, Options, Weighted Average Price of Shares Canceled	$ 16.05
Restricted Stock Units (RSUs)
Number of shares
Balance at beginning of year (in shares)	468,986	468,986
Granted (in shares)		107,563
Vested (in shares)		0
Forfeited (in shares)		0
Balance at end of year (in shares)		107,563
Weighted-Average Grant Date Fair Value
Balance at beginning of year (in dollars per share)	$ 6.97	$ 6.97
Granted (in dollars per share)		23.15
Vested (in dollars per share)		0
Forfeited (in dollars per share)		$ 0
Share-based Compensation Arrangements by Share-based Payment Award, Options, Cancelled		$ (468,986)
Balance at end of year (in dollars per share)		$ 23.15
Share-based Compensation Arrangement by Share-by Payment Awards, Options, Weighted Average Price of Shares Canceled		$ 6.97
Performance Based Restricted Stock Units (PBRSUs)
Number of shares
Balance at beginning of year (in shares)	941,097	941,097
Granted (in shares)		0
Forfeited (in shares)		0
Balance at end of year (in shares)		0
Weighted-Average Grant Date Fair Value
Balance at beginning of year (in dollars per share)	$ 9.19	$ 9.19
Granted (in dollars per share)		0
Forfeited (in dollars per share)		$ 0
Share-based Compensation Arrangements by Share-based Payment Award, Options, Cancelled		$ (941,097)
Balance at end of year (in dollars per share)		$ 0
Share-based Compensation Arrangement by Share-by Payment Awards, Options, Weighted Average Price of Shares Canceled		$ 9.19
Minimum | Performance Based Restricted Stock Units (PBRSUs)
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Shares, Expected to Vest, Percentage	0.00%
Maximum | Performance Based Restricted Stock Units (PBRSUs)
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Shares, Expected to Vest, Percentage	200.00%

Impairments (Details)

Impairments (Details) - USD ($) $ in Thousands	3 Months Ended	4 Months Ended	8 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Impaired Long-Lived Assets Held and Used [Line Items]
Impairments		$ 0	$ 0	$ 1,397,424	$ 791,809
Impairment of Long-Lived Assets Held-for-use		0	0	1,396,340	791,809
Other Asset Impairment Charges		$ 0	$ 0	1,084	0
Eagle Ford Shale, Lavaca County [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Long-Lived Assets Held-for-use				1,400,000
East Texas, Granite Wash and Marcellus regions
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Long-Lived Assets Held-for-use					667,800
Mid-Continent region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Oil and Gas Properties					6,100
Selma Chalk
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Oil and Gas Properties	$ 117,900				$ 117,900
Tubular Goods
Impaired Long-Lived Assets Held and Used [Line Items]
Other Asset Impairment Charges				1,100
Fair Value, Measurements, Nonrecurring
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Long-Lived Assets Held-for-use				$ 312,000

Impairments Impairments Fair Va

Impairments Impairments Fair Value Nonrecurring (Details) - Fair Value, Measurements, Nonrecurring - Long-lived assets held for use - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Assets, fair value	$ 311,886	$ 65,203
Level 1
Property, Plant and Equipment [Line Items]
Assets, fair value	0	0
Level 2
Property, Plant and Equipment [Line Items]
Assets, fair value	0	0
Level 3
Property, Plant and Equipment [Line Items]
Assets, fair value	$ 311,886	$ 65,203

Components of Interest Expense

Components of Interest Expense (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument, Redemption [Line Items]
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations		$ 66,100
Debtor Reorganization Items, Write-off of Debt Issuance Costs and Debt Discounts		20,500
Interest on borrowings and related fees 1	$ 678	36,012	$ 92,490	$ 91,866
Amortization of debt issuance costs 2	226	22,189	4,749	4,197
Capitalized interest	(25)	(183)	(6,288)	(7,232)
Interest expense	$ 879	58,018	$ 90,951	$ 88,831
Senior Notes Due 2019 [Member]
Debt Instrument, Redemption [Line Items]
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations		15,300
Senior Notes Due 2020 [Member]
Debt Instrument, Redemption [Line Items]
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations		$ 46,300

Components of Calculation of Ba

Components of Calculation of Basic and Diluted Earnings Per Share (Detail) - USD ($) shares in Thousands, $ in Thousands	4 Months Ended		8 Months Ended		12 Months Ended
	Dec. 31, 2016		Sep. 12, 2016		Dec. 31, 2015		Dec. 31, 2014
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income (loss)	$ (5,296)		$ 1,054,602		$ (1,582,961)		$ (409,592)
Less: Preferred stock dividends	0		(5,972)	[1]	(22,789)	[1]	(17,148)	[1]
Induced conversion of preferred stock	0		0		0		(4,256)
Net loss attributable to common shareholders – basic and diluted	$ (5,296)		$ 1,048,630		$ (1,605,750)		$ (430,996)
Weighted-average shares – basic	14,992		88,013		73,639		68,887
Effect of dilutive securities	0	[2]	36,074		0	[2]	0	[2]
Weighted-average shares – diluted	14,992		124,087		73,639		68,887
Potentially dilutive securities with the effect of being anti-dilutive excluded from the calculation of diluted earnings per common share	100				30,200		26,600
[1]	Preferred stock dividends were excluded from diluted earnings per share for the years ended December 31, 2015 and 2014, respectively, as the assumed conversion of the outstanding preferred stock would have been anti-dilutive.
[2]	For 2015 and 2014, respectively, approximately 30.2 million and 26.6 million potentially dilutive securities, including the Series A and Series B Preferred Stock, stock options and restricted stock units had the effect of being anti-dilutive and were excluded from the calculation of diluted earnings per common share.