Petroquest Energy (PQ) 10-K 28 Mar 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Mar. 10, 2019	Jun. 29, 2018
Entity Registrant Name	PETROQUEST ENERGY INC
Entity Central Index Key	0000872248
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	true
Entity Shell Company	false
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 5,424
Class A Common Stock
Entity Common Stock, Shares Outstanding		9,200,000
Class B Common Stock
Entity Common Stock, Shares Outstanding		1
Class C Common Stock
Entity Common Stock, Shares Outstanding		1

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 34,891	$ 15,655
Revenue receivable	6,364	15,340
Joint interest billing receivable	4,716	6,597
Other receivable	0	7,750
Derivative asset	0	1,174
Deposit for surety bonds	3,550	8,300
Other current assets	3,261	2,125
Total current assets	52,782	56,941
Oil and gas properties:
Oil and gas properties, full cost method	1,361,374	1,369,861
Unevaluated oil and gas properties	23,492	21,854
Accumulated depreciation, depletion and amortization	(1,301,592)	(1,285,660)
Oil and gas properties, net	83,274	106,055
Other property and equipment	9,282	9,353
Accumulated depreciation of other property and equipment	(9,056)	(8,843)
Total property and equipment	83,500	106,565
Other assets	1,005	792
Total assets	137,287	164,298
Current liabilities:
Accounts payable to vendors	11,699	32,148
Advances from co-owners	2,020	1,730
Oil and gas revenue payable	7,765	19,344
Accrued interest	639	1,724
Asset retirement obligation	183	687
Derivative liability	0	731
Other accrued liabilities	1,259	6,476
Total current liabilities	23,565	62,840
Multi-draw Term Loan	49,738	27,963
Asset retirement obligation	2,297	30,623
Preferred stock dividend payable	0	10,278
Other long-term liabilities	0	131
Liabilities Not Subject To Compromise	75,600	413,233
Liabilities subject to compromise	323,854	0
Total liabilities	399,454	413,233
Stockholders’ equity:
Preferred stock, $.001 par value; authorized 5,000 shares; issued and outstanding 1,495 shares	1	1
Common stock, $.001 par value; authorized 150,000 shares; issued and outstanding 25,587 and 25,521 shares, respectively	26	26
Paid-in capital	314,268	313,244
Accumulated other comprehensive income	0	278
Accumulated deficit	(576,462)	(562,484)
Total stockholders’ equity	(262,167)	(248,935)
Total liabilities and stockholders’ equity	137,287	164,298
10% Senior Secured Notes due 2021 | Senior Notes
Current liabilities:
10% Senior Secured Notes	0	9,821
10% Senior Secured PIK Notes due 2021 | Payment in Kind (PIK) Note
Current liabilities:
10% Senior Secured Notes	$ 0	$ 271,577

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Preferred stock, par value (usd per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	1,495,000	1,495,000
Preferred stock, shares outstanding	1,495,000	1,495,000
Common stock, par value (usd per share)	$ 0.001	$ 0.001
Common stock, shares authorized	150,000,000	150,000,000
Common stock, shares issued	25,587,000	25,521,000
Common stock, shares outstanding	25,587,000	25,521,000
10% Senior Secured Notes due 2021 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate	10.00%	10.00%
10% Senior Secured PIK Notes due 2021 | Payment in Kind (PIK) Note
Debt Instrument [Line Items]
Stated interest rate	10.00%	10.00%

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues:
Oil and gas sales	$ 87,099,000	$ 108,287,000	$ 66,667,000
Expenses:
Lease operating expenses	20,552,000	33,162,000	28,508,000
Production taxes	3,198,000	3,302,000	354,000
Depreciation, depletion and amortization	22,667,000	32,053,000	28,720,000
Ceiling test write-down	0	0	40,304,000
General and administrative	17,564,000	15,860,000	26,040,000
Accretion of asset retirement obligation	322,000	2,252,000	2,515,000
Interest expense	28,147,000	28,836,000	30,019,000
Total expenses	92,450,000	115,465,000	156,460,000
Other income (expense):
Other income (expense)	248,000	(408,000)	(560,000)
Other income (expense), net	248,000	(408,000)	(560,000)
Loss from operations	(5,103,000)	(7,586,000)	(90,353,000)
Reorganization items	4,293,000	0	0
Income tax expense (benefit)	152,000	(949,000)	543,000
Net loss	(9,548,000)	(6,637,000)	(90,896,000)
Preferred stock dividend	4,371,000	5,139,000	5,349,000
Net loss available to common stockholders	$ (13,919,000)	$ (11,776,000)	$ (96,245,000)
Basic
Net loss per share (in usd per share)	$ (0.54)	$ (0.55)	$ (5.24)
Diluted
Net loss per share (in usd per share)	$ (0.54)	$ (0.55)	$ (5.24)
Weighted average number of common shares:
Basic (shares)	25,581	21,330	18,354
Diluted (shares)	25,581	21,330	18,354

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Loss - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Comprehensive Income [Abstract]
Net loss	$ (9,548)	$ (6,637)	$ (90,896)
Change in fair value of derivatives, net of income tax (expense) benefit of $106, ($165) and $561, respectively	(278)	5,028	(5,697)
Comprehensive loss	$ (9,826)	$ (1,609)	$ (96,593)

Consolidated Statements of Co_2

Consolidated Statements of Comprehensive Loss (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Comprehensive Income [Abstract]
Income tax (expense) benefit related to other comprehensive income due to derivatives	$ 106	$ (165)	$ 561

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash flows provided by (used in) operating activities:
Net loss	$ (9,548,000)	$ (6,637,000)	$ (90,896,000)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Deferred tax (benefit) expense	152,000	(949,000)	543,000
Depreciation, depletion and amortization	22,667,000	32,053,000	28,720,000
Ceiling test write-down	0	0	40,304,000
Accretion of asset retirement obligation	322,000	2,252,000	2,515,000
Share based compensation expense	966,000	1,447,000	1,444,000
Amortization costs and other	1,138,000	554,000	2,106,000
Non-cash PIK interest	2,961,000	22,895,000	5,722,000
Non-cash reorganization items	534,000	0	0
Gain on asset sale	(863,000)	(3,364,000)	(3,169,000)
Costs incurred to issue 2021 Notes and 2021 PIK Notes	0	0	10,139,000
Gain on extinguishment of debt	0	(403,000)	0
Changes in working capital accounts:
Revenue receivable	8,976,000	(5,046,000)	(3,818,000)
Joint interest billing receivable	2,653,000	610,000	41,400,000
Accounts payable and accrued liabilities	(14,458,000)	2,970,000	(72,760,000)
Advances from co-owners	290,000	(600,000)	(13,788,000)
Net refund (deposit) of surety bonds	4,488,000	(2,037,000)	(6,162,000)
Other	(1,429,000)	408,000	1,102,000
Net cash provided by (used in) operating activities	18,849,000	44,153,000	(56,598,000)
Cash flows used in investing activities:
Investment in oil and gas properties	(20,559,000)	(64,613,000)	(30,366,000)
Investment in other property and equipment	28,000	(54,000)	(24,000)
Sale of oil and gas properties	(6,478,000)	10,707,000	25,482,000
Sale of unevaluated oil and gas properties	7,750,000	0	0
Net cash used in investing activities	(19,259,000)	(53,960,000)	(4,908,000)
Cash flows provided by (used in) financing activities:
Net payments for share based compensation	43,000	(26,000)	11,000
Deferred financing costs	(386,000)	(174,000)	(3,156,000)
Payment of preferred stock dividend	0	0	(1,285,000)
Proceeds from borrowings	52,500,000	20,000,000	10,000,000
Repayment of borrowings	(32,500,000)	0	0
Redemption of 2017 Notes	0	(22,650,000)	(53,626,000)
Costs incurred to issue 2021 Notes and 2021 PIK Notes	0	0	(10,139,000)
Costs incurred to redeem 2021 Notes	(11,000)	0	0
Net cash provided by (used in) financing activities	19,646,000	(2,850,000)	(58,195,000)
Net increase (decrease) in cash and cash equivalents	19,236,000	(12,657,000)	(119,701,000)
Cash and cash equivalents, beginning of period	15,655,000	28,312,000	148,013,000
Cash and cash equivalents, end of period	34,891,000	15,655,000	28,312,000
Cash paid (received) during the period for:
Interest	5,341,000	7,432,000	33,206,000
Income taxes	38,000	(94,000)	(18,000)
Reorganization items	$ 980,000	$ 0	$ 0

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands	Total	Common Stock	Preferred Stock	Paid-In Capital	Other Comprehensive Income (Loss)	Accumulated Deficit
Beginning balance at Dec. 31, 2015	$ (163,067)	$ 16	$ 1	$ 290,432	$ 947	$ (454,463)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of shares in debt exchange	12,525	5		12,520
Retirement of shares upon vesting of restricted stock	(200)	0		(200)
Share-based compensation expense	1,444			1,444
Issuance of shares under employee stock purchase plan	145			145
Derivative fair value adjustment, net of tax	(5,697)				(5,697)
Preferred stock dividend	(5,349)					(5,349)
Net loss	(90,896)					(90,896)
Ending balance at Dec. 31, 2016	(251,095)	21	1	304,341	(4,750)	(550,708)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of shares	7,446	5		7,441
Retirement of shares upon vesting of restricted stock	(10)	0		(10)
Share-based compensation expense	1,447			1,447
Issuance of shares under employee stock purchase plan	25			25
Derivative fair value adjustment, net of tax	5,028				5,028
Preferred stock dividend	(5,139)					(5,139)
Net loss	(6,637)					(6,637)
Ending balance at Dec. 31, 2017	(248,935)	26	1	313,244	278	(562,484)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of shares	(11)	0		(11)
Share-based compensation expense	992			992
Issuance of shares under employee stock purchase plan	43			43
Derivative fair value adjustment, net of tax	(337)				(278)	(59)
Preferred stock dividend	(4,371)					(4,371)
Net loss	(9,548)					(9,548)
Ending balance at Dec. 31, 2018	$ (262,167)	$ 26	$ 1	$ 314,268	$ 0	$ (576,462)

Organization and Summary of Sig

Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Summary of Significant Accounting Policies	Organization and Summary of Significant Accounting Policies PetroQuest Energy, Inc. (a Delaware corporation) (“PetroQuest”) is an independent oil and gas company headquartered in Lafayette, Louisiana with an exploration office in The Woodlands, Texas. It is engaged in the exploration, development, acquisition and operation of oil and gas properties in Texas and Louisiana. To facilitate our financial statement presentations, we refer to the post-emergence reorganized company in these consolidated financial statements and footnotes as the “Successor” for periods subsequent to February 8, 2019, and to the pre-emergence company as “Predecessor” for periods prior to February 8, 2019. As discussed in “Note 2-Voluntary Reorganization under Chapter 11 of the Bankruptcy Code” the Company and its wholly owned direct and indirect subsidiaries filed voluntary petitions for bankruptcy relief and subsequently operated as debtors in possession, in accordance with the applicable provisions of the Bankruptcy Code, until emergence on February 8, 2019. Principles of Consolidation The consolidated financial statements include the accounts of PetroQuest and its subsidiaries, PetroQuest Energy, L.L.C., PetroQuest Oil & Gas, L.L.C, Pittrans, Inc. and TDC Energy LLC (collectively, the "Company"). All intercompany accounts and transactions have been eliminated. Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States ("US GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Estimates of proved oil and gas reserves and future net cash flows from estimated proved reserves are based on geological and engineering data and depend upon a number of variable factors and assumptions. Changes in estimated proved oil and gas reserves used in the calculation of depreciation, depletion and amortization of oil and gas properties or the present value of the estimated future net cash flows from estimated proved reserves used in the ceiling test could have a material impact on future results of operations. Bankruptcy Accounting and Financial Reporting The consolidated financial statements have been prepared in accordance with Accounting Standards Codification ("ASC") 852, Reorganizations , for the period subsequent to the bankruptcy filing. ASC 852 requires that the consolidated financial statements distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Accordingly, certain expenses, gains and losses that are realized or incurred in the Chapter 11 Cases (as defined below) are recorded as reorganization items on the consolidated statement of operations. In addition, the pre-petition obligations that may be impacted by the bankruptcy reorganization process are classified on the consolidated balance sheet in liabilities subject to compromise. These liabilities are reported at the amounts expected to be allowed by the Bankruptcy Court (as defined below), even if they may be settled for lesser amounts. Oil and Gas Properties The Company utilizes the full cost method of accounting, which involves capitalizing all acquisition, exploration and development costs incurred for the purpose of finding oil and gas reserves including the costs of drilling and equipping productive wells, dry hole costs, lease acquisition costs and delay rentals. The Company also capitalizes the portion of general and administrative costs that can be directly identified with acquisition, exploration or development of oil and gas properties. Unevaluated property costs are transferred to evaluated property costs at such time as wells are completed on the properties, the properties are sold, or management determines these costs to have been impaired. Interest is capitalized on unevaluated property costs. Transactions involving sales of reserves in place are recorded as adjustments to accumulated depreciation, depletion and amortization with no gain or loss recognized, unless such adjustments would cause a significant alteration in the relationship between capitalized costs and proved reserves. Depreciation, depletion and amortization of oil and gas properties is computed using the unit-of-production method based on estimated proved reserves. All costs associated with evaluated oil and gas properties, including an estimate of future development costs associated therewith, are included in the depreciable base. The costs of investments in unevaluated properties are excluded from this calculation until the related properties are evaluated, proved reserves are established or the properties are determined to be impaired. Proved oil and gas reserves are estimated annually by independent petroleum engineers. The capitalized costs of proved oil and gas properties cannot exceed the present value of the estimated net future cash flows from proved reserves based on historical twelve-month, first day of the month, average oil, gas and natural gas liquid prices, including the effect of hedges in place (the full cost ceiling). If the capitalized costs of proved oil and gas properties exceed the full cost ceiling, the Company is required to write-down the value of its oil and gas properties to the full cost ceiling amount. The Company follows the provisions of Staff Accounting Bulletin (“SAB”) No. 106, regarding the application of ASC Topic 410-20 by companies following the full cost accounting method. SAB No. 106 indicates that estimated future dismantlement and abandonment costs that are recorded on the balance sheet are to be included in the costs subject to the full cost ceiling limitation. The estimated future cash outflows associated with settling the recorded asset retirement obligations are excluded from the computation of the present value of estimated future net revenues used in applying the ceiling test. Cash and Cash Equivalents The Company considers all highly liquid investments with a stated maturity of three months or less to be cash and cash equivalents. The majority of the Company’s cash and cash equivalents are in overnight securities made through its commercial bank accounts, which result in available funds the next business day. Accounts Receivable In its capacity as operator, the Company incurs drilling and operating costs that are billed to its partners based on their respective working interests. Other Property and Equipment The costs related to other furniture and fixtures are depreciated on a straight line basis over estimated useful lives ranging from three to five years. Deposit For Surety Bonds The deposit for surety bonds of $3.6 million and $8.3 million at December 31, 2018 and 2017 , respectively, represent cash collateral paid with respect to the Company's surety bonds which secured its offshore decommissioning obligations. The Company received a refund of the majority of the remaining deposits during March 2019. Income Taxes The Company accounts for income taxes in accordance with ASC Topic 740. Provisions for income taxes include deferred taxes resulting primarily from temporary differences due to different reporting methods for oil and gas properties for financial reporting purposes and income tax purposes. For financial reporting purposes, all exploratory and development expenditures are capitalized and depreciated, depleted and amortized on the unit-of-production method. For income tax purposes, only the equipment and leasehold costs relative to successful wells are capitalized and recovered through depreciation or depletion. Generally, most other exploratory and development costs are charged to expense as incurred; however, the Company may use certain provisions of the Internal Revenue Code that allow capitalization of intangible drilling costs. Other financial and income tax reporting differences occur primarily as a result of statutory depletion. Deferred tax assets are assessed for realizability and a valuation allowance is established for any portion of the asset for which it is more likely than not will not be realized. Revenue Recognition The Company records natural gas and oil revenue in accordance with Accounting Standards Update ("ASU") 2014-09 "Revenue from Contracts with Customers". The core principle of ASU 2014-09 is that an entity will recognize revenue when it transfers control of goods or services to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods and or services. The Company's sources of revenue are oil, natural gas and natural gas liquids ("NGL") production from its oil and gas properties. Oil and natural gas production is typically sold to purchasers through monthly contracts at negotiated sales prices based on published market indices. The sale takes place at the wellhead for oil production and at the wellhead or gas processing plant for natural gas. NGL production is sold once natural gas is processed and the related liquids are removed at the processing plant. The contracts for sale of NGL production are with the processing plant with prices based on what the processing plant is able to receive from third party purchasers. Sales of oil, natural gas and NGL production are recognized when the product is delivered and title transfers to the purchaser and payment is generally received one to two months after the sale has occurred. The Company had $6.4 million of revenue receivable at December 31, 2018 , comprised of $1.1 million of oil revenue, $4.8 million of natural gas revenue and $0.5 million of NGL revenue. The following table includes a disaggregation of revenue by product including the effects of hedges in place (in thousands): Year Ended December 31, 2018 2017 2016 Total oil sales $ 21,027 $ 31,258 $ 20,614 Total gas sales 50,768 60,922 37,963 Total ngl sales 15,303 16,107 8,090 Total oil and gas sales $ 87,099 $ 108,287 $ 66,667 Concentrations The Company’s production is sold on month to month contracts at prevailing prices. The Company attempts to diversify its sales among multiple purchasers and obtain credit protection such as letters of credit and parental guarantees when necessary. The following table identifies customers from whom the Company derived 10% or more of its oil and gas revenues during the years presented. Based on the availability of other customers, the Company does not believe the loss of any of these customers would have a significant effect on its business or financial condition. Year Ended December 31, 2018 2017 2016 Superior Natural Gas 26% 29% 14% Shell Trading Company 21% 24% 23% Texla Energy Management 16% (a) (a) Harvest Pipeline Company 12% (a) (a) Laclede Energy Resources (a) (a) 17% BG Group (a) (a) 10% (a) Less than 10 percent Derivative Instruments Under ASC Topic 815, the nature of a derivative instrument must be evaluated to determine if it qualifies for hedge accounting treatment. Instruments qualifying for hedge accounting treatment are recorded as an asset or liability measured at fair value and subsequent changes in fair value are recognized in stockholders’ equity through other comprehensive income (loss), net of related taxes, to the extent the hedge is effective. If a hedge becomes ineffective because the hedged production does not occur, or the hedge otherwise does not qualify for hedge accounting treatment, the changes in the fair value of the derivative are recorded in the statement of operations as derivative income (expense). The Company does not offset fair value amounts recognized for derivative instruments. The Company’s hedges are specifically referenced to NYMEX prices for oil and natural gas. The effectiveness of hedges is evaluated at the time the contracts are entered into, as well as periodically over the life of the contracts, by analyzing the correlation between NYMEX prices and the posted prices received from the designated production. Through this analysis, the Company is able to determine if a high correlation exists between the prices received for its designated production and the NYMEX prices at which the hedges will be settled. At December 31, 2018 , the Company had no derivative instruments in place. See Note 8 for further discussion of the Company’s derivative instruments. Recently Issued Accounting Standards In February 2016, the Financial Accounting Standards Board ("FASB") issued ASU 2016-02, " Leases (Topic 842), " to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. This ASU supersedes the lease requirements in Topic 840, Leases , and requires that a lessee recognize a right-of-use asset and lease liability for leases that do not meet the definition of a short-term lease. The right-of-use asset and lease liability are to be measured on the balance sheet at the present value of the lease payments. For income statement purposes, ASU 2016-02 retains a dual model requiring leases to be classified as either operating or finance within the Company’s consolidated statements of operations. Lease costs for operating leases are recognized as a single lease cost, calculated so that the cost of the lease is allocated over the lease term on a straight-line basis. For finance leases, interest expense is recognized on the lease liability separately from amortization of the right-to-use asset. ASU 2016-02 does not apply to mineral leases for oil and natural gas properties, but does apply to equipment used to explore and develop oil and natural gas reserves. This ASU is effective for fiscal years beginning after December 15, 2018, including the first quarter of 2019. The Company will adopt this standard using the modified retrospective method applied to all leases that exist on January 1, 2019. The Company made certain elections allowing it not to reassess contracts that commenced prior to adoption and to not recognize right-of-use assets or lease liabilities for short-term leases. Upon adoption, the Company expects the right-to-use asset and lease liability reported on its consolidated financial statements to be immaterial. In August 2017, the FASB issued ASU 2017-12, "Derivative and Hedging," to improve the financial reporting of hedging relationships to better portray the economic results of an entity's risk management activities in its consolidated financial statements and make certain targeted improvements to simplify the application of the hedge accounting guidance in current US GAAP. ASU 2017-12 is effective for public entities for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years, with earlier application permitted. The Company is currently evaluating the effect that this new standard may have on its consolidated financial statements.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures Divestitures: On April 17, 2017 , the Company completed the sale of its interest in the East Lake Verret field in Louisiana for approximately $2.2 million . On December 15, 2017 , the Company completed the sale of its saltwater disposal assets in East Texas for approximately $8.5 million . These sales were accounted for as adjustments to the capitalized costs of oil and gas properties. On January 31, 2018 , the Company sold its Gulf of Mexico properties. The Company received no consideration from the sale of these properties and was required to contribute approximately $3.8 million towards the future abandonment costs for the properties. As a result of the sale, the Company extinguished approximately $28.2 million of its discounted asset retirement obligations. In connection with the sale, the Company received net cash refunds during 2018 totaling $4.5 million related to a depositary account that served to collateralize a portion of the Company's offshore bonds related to these properties. The Company received the majority of the remaining $3.6 million during March 2019, which is included in deposits for surety bonds on the consolidated balance sheet as of December 31, 2018 . This sale was accounted for as an adjustment to the capitalized costs of oil and gas properties. Acquisitions: On December 20, 2017 , the Company entered into an oil focused play in central Louisiana targeting the Austin Chalk formation through the execution of agreements to acquire interests in approximately 24,600 gross acres. The Company has invested approximately $15.0 million in acquisition, engineering and geological costs as of December 31, 2018 and issued 2.0 million shares of Predecessor common stock with respect to these interests.

Voluntary Reorganization under

Voluntary Reorganization under Chapter 11 of the Bankruptcy Code	12 Months Ended
	Dec. 31, 2018
Reorganizations [Abstract]
Voluntary Reorganization under Chapter 11 of the Bankruptcy Code	Voluntary Reorganization under Chapter 11 of the Bankruptcy Code The Company's overall liquidity position and cash available for capital expenditures have been negatively impacted by weak natural gas prices, declining production and increasing cash interest expense on its outstanding indebtedness. In addition, beginning with the August 15, 2018 interest payment on the Company's 2021 PIK Notes (as defined below), the Company was required to pay interest on its 2021 PIK Notes at 10% in cash (instead of 1% in cash and 9% in payment in kind). The Company elected not to pay the cash interest payments that were due on August 15, 2018 under the Company's 2021 PIK Notes and 2021 Notes (as defined below) which totaled approximately $14.2 million (see Note 10 for additional information). As a result of the forgoing, the Company engaged in discussions and negotiations with the lenders under the Multidraw Term Loan (as defined below), certain holders of the Company’s 2021 Notes and 2021 PIK Notes, and their legal and financial advisors regarding various alternatives with respect to the Company’s capital structure and financial position, including the significant amount of indebtedness, and the August 15, 2018 interest payments overdue on the Company’s 2021 Notes and 2021 PIK Notes. As a result of the forgoing discussions and negotiations, on November 6, 2018 (the “Petition Date”), the Company, PetroQuest Energy, L.L.C. (“PQE”) and their direct and indirect wholly owned subsidiaries (collectively, the “Debtors”) filed voluntary petitions (collectively, the “Petition,” and the cases commenced thereby, the “Chapter 11 Cases”) seeking relief under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”). In connection with the Chapter 11 filing, on the Petition Date, the Debtors entered into a restructuring support agreement (the “Restructuring Support Agreement”) with (i) holders of 81.83% of the Company's 10% Second Lien Senior Secured Notes due 2021 (the “2021 Notes”) issued under that certain Indenture dated as of February 17, 2016 , among the Company, the Subsidiary Guarantors (as defined therein) and Wilmington Trust, National Association, as trustee and collateral trustee thereunder, (ii) holders of 84.76% of the Company’s 10% Second Lien Senior Secured PIK Notes due 2021 (the “2021 PIK Notes”) issued under that certain Indenture dated as of September 27, 2016 , among the Company, the Subsidiary Guarantors (as defined therein) and Wilmington Trust, National Association, as indenture trustee and collateral trustee thereunder, and (iii) each of the lenders, or investment advisors or managers for the account of each of the lenders under the multidraw term loan agreement (the "Multidraw Term Loan Agreement"), by and among PQE, the Company, Wells Fargo Bank, National Association, as administrative agent, and lenders holding Term Loans (as defined therein) party thereto from time to time, pursuant to which such parties agreed to support the Plan (as defined below). On January 31, 2019, the Court entered an order (the “Confirmation Order”) confirming the Debtors’ First Amended Chapter 11 Plan of Reorganization, as Immaterially Modified as of January 28, 2019 (as amended, modified or supplemented from time to time, the “Plan”) under Chapter 11 of the Bankruptcy Code. On February 8, 2019 (the “Effective Date”), the Plan became effective in accordance with its terms and the Debtors emerged from the Chapter 11 Cases. On the Effective Date, TDC Energy, LLC, Pittrans, Inc. and Sea Harvester Energy Development, L.L.C. were dissolved. The remaining Debtors (collectively, the "Reorganized Debtors") continue in existence. On the Effective Date and pursuant to the terms of the Plan and the Confirmation Order, the Company: • Adopted an amended and restated certificate of incorporation and bylaws; • Appointed four new members to the Successor’s board of directors to replace all of the directors of the Predecessor, other than the director also serving as Chief Executive Officer, who was re-appointed pursuant to the Plan; • Cancelled all of the Predecessor’s common stock and 6.875% Series B Cumulative Convertible Perpetual Preferred Stock with the former holders thereof not receiving any consideration in respect of such stock; • Issued to the former holders of the Predecessor’s 2021 Notes and 2021 PIK Notes, (collectively, the “Old Notes”), in exchange for the cancellation and discharge of the Old Notes: ◦ 8,900,000 shares of the Successor’s Class A Common Stock; and ◦ $80 million of the Successor’s 10% Senior Secured PIK Notes due 2024 (the “2024 PIK Notes”); • Issued 300,000 shares of the Successor’s Class A Common Stock to certain former holders of the Old Notes for their commitment to backstop the Exit Facility (as defined below); • Issued to the Class B Holder (as defined in the Successor’s amended and restated certificate of incorporation) one share of the Successor’s Class B Common Stock, which confers certain rights to elect directors and certain drag-along rights; • Issued to the Class C Holder (as defined in the Successor’s amended and restated certificate of incorporation) one share of the Successor’s Class C Common Stock, which confers certain rights to elect directors and certain drag-along rights; • Entered into a new $50 million senior secured Term Loan Agreement (the “Exit Facility”) upon the repayment and termination of the Predecessor’s Multidraw Term Loan Agreement; • Entered into a registration rights agreement (the “Registration Rights Agreement”) with certain holders of the Successor’s Class A Common Stock and 2024 PIK Notes; and • Adopted a new management incentive plan (the “2019 Long Term Incentive Plan”) for officers, directors and employees of the Successor and its subsidiaries, pursuant to which 1,344,000 shares of the Successor’s Class A Common Stock were reserved for issuance. The foregoing is a summary of the substantive provisions of the Plan and related transactions and is not intended to be a complete description of, or a substitute for a full and complete reading of, the Plan and the other documents referred to above. Effect of Filing on Creditors Subject to certain exceptions, under the Bankruptcy Code, the filing of the Petition automatically enjoined, or stayed, the continuation of most judicial or administrative proceedings or filing of other actions against the Debtors or their property to recover, collect or secure a claim arising prior to the Petition Date. Absent an order of the Bankruptcy Court, substantially all of the Debtors’ pre-petition liabilities are subject to settlement in the Bankruptcy Court. Although the filing of the Petition triggered defaults on the Debtors’ debt obligations, creditors were stayed from taking any actions against the Debtors as a result of such defaults, subject to certain limited exceptions permitted by the Bankruptcy Code. Rejection of Executory Contracts Subject to certain exceptions, under the Bankruptcy Code, the Debtors may assume, assign or reject certain executory contracts and unexpired leases subject to the approval of the Bankruptcy Court and satisfaction of certain other conditions. Generally, the rejection of an executory contract or unexpired lease is treated as a pre-petition breach of such executory contract or unexpired lease and, subject to certain exceptions, relieves the Debtors of performing their future obligations under such executory contract or unexpired lease but entitles the contract counterparty or lessor to a pre-petition general unsecured claim for damages caused by such deemed breach. Counterparties to such rejected contracts or leases may assert unsecured claims in the Bankruptcy Court against the applicable Debtor's estate for damages. Generally, the assumption of an executory contract or unexpired lease requires the Debtors to cure existing monetary defaults under such executory contract or unexpired lease and provide adequate assurance of future performance. Accordingly, any description of an executory contract or unexpired lease with any of the Debtors, including where applicable a quantification of the Company’s obligations under any such executory contract or unexpired lease with the applicable Debtor, is qualified by any rights the Company has under the Bankruptcy Code. Further, nothing herein is or shall be deemed an admission with respect to any claim amounts or calculations arising from the rejection of any executory contract or unexpired lease and the Debtors expressly preserve all of their rights with respect thereto. Debtor-In-Possession During the pendency of the Chapter 11 Cases, the Debtors operated as debtors-in-possession in accordance with the applicable provisions of the Bankruptcy Code. In general, as debtors-in-possession under the Bankruptcy Code, the Debtors were authorized to continue to operate as an ongoing business, but were not permitted to engage in transactions outside the ordinary course of business without the prior approval of the Bankruptcy Court. Pursuant to motions filed with the Bankruptcy Court that were designed primarily to mitigate the impact of the Chapter 11 Cases on our operations, customers and employees, the Bankruptcy Court authorized the Debtors to conduct their business activities in the ordinary course, including, among other things and subject to the terms and conditions of such orders, authorizing the Debtors to: (i) pay employees' wages and related obligations; (ii) continue to operate their cash management system in a form substantially similar to pre-petition practice; (iii) continue to honor certain obligations related to our royalty obligations; and (iv) pay taxes in the ordinary course. Reorganization Items The Debtors have incurred costs associated with the reorganization, primarily legal and professional fees. In accordance with applicable guidance, costs associated with the bankruptcy proceedings have been recorded as reorganization items within the consolidated statement of operations for the year ended December 31, 2018 . Reorganization items included $3.8 million related to post petition professional fees and $0.5 million related to adjustments to certain claims relating to the Chapter 11 Cases and to the carrying value of debt classified as liabilities subject to compromise. Liabilities Subject to Compromise The consolidated balance sheet as of December 31, 2018 includes amounts classified as liabilities subject to compromise, which represent liabilities which have been allowed as claims in the Chapter 11 Cases. These amounts represent the Debtors' current estimate of known or potential obligations to be resolved in connection with the Chapter 11 Cases, and may differ from actual future settlement amounts paid. Differences between liabilities estimated and claims filed, or to be filed, will be investigated and resolved in connection with the claims resolution process. Liabilities subject to compromise at December 31, 2018 consisted of the following (in thousands): December 31, 2018 10% Senior PIK Notes due 2021 $ 275,046 10% Senior Notes due 2021 9,427 Accrued interest 20,624 Accounts payable to vendors 874 Other long-term liabilities 510 Other accrued liabilities 2,724 Preferred stock dividend payable 14,649 Liabilities subject to compromise $ 323,854

Equity

Equity	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Equity	Equity As discussed in “Note 2-Voluntary Reorganization under Chapter 11 of the Bankruptcy Code,” on the Effective Date and pursuant to the terms of the Plan and the Confirmation Order, all of the Predecessor’s common stock and 6.875% Series B Cumulative Convertible Perpetual Preferred Stock was canceled with the former holders thereof not receiving any consideration in respect thereof. Accordingly, the following discussion relates solely to the Predecessor’s common stock and 6.875% Series B Cumulative Convertible Perpetual Preferred Stock prior to such cancellation. Common Stock During December 2017, the Company issued 2.0 million shares of common stock in connection with the acquisition of Austin Chalk acreage (see Note 3). Additionally, during December 2017, the Company issued approximately 2.2 million shares of common stock related to the extinguishment of a portion of the outstanding 2021 Notes (see Note 10). Convertible Preferred Stock The Company had 1,495,000 shares of 6.875% Series B Cumulative Convertible Perpetual Preferred Stock (the “Series B Preferred Stock”) outstanding as of December 31, 2018 and 2017 , all of which were canceled on the Effective Date pursuant to the Plan. The following is a summary of certain terms of the Series B Preferred Stock: Dividends . The Series B Preferred Stock accumulated dividends at an annual rate of 6.875% for each share of Series B Preferred Stock. Dividends were cumulative from the date of first issuance and, to the extent payment of dividends was not prohibited by the Company’s debt agreements, assets were legally available to pay dividends and the Company’s board of directors or an authorized committee of the board declared a dividend payable, the Company paid dividends in cash, every quarter. In connection with an amendment to the Company's prior bank credit facility (which was replaced by the Old Loan Agreement (as defined below) in October 2016 and the Multidraw Term Loan Agreement in August 2018) prohibiting the Company from declaring or paying dividends on the Series B Preferred Stock, the Company suspended the quarterly cash dividend on the Series B Preferred Stock beginning with the dividend payment due on April 15, 2016. The Old Loan Agreement prohibited, and the Multidraw Term Loan Agreement also prohibited the Company from declaring and paying cash dividends on the Series B Preferred Stock. Under the terms of the Series B Preferred Stock, any unpaid dividends accumulated. As of December 31, 2018 , the Company had deferred eleven quarterly dividend payments and had accrued a $14.6 million payable related to the eleven deferred quarterly dividends and the quarterly dividend that accrued through the bankruptcy filing date. The accrued dividend payable is included in liabilities subject to compromise on the consolidated balance sheet. Mandatory conversion . The Company could, at its option, cause shares of the Series B Preferred Stock to be automatically converted at the applicable conversion rate, but only if the closing sale price of the Company’s common stock for 20 trading days within a period of 30 consecutive trading days ending on the trading day immediately preceding the date the Company gave the conversion notice equaled or exceeded 130% of the conversion price in effect on each such trading day. Conversion rights . Each share of Series B Preferred Stock could be converted at any time, at the option of the holder, into 0.8608 shares of the Company’s common stock (which is based on an initial conversion price of approximately $58.08 per share of common stock, subject to further adjustment) plus cash in lieu of fractional shares, subject to the Company’s right to settle all or a portion of any such conversion in cash or shares of the Company’s common stock. If the Company elected to settle all or any portion of its conversion obligation in cash, the conversion value and the number of shares of the Company’s common stock it would have delivered upon conversion (if any) would be based upon a 20 trading day averaging period. Upon any conversion, the holder would not receive any cash payment representing accumulated and unpaid dividends on the Series B Preferred Stock, whether or not in arrears, except in limited circumstances. The conversion rate was equal to $50 divided by the conversion price at the time. The conversion price was subject to adjustment upon the occurrence of certain events.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share A reconciliation between the basic and diluted earnings per share computations (in thousands, except per share amounts) is as follows: For the Year Ended December 31, 2018 Loss(Numerator) Shares Per BASIC EPS Net loss available to common stockholders $ (13,919 ) 25,581 $ (0.54 ) Stock options — — Attributable to participating securities — — DILUTED EPS $ (13,919 ) 25,581 $ (0.54 ) For the Year Ended December 31, 2017 Loss(Numerator) Shares Per BASIC EPS Net loss available to common stockholders $ (11,776 ) 21,330 $ (0.55 ) Stock options — — Attributable to participating securities — — DILUTED EPS $ (11,776 ) 21,330 $ (0.55 ) For the Year Ended December 31, 2016 Loss(Numerator) Shares Per BASIC EPS Net loss available to common stockholders $ (96,245 ) 18,354 $ (5.24 ) Stock options — — Attributable to participating securities — — DILUTED EPS $ (96,245 ) 18,354 $ (5.24 ) An aggregate of 2.0 million , 1.6 million and 0.9 million shares of common stock representing options to purchase common stock and unvested shares of restricted common stock for the years ended December 31, 2018 , 2017 and 2016 , respectively, and common shares issuable upon the assumed conversion of the Series B Preferred Stock totaling 1.3 million shares for each of the periods presented were not included in the computation of diluted earnings per share for the years ended December 31, 2018 , 2017 and 2016 , respectively, because the inclusion would have been anti-dilutive as a result of the net loss reported for the year.

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation As discussed in “Note 2-Voluntary Reorganization under Chapter 11 of the Bankruptcy Code”, on the Effective Date and pursuant to the terms of the Plan and the Confirmation Order, all of the Predecessor’s common stock (and any share-based compensation based on such common stock) was canceled with the former holders thereof not receiving any consideration in respect thereof. The Predecessor's share-based compensation plan was also terminated on the Effective Date. Accordingly, the following discussion relates solely to the Predecessor’s share-based compensation plan and share-based compensation issued and outstanding prior to such cancellation. The Company accounts for share-based compensation in accordance with ASC Topic 718. Share-based compensation cost is recognized over the requisite service period. Compensation cost for awards with graded vesting is recognized using the accelerated attribution method. Share-based compensation cost is reflected as a component of general and administrative expenses. A detail of share-based compensation cost for the years ended December 31, 2018 , 2017 and 2016 is as follows (in thousands): Year Ended December 31, 2018 2017 2016 Stock options: Incentive Stock Options (share settled) $ 407 $ 820 $ 206 Non-Qualified Stock Options (share settled) 94 387 164 Restricted stock (share settled) 465 197 1,073 Cash settled stock units (241 ) 245 244 Share-based compensation $ 725 $ 1,649 $ 1,687 During the years ended December 31, 2017 and 2016 , the Company capitalized $103,000 and $106,000 , respectively, of compensation cost related to cash settled restricted stock units to oil and gas properties. No such amounts were capitalized during the year ended December 31, 2018 . During the years ended December 31, 2018 , 2017 and 2016 , the Company recorded income tax benefits of approximately $101,000 , $270,000 and $512,000 , respectively, related to share-based compensation expense recognized during those periods. As a result of the adoption of ASU 2016-09 during the year ended December 31, 2017 , the Company recognized an additional deferred tax asset of $4.7 million related to net operating loss carryforwards for excess tax benefits on share-based compensation that did not meet the criteria for recognition under previous guidance. Share-Based compensation settled in shares At December 31, 2018 , the Company had $0.4 million of unrecognized compensation cost related to unvested restricted stock and stock options. Stock Options Stock options may be granted to employees and consultants and generally vest ratably over a three -year period. Stock options may also be granted to directors and generally vest one year or less from the date of grant to align with their term on the board. Stock options must be exercised within 10 years of the grant date. The exercise price of each option may not be less than the fair market value of a share of common stock on the date of grant. Upon a change in control of the Company, all outstanding options become immediately exercisable. The Company computes the fair value of its stock options using the Black-Scholes option-pricing model assuming an expected term based on historical activity and expected volatility computed using historical stock price fluctuations on a weekly basis for a period of time equal to the expected term of the option. Periodically, the Company adjusts compensation expense based on the difference between actual and estimated forfeitures. The following table outlines the assumptions used in computing the fair value of stock options granted during 2017 and 2016 . No such grants were made during 2018 . 2017 2016 Dividend yield —% —% Expected volatility 80.44% 62.0%-79.99% Risk-free rate 1.925% 1.255%-2.09% Expected term 6 years 6 years Stock options granted 219,130 1,168,754 Wgtd. avg. grant date fair value per share $1.28 $1.96 Fair value of grants $280,000 $2,293,000 The following table details stock option activity during the year ended December 31, 2018 : Number of Options Wgtd. Avg. Exercise Price Wgtd. Avg. Remaining Life Aggregate Intrinsic Value (000’s) Outstanding at beginning of year 1,608,646 $ 6.20 Granted — — Expired/cancelled/forfeited (121,823 ) 4.98 Exercised — — Outstanding at end of year 1,486,823 6.34 7.03 $ — Options exercisable at end of year 1,047,590 $ 7.78 6.64 $ — The total fair value of stock options that vested during the years ended December 31, 2018 , 2017 and 2016 was $1.2 million , $1.6 million and $0.4 million , respectively. The intrinsic value of stock options exercised was immaterial for all periods presented. The following table summarizes information regarding stock options outstanding at December 31, 2018 : Range of Options Wgtd. Avg. Wgtd. Avg. Options Wgtd. Avg. Exercise Outstanding Remaining Exercise Exercisable Exercise Price 12/31/2018 Contractual Life Price 12/31/2018 Price $0.00-$2.37 250,477 8.43 $1.99 105,780 $2.07 $3.17-$4.36 1,013,663 7.68 $3.37 719,127 $3.36 $16.72-$19.52 68,190 4.42 $17.11 68,190 $17.11 $20.40-$30.32 154,493 1.73 $28.15 154,493 $28.15 1,486,823 1,047,590 $7.78 Restricted Stock The Company computes the fair value of its service based restricted stock using the closing price of the Company’s stock at the date of grant. Restricted stock granted to employees generally vests ratably over a three -year period. Restricted stock granted to directors vests one year or less from the date of grant to align with their term on the board. Upon a change in control of the Company, all outstanding shares of restricted stock will become immediately vested. The following table details restricted stock activity during the year ended December 31, 2018 : Number of Shares Wgtd. Avg. Fair Value per Share Outstanding at beginning of year 487,502 $1.87 Cancelled/forfeited (34,946 ) $1.85 Lapse of restrictions (37,500 ) $2.15 Outstanding at December 31, 2018 415,056 $1.85 The weighted average grant date fair value of restricted stock granted during the year ended December 31, 2017 was $1.87 per share. No restricted stock was granted in 2018 and 2016. The total fair value of restricted stock that vested during the years ended December 31, 2018 , 2017 and 2016 was $0.1 million , $1.3 million and $2.4 million , respectively. Share-Based compensation settled in cash Restricted Stock Units The Company may grant restricted stock units ("RSUs") to employees that vest ratably over a three -year period. Cash payment will be made to employees on each vesting date based upon the Company's closing stock price on that date. Upon change in control of the Company, all of the RSUs will immediately vest. The Company computes the fair value of the RSUs using the closing price of the Company's stock at the end of each period and records a liability based on the percentage of requisite service rendered at the reporting date. During 2018 and 2017 , the Company paid $24,000 and $59,000 , respectively, to settle 323,374 and 31,703 RSUs, respectively, that vested during the period. Market Based Restricted Stock Units The Company granted 60,767 market based restricted stock units ("MRSUs") to executive officers during November 2014. The executive officers can earn between 0 - 200% of the MRSUs granted based on the Company's performance versus a defined peer group. The 2014 MRSUs vested in one-third increments on each of the first, second and third annual anniversaries starting January 1, 2016. Upon change in control of the Company, all of the MRSUs will immediately vest. The number of MRSUs that ultimately vest is based on the Company's total shareholder return in the last 20 days of the fiscal year in relation to the last 20 days of the previous fiscal year in comparison to a group of 12 selected peer stocks of similar sized companies which operate within the same sector. The performance period ended on December 31, 2015 and executive officers earned 50% of the MRSUs. The MRSUs are cash settled on each vesting date based on the number of MRSUs that vest multiplied by the Company's closing stock price. In November 2017, the Company granted an additional 270,269 MRSUs. The performance period ended on December 31, 2018 for these grants and executive officers earned none of the MRSUs. The Company estimates the fair value of the outstanding MRSUs using a Monte Carlo valuation model and records a liability based on the percentage of requisite service rendered at the reporting date. The Monte Carlo valuation model considers such inputs as the stock prices of the Company and its peer group, a risk-free interest rate, and an estimated volatility for the Company and its peer group. As of December 31, 2018 , the Company had no liability for RSUs outstanding and as of December 31, 2017 , the Company had a liability for RSUs and MRSUs outstanding in the amount of $0.3 million , based upon the closing stock price at December 31, 2018 and December 31, 2017 , respectively. The following table details MRSU and RSU activity during the year ended December 31, 2018 : MRSU RSU Total Outstanding at beginning of year 277,733 889,587 1,167,320 Granted — — — Expired/Cancelled/Forfeited (270,269 ) (78,808 ) (349,077 ) Vested/Paid (7,464 ) (323,374 ) (330,838 ) Outstanding at December 31, 2018 — 487,405 487,405

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	Asset Retirement Obligation The Company accounts for asset retirement obligations in accordance with ASC Topic 410-20, which requires recording the fair value of an asset retirement obligation associated with tangible long-lived assets in the period incurred. Asset retirement obligations associated with long-lived assets included within the scope of ASC Topic 410-20 are those for which there is a legal obligation to settle under existing or enacted law, statute, written or oral contract or by legal construction under the doctrine of promissory estoppel. The Company has legal obligations to plug, abandon and dismantle existing wells and facilities that it has acquired and constructed. The following table summarizes the changes to the Company’s asset retirement obligation (in thousands): Year Ended December 31, 2018 2017 Asset retirement obligation, beginning of period $ 31,310 $ 36,610 Liabilities incurred 7 574 Liabilities settled (863 ) (3,364 ) Accretion expense 322 2,252 Revisions in estimated cash flows (62 ) (4,514 ) Divestiture of oil and gas properties (28,234 ) (248 ) Asset retirement obligation, end of period 2,480 31,310 Less: current portion of asset retirement obligation (183 ) (687 ) Long-term asset retirement obligation $ 2,297 $ 30,623 Divestitures of oil and gas properties during 2018 included $28.2 million as a result of the sale of the Company's Gulf of Mexico assets in January 2018. The liabilities incurred, revisions in estimated cash flows and divestitures represent non-cash investing activities for purposes of the statement of cash flows.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments The Company seeks to reduce its exposure to commodity price volatility by hedging a portion of its production through commodity derivative instruments. When the conditions for hedge accounting are met, the Company may designate its commodity derivatives as cash flow hedges. The changes in fair value of derivative instruments that qualify for hedge accounting treatment are recorded in other comprehensive income (loss) until the hedged oil or natural gas quantities are produced. If a derivative does not qualify for hedge accounting treatment, the changes in the fair value of the derivative are recorded in the statement of operations as derivative income (expense). At December 31, 2017 , all of the Company's outstanding derivative instruments were designated as cash flow hedges. The Company had no outstanding derivative contracts as of December 31, 2018 . Oil and gas sales include additions related to the settlement of gas hedges of $0.8 million , $1.5 million and $1.8 million , for the years ended December 31, 2018 , 2017 and 2016 , respectively. Oil and gas sales include reductions of $1.4 million related to the settlement of oil hedges for the year ended December 31, 2018 . There were no settlements of Ngls for any period presented or oil hedges for the years ended December 31, 2017 and 2016 . On June 14, 2018, the Company's hedging counterparty, Koch Supply & Trading LP, terminated the only outstanding hedge contract resulting in a settlement of $0.5 million . The settlement at the termination date remained in accumulated other comprehensive loss and was reclassified to earnings as the hedged volumes were produced over the original term of the contract. Derivatives designated as hedging instruments: The following tables reflect the fair value of the Company’s effective cash flow hedges in the consolidated financial statements (in thousands): Effect of Cash Flow Hedges on the Consolidated Balance Sheet at December 31, 2017 : Commodity Derivatives Period Balance Sheet Fair Value December 31, 2017 Derivative asset $ 1,174 December 31, 2017 Derivative liability $ (731 ) Effect of Cash Flow Hedges on the Consolidated Statement of Operations for years ended December 31, 2018 , 2017 and 2016 : Instrument Amount of Gain (Loss) Location of Amount of Gain (Loss) Reclassified into Commodity Derivatives at December 31, 2018 $ (990 ) Oil and gas sales $ (622 ) Commodity Derivatives at December 31, 2017 $ 6,654 Oil and gas sales $ 1,461 Commodity Derivatives at December 31, 2016 $ (4,447 ) Oil and gas sales $ 1,811

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements ASC Topic 820 defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date and establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. As presented in the tables below, this hierarchy consists of three broad levels: • Level 1: valuations consist of unadjusted quoted prices in active markets for identical assets and liabilities and has the highest priority; • Level 2: valuations rely on quoted prices in markets that are not active or observable inputs over the full term of the asset or liability; • Level 3: valuations are based on prices or third party or internal valuation models that require inputs that are significant to the fair value measurement and are less observable and thus have the lowest priority. The Company classifies its commodity derivatives based upon the data used to determine fair value. The Company's derivative instruments at December 31, 2017 were in the form of swaps based on NYMEX pricing for oil and natural gas. The fair value of these derivatives was derived using an independent third-party’s valuation model that utilizes market-corroborated inputs that are observable over the term of the derivative contract. The Company’s fair value calculations also incorporate an estimate of the counterparties’ default risk for derivative assets and an estimate of the Company’s default risk for derivative liabilities. As a result, the Company designated its commodity derivatives as Level 2 in the fair value hierarchy. The Company had no outstanding derivative contracts at December 31, 2018 . The following table summarizes the Company’s assets (liabilities) that are subject to fair value measurement on a recurring basis as of December 31, 2017 (in thousands): Fair Value Measurements Using Instrument Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Commodity Derivatives: At December 31, 2017 $ — $ 443 $ — The fair value of the Company's cash and cash equivalents approximated book value at December 31, 2018 and 2017 . The fair value of the Multidraw Term Loan Agreement approximated face value as of December 31, 2018 and 2017 . The fair value of the Company's 2021 Notes and 2021 PIK Notes was determined based upon market quotes provided by an independent broker, which represents a Level 2 input. The fair value of the 2021 Notes was $2.8 million and $7.3 million and the fair value of the 2021 PIK Notes was $82.5 million and $198.7 million as of December 31, 2018 and 2017 , respectively.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Predecessor Long-Term Debt On August 19, 2010, the Company issued $150 million in principal amount of its 10% Senior Notes due 2017. On July 3, 2013, the Company issued an additional $200 million in principal amount of its 10% Senior Notes due 2017 (collectively, the "2017 Notes"). On February 17, 2016, the Company closed a private exchange offer (the "February Exchange") and consent solicitation (the "February Consent Solicitation") to certain eligible holders of its outstanding 2017 Notes. In satisfaction of the tender of $214.4 million in aggregate principal amount of the 2017 Notes, representing approximately 61% of the then outstanding aggregate principal amount of 2017 Notes, the Company (i) paid approximately $53.6 million of cash, (ii) issued $144.7 million aggregate principal amount of its new 10% Second Lien Senior Secured Notes due 2021 (the "2021 Notes") and (iii) issued approximately 1.1 million shares of Predecessor common stock. Following the completion of the February Exchange, $135.6 million in aggregate principal amount of the 2017 Notes remained outstanding. The February Consent Solicitation eliminated or waived substantially all of the restrictive covenants contained in the indenture governing the 2017 Notes. On September 27, 2016 , the Company closed private exchange offers (the "September Exchange") and a consent solicitation (the "September Consent Solicitation") to certain eligible holders of its outstanding 2017 Notes and 2021 Notes. In satisfaction of the consideration of $113.0 million in aggregate principal amount of the 2017 Notes, representing approximately 83% of the then outstanding aggregate principal amount of 2017 Notes, and $130.5 million in aggregate principal amount of the 2021 Notes, representing approximately 90% of the then outstanding aggregate principal amount of 2021 Notes, the Company issued (i) $243.5 million in aggregate principal amount of its new 10% Second Lien Senior Secured PIK Notes due 2021 (the "2021 PIK Notes") and (ii) approximately 3.5 million shares of Predecessor common stock. The Company also paid, in cash, accrued and unpaid interest on the 2017 Notes and 2021 Notes accepted in the September Exchange from the last applicable interest payment date to, but not including, September 27, 2016 . Following the consummation of the September Exchange, there were $22.7 million in aggregate principal amount of the 2017 Notes outstanding and $14.2 million in aggregate principal amount of the 2021 Notes outstanding. The September Consent Solicitation amended certain provisions of the indenture governing the 2021 Notes and amended the registration rights agreement with respect to the 2021 Notes. On March 31, 2017, the Company redeemed the remaining outstanding 2017 Notes at a redemption price of $22.8 million . The redemption was funded by cash on hand and amounts borrowed under the Old Loan Agreement described below. On December 28, 2017, the Company issued 2.2 million shares of Predecessor common stock to extinguish approximately $4.8 million of outstanding principal amount of 2021 Notes. The 2021 PIK Notes accrued interest at a rate of 10% per annum on the principal amount and interest was payable semi-annually in arrears on February 15 and August 15 of each year. The Company was permitted, at its option, for the first three interest payment dates of the 2021 PIK Notes, to instead pay interest at (i) the annual rate of 1% in cash plus (ii) the annual rate of 9% PIK (the "PIK Interest") payable by increasing the principal amount outstanding of the 2021 PIK Notes or by issuing additional 2021 PIK Notes in certificated form. The Company exercised this PIK option in connection with the interest payments due on February 15, 2017, August 15, 2017 and February 15, 2018. The 2021 Notes accrued interest at a rate of 10% per annum on the principal amount and interest was payable semi-annually in arrears on February 15 and August 15 of each year. The February Exchange and September Exchange were accounted for as troubled debt restructurings pursuant to ASC Topic 470-60 "Troubled Debt Restructurings by Debtors." The Company determined that the future undiscounted cash flows from the 2021 PIK Notes issued in the September Exchange through the maturity date exceeded the adjusted carrying amount of the 2017 Notes and the 2021 Notes tendered in the September Exchange. Accordingly, no gain or loss on extinguishment of debt was recognized in connection with the September Exchange. The net shortfall of the remaining carrying value of the 2017 Notes and 2021 Notes tendered as compared to the principal amount of the 2021 PIK Notes issued in the September Exchange of $0.6 million was reflected as part of the carrying value of the 2021 PIK Notes. Such shortfall was being amortized under the effective interest method over the term of the 2021 PIK Notes. The Company previously determined that the future undiscounted cash flows from the 2021 Notes issued in the February Exchange through the maturity date exceeded the adjusted carrying amount of the 2017 Notes tendered in the February Exchange. Accordingly, no gain on extinguishment of debt was recognized in connection with the February Exchange. The excess of the remaining carrying value of the 2017 Notes tendered over the principal amount of the 2021 Notes issued in the February Exchange of $13.9 million was reflected as part of the carrying value of the 2021 Notes. The amount of the excess carrying value attributable to the 2021 Notes tendered in the September Exchange was then reflected as part of the carrying value of the 2021 PIK Notes. The excess carrying value attributable to the remaining 2021 Notes was being amortized under the effective interest method over the term of the 2021 Notes. On October 17, 2016, the Company entered into a multidraw term loan agreement (the "Old Loan Agreement") with Franklin Custodian Funds - Franklin Income Fund, as a lender, and Wells Fargo Bank, National Association, as administrative agent (the "Agent"), replacing the prior credit agreement with JPMorgan Chase Bank, N.A. Effective August 14, 2018, the Company and certain of its subsidiaries entered into a Forbearance Agreement (the "Forbearance Agreement") with the Agent for the lenders with respect to the Old Loan Agreement. Pursuant to the Forbearance Agreement, the Agent and the lenders under the Old Loan Agreement agreed to forbear from taking any action with respect to certain specified events of default occurring under the Old Loan Agreement as a result of non-payment by the Company of interest with respect to the 2021 PIK Notes and 2021 Notes when due and payable on August 15, 2018 under the indentures governing those notes. On August 31, 2018, the Company and PetroQuest Energy, L.L.C. entered into a new Multidraw Term Loan Agreement (the "Multidraw Term Loan Agreement"), which replaced the Old Loan Agreement with the lenders party thereto from time to time (the "Lenders") and the Agent. The Multidraw Term Loan Agreement provided a multi-advance term loan facility in the principal amount of up to $50.0 million . The loans drawn under the Multidraw Term Loan Agreement (collectively, the “Term Loans”) were permitted to be used to repay existing debt, to pay transaction fees and expenses, to provide working capital for exploration and production operations and for general corporate purposes. On August 31, 2018, the Company borrowed $50.0 million under the Term Loans, and repaid $32.5 million of outstanding borrowings under the Old Loan Agreement, plus accrued interest and fees, and retained the balance of the borrowings for general corporate purposes. As of December 31, 2018 , the Company had no borrowing availability under the Multidraw Term Loan Agreement. Effective September 14, 2018, the Company and certain of its subsidiaries entered into a Forbearance Agreement (the "Loan Forbearance Agreement") with the Agent for the lenders with respect to the Multidraw Term Loan Agreement. Pursuant to the Loan Forbearance Agreement, the Agent and Lenders agreed to forbear from taking any action with respect to certain anticipated events of default occurring under the Multidraw Term Loan Agreement as a result of the non-payment of interest with respect to the 2021 Notes and 2021 PIK Notes when due and payable on August 15, 2018, and such non-payment continuing for a period of 30 days under the indentures governing the notes. The Loan Forbearance Agreement was effective from September 14, 2018 until the earlier of (i) 11:59 p.m. Eastern time on September 28, 2018 or (ii) the occurrence of any specified forbearance default, which includes, among other things, any event of default under the Multidraw Term Loan Agreement other than the anticipated events of default or a breach by the Company or certain of its subsidiaries of the Loan Forbearance Agreement. On September 28, 2018, October 5, 2018, October 19, 2018 and October 31, 2018, the Company and certain of its subsidiaries, the Agent and the Lenders entered into first, second, third and fourth amendments to the Loan Forbearance Agreement that extended the September 28, 2018 deadline to 11:59 p.m. Eastern time on each of October 5, 2018, October 19, 2018, October 31, 2018 and November 6, 2018, respectively. The Loan Forbearance Agreement terminated on the commencement of the Chapter 11 Cases described in Note 2. Effective September 14, 2018, the Company and certain of its subsidiaries entered into (i) a Forbearance Agreement (the "2021 Notes Forbearance Agreement") with certain holders (the "2021 Notes Supporting Holders") of approximately $7.3 million in aggregate principal amount (representing approximately 77.9% of the outstanding principal amount) of the 2021 Notes, and (ii) a Forbearance Agreement (the "2021 PIK Notes Forbearance Agreement" and together with the 2021 Notes Forbearance Agreement, the "Notes Forbearance Agreements") with certain holders (the "2021 PIK Notes Supporting Holders" and together with the 2021 Notes Supporting Holders, the "Supporting Holders") of approximately $194.6 million in aggregate principal amount (representing approximately 70.7% of the outstanding principal amount) of the 2021 PIK Notes. Pursuant to the Notes Forbearance Agreements, the Supporting Holders agreed to forbear from exercising their rights and remedies under their respective indentures governing the 2021 Notes and the 2021 PIK Notes or the related security documents with respect to certain anticipated events of default occurring under the indentures as a result of the non-payment by the Company of interest with respect to the 2021 Notes and the 2021 PIK Notes when due and payable on August 15, 2018 and such non-payment continuing for a period of 30 days , until the earlier of (i) 11:59 p.m. Eastern time on September 28, 2018 and (ii) the date the Notes Forbearance Agreements otherwise terminate in accordance with the terms therein (the "Forbearance Period"). Pursuant to the Notes Forbearance Agreements, the Supporting Holders agreed to not deliver any notice or instruction in respect of the exercise of any of the rights and remedies otherwise available under the indentures or the related security documents with respect to such anticipated events of default. The Supporting Holders also agreed to not transfer any ownership in the 2021 Notes and the 2021 PIK Notes held by any of the Supporting Holders during the Forbearance Period other than to potential transferees currently parties to, or who agree in writing to be bound by, the Notes Forbearance Agreements. On September 28,2018, October 5, 2018, October 19, 2018 and October 31, 2018, the Company and certain of its subsidiaries, and the Supporting Holders entered into first, second, third and fourth amendments to the Notes Forbearance Agreements that extended the September 28, 2018 deadline to 11:59 p.m. Eastern time on each of October 5, 2018, October 19, 2018, October 31, 2018 and November 6, 2018, respectively. The Notes Forbearance Agreements terminated on the commencement of the Chapter 11 Cases described in Note 2. The face value of the 2021 Notes and the 2021 PIK Notes, including accrued PIK interest, is classified as liabilities subject to compromise as of December 31, 2018. The Term Loans are reflected net of $0.3 million and $2.0 million of related unamortized deferred financing costs as of December 31, 2018 and 2017 , respectively. The adjustments to write off the remaining unamortized deferred financing costs and carrying value adjustments related to the February Exchange and September Exchange are included in reorganization items in the consolidated statement of operations. Successor Long-Term Debt On the Effective Date and pursuant to the terms of the Plan and the Confirmation Order, the Company entered into the Term Loan Agreement (the “Exit Facility”) with the lenders party thereto and Wells Fargo Bank, National Association, as administrative agent. The Exit Facility provides for a $50 million term loan facility. The proceeds of the Exit Facility were used to repay in full the loans and other obligations under the Multidraw Term Loan Agreement. The maturity date of the Exit Facility is November 8, 2023 . The interest rate per annum is equal to (i) in the case of LIBOR Loans (as defined in the Exit Facility), 7.5% per annum and (ii) in the case of Base Rate Loans (as defined in the Exit Facility), 6.5% per annum. The Exit Facility is secured by a first priority lien on substantially all of the Company's assets. The Company is subject to a restrictive covenant under the Exit Facility, consisting of maintaining a ratio of (i) the present value, discounted at 10% per annum, of the estimated future net revenues in respect of its oil and gas properties, before any state, federal, foreign or other income taxes, attributable to total proved reserves, using strip prices then in effect at the end of each calendar quarter, including swap agreements in place at the end of each quarter, to (ii) the sum of the aggregate outstanding principal amount of the term loans to be less than 1.50 to 1.00 as measured on the last day of each calendar. If the Company fails to maintain the ratio, it may either (i) prepay the outstanding term loans such that after giving effect to such prepayment, the financial covenant is met or (ii) be in default under the Exit Facility, in which case the term loans and all other amounts owed pursuant to the Exit Facility would become immediately due and payable. The Exit 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, maintenance and operation of property (including oil and gas properties), restrictions on the incurrence of liens and indebtedness, entering into mergers, consolidations and sales of assets, and transactions with affiliates and other customary covenants. The Exit Facility contains customary events of default and remedies for credit facilities of this nature. If the Company does not comply with the financial and other covenants in the Exit Facility, the lenders may, subject to customary cure rights, require immediate payment of all amounts outstanding under the Exit Facility. An event of default under the Exit Facility, if not cured or waived, could result in an event of default under the 2024 PIK Notes (as defined below). On the Effective Date and pursuant to the terms of the Plan and the Confirmation Order, the Company entered into an indenture (the “Indenture”) with Wilmington Trust, National Association, as trustee (the “Trustee”) and collateral agent, and issued $80 million of its new 10% Senior Secured PIK Notes due 2024 (the “2024 PIK Notes”) pursuant thereto. Interest on the 2024 PIK Notes accrues at a rate of 10% per annum payable semi-annually in kind (“PIK Interest”) on February 15 and August 15 of each year, beginning on August 15, 2019. At the election of the Board of Directors, so long as the Company has provided notice to the holders of the 2024 PIK Notes and the Trustee of such election at least 30 days prior to any applicable interest payment date, interest on the 2024 PIK Notes for any interest period may instead be payable at the annual rate (i) solely in cash (the “Cash Interest”) or (ii) partially as Cash Interest and partially as PIK Interest. The maturity date of the 2024 Notes is February 15, 2024 . The 2024 PIK Notes are secured on a second priority lien basis by the equity of the Company's subsidiary PetroQuest Energy, LLC that also secures the Exit Facility. Pursuant to the terms of an intercreditor agreement, the security interest in those assets that secure the 2024 PIK Notes and the related guarantee will be contractually subordinated to liens thereon that secure the Exit Facility and certain other permitted obligations as set forth in the Indenture. Consequently, the 2024 PIK Notes and the related guarantee will be effectively subordinated to the Exit Facility and such other permitted obligations to the extent of the value of such assets. The Company may, at its option, on any one or more occasions redeem all or a portion of the 2024 PIK Notes issued under the Indenture at the redemption prices set forth below (expressed in percentages of principal amount on the redemption date), plus accrued and unpaid Cash Interest together with an amount of cash equal to all accrued and unpaid PIK Interest on the 2024 PIK Notes to be redeemed to, but not including, the redemption date (subject to the right of holders of the 2024 PIK Notes of record on the relevant record date to receive interest due on the relevant interest payment date), if redeemed during the periods set forth below: Period Redemption Price February 8, 2019 to February 7, 2020 102.000% February 8, 2020 to February 7, 2021 101.000% February 8, 2021 and thereafter 100.000% Upon the occurrence of certain change of control events, any holder of the 2024 PIK Notes will have the right to cause the Company to repurchase all or any part of such holder’s 2024 PIK Notes at a repurchase price payable in cash equal to 101% of the principal amount of the 2024 PIK Notes to be repurchased (including any PIK Notes (as defined in the Indenture) or any increase in principal amount of the 2024 PIK Notes in connection with PIK Interest, plus accrued interest to the date of repurchase (subject to the right of holders of record on the relevant record date to receive interest due on the related interest payment date).

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Two of the Company’s senior officers, Charles T. Goodson and Stephen H. Green, or their affiliates, are working interest owners and overriding royalty interest owners in certain properties operated by the Company or in which the Company also holds a working interest. As working interest owners, they are required to pay their proportionate share of all costs and are entitled to receive their proportionate share of revenues in the normal course of business. As overriding royalty interest owners, they are entitled to receive their proportionate share of revenues in the normal course of business. During 2018 , in their capacities as working interest owners or overriding royalty interest owners, revenues, net of costs, were disbursed to Messrs. Goodson and Green, or their affiliates, in the amounts of $0 and $20,000 , respectively. During 2017 , in their capacities as working interest owners or overriding royalty interest owners, revenues, net of costs, were disbursed to (received from) Messrs. Goodson and Green, or their affiliates, in the amounts of $(107,000) and $41,000 , respectively. During 2016 , in their capacities as working interest owners or overriding royalty interest owners, revenues, net of costs, were disbursed to (received from) Messrs. Goodson and Green, or their affiliates, in the amounts of $(15,000) and $25,000 , respectively. With respect to Mr. Goodson, gross revenues attributable to interests, properties or participation rights held by him prior to joining the Company as an officer and director on September 1, 1998 represent all of the gross revenue received by him during these periods. In its capacity as operator, the Company incurs drilling and operating costs that are billed to its partners based on their respective working interests. At December 31, 2018 , the Company’s joint interest billing receivable included no amounts due from the related parties discussed above or their affiliates, attributable to their share of costs. In December 2017, the Company sold certain saltwater disposal assets in East Texas to a third party purchaser. In connection with the sale, the Company also entered into a volumetric commitment to deliver saltwater volumes to the purchaser of the saltwater disposal assets over a six year period. One of the minority owners of the purchaser is the son of Dr. Charles Mitchell, II, a member of our Predecessor's board of directors. The transactions were approved by the Predecessor's Audit Committee.

Ceiling Test Write-down

Ceiling Test Write-down	12 Months Ended
	Dec. 31, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Ceiling Test Write-down	Ceiling Test Write-down The Company uses the full cost method to account for its oil and gas properties. Accordingly, the costs to acquire, explore for and develop oil and gas properties are capitalized. Capitalized costs of oil and gas properties, net of accumulated DD&A and related deferred taxes, are limited to the estimated future net cash flows from estimated proved oil and gas reserves, including the effects of cash flow hedges in place, discounted at 10% , plus the lower of cost or fair value of unproved properties, as adjusted for related income tax effects (the full cost ceiling). If capitalized costs exceed the full cost ceiling, the excess is charged to ceiling test write-down of oil and gas properties in the quarter in which the excess occurs. In accordance with SEC requirements, the estimated future net cash flows from estimated proved reserves are based on an average of the first day of the month spot price for a historical 12-month period, adjusted for quality, transportation fees and market differentials. At December 31, 2016 , the prices used in computing the estimated future net cash flows from the Company’s estimated proved reserves, including the effect of hedges in place at that date, averaged $2.51 per Mcf of natural gas, $40.85 per barrel of oil and $1.82 per Mcfe of Ngl. As a result of lower commodity prices and their negative impact on the Company's estimated proved reserves and estimated future net cash flows, the Company recognized ceiling test write-downs of approximately $40.3 million during the year ended December 31, 2016 . The Company’s cash flow hedges in place decreased these ceiling test write-downs by approximately $8.0 million for the year ended December 31, 2016 . The Company did not recognize a ceiling test write-down during the years ended December 31, 2018 and 2017 .

Other Comprehensive Income (Los

Other Comprehensive Income (Loss)	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Other Comprehensive Income (Loss)	Other Comprehensive Income (Loss) The following table represents the changes in accumulated other comprehensive income (loss), net of tax, for the year ended December 31, 2016 (in thousands): Gains and Losses on Cash Flow Hedges Change in Valuation Allowance Total Balance as of December 31, 2015 $ 947 $ — $ 947 Other comprehensive income before reclassifications: Change in fair value of derivatives (4,447 ) — (4,447 ) Income tax effect 1,654 (1,654 ) — Net of tax (2,793 ) (1,654 ) (4,447 ) Amounts reclassified from accumulated other comprehensive income: Oil and gas sales (1,811 ) — (1,811 ) Income tax effect 674 (113 ) 561 Net of tax (1,137 ) (113 ) (1,250 ) Net other comprehensive loss (3,930 ) (1,767 ) (5,697 ) Balance as of December 31, 2016 $ (2,983 ) $ (1,767 ) $ (4,750 ) The following table represents the changes in accumulated other comprehensive income (loss), net of tax, for the year ended December 31, 2017 (in thousands): Gains and Losses on Cash Flow Hedges Change in Valuation Allowance Total Balance as of December 31, 2016 $ (2,983 ) $ (1,767 ) $ (4,750 ) Other comprehensive income before reclassifications: — Change in fair value of derivatives 6,654 — 6,654 Income tax effect (2,475 ) 1,767 (708 ) Net of tax 4,179 1,767 5,946 Amounts reclassified from accumulated other comprehensive income: Oil and gas sales (1,461 ) — (1,461 ) Income tax effect 543 — 543 Net of tax (918 ) — (918 ) Net other comprehensive loss $ 3,261 $ 1,767 $ 5,028 Balance as of December 31, 2017 $ 278 $ — $ 278 The following table represents the changes in accumulated other comprehensive income (loss), net of tax, for the year ended December 31, 2018 (in thousands): Gains and Losses on Cash Flow Hedges Balance as of December 31, 2017 $ 278 Other comprehensive income before reclassifications: Change in fair value of derivatives (990 ) Income tax effect 238 Net of tax (752 ) Amounts reclassified from accumulated other comprehensive income: Oil and gas sales 622 Income tax effect (148 ) Net of tax 474 Net other comprehensive loss (278 ) Balance as of December 31, 2018 $ —

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company typically provides for income taxes at the statutory federal income tax rate adjusted for permanent differences expected to be realized, primarily statutory depletion, non-deductible stock compensation expenses and state income taxes. As a result of ceiling test write-downs, the Company has incurred a three -year cumulative loss. Because of the impact the cumulative loss had on the determination of the recoverability of deferred tax assets through future earnings, the Company assessed the realizability of its deferred tax assets based on the future reversals of existing deferred tax liabilities, of which there were none as of December 31, 2018 . The Company had a valuation allowance of $118.7 million as of December 31, 2018 and $115.9 million as of December 31, 2017 . The Tax Cuts and Jobs Act (the “Act”) was enacted on December 22, 2017. The Act, among other things, reduces the U.S. federal corporate tax rate from 35% to 21% , eliminates the corporate alternative minimum tax and changes how existing alternative minimum tax credits are realized, creates a new limitation on deductible interest expense and changes the rules related to uses and limitations of net operating loss carryforwards generated in tax years beginning after December 31, 2017. The Company made a reasonable estimate of the effects on its existing deferred tax balances and recognized a provisional amount of $64.9 million as of December 31, 2017 to remeasure deferred tax assets and liabilities based on the rate at which they are expected to reverse in the future, which is generally 21% . This amount was included as a component of income tax expense (benefit) from continuing operations and was fully offset by the related adjustment to the Company’s valuation allowance. The Company finalized its accounting for the Act in connection with the filing of its 2017 federal tax return and determined no adjustment was necessary to the previously recognized provisional amount. As a result of the adoption of ASU 2016-09 during the year ended December 31, 2017 , the Company recognized an additional deferred tax asset of $4.7 million related to net operating loss carryforwards for excess tax benefits on share-based compensation that did not meet the criteria for recognition under previous guidance. This additional deferred tax asset was fully offset by the related adjustment to the Company's valuation allowance. The cumulative effect adjustment to record the previously unrecognized excess tax benefits and the related adjustment to the valuation allowance, were recorded in retained earnings on the date of adoption. An analysis of the Company’s deferred tax assets and liabilities follows (amounts in thousands): December 31, 2018 2017 Net operating loss carryforwards $ 86,046 $ 78,541 Percentage depletion carryforward 6,011 5,701 Interest expense carryforward 10,540 — Contributions carryforward and other 194 192 Temporary differences: Oil and gas properties 3,673 8,279 Asset retirement obligation 602 7,602 Derivatives — (107 ) Share-based compensation 1,403 1,269 Original issue discount on debt exchanges 9,815 14,429 Other 432 — Valuation allowance (118,716 ) (115,906 ) Deferred tax asset (liability) $ — $ — At December 31, 2018 , the Company had approximately $355.4 million of federal net operating loss carryforwards. If not utilized, approximately $6.9 million of such carryforwards would expire in 2025 , $328.2 million would expire by the year 2037 and $20.3 million does not expire and is subject to a limitation of 80% of taxable income. The Company also had approximately $180.7 million of Louisiana state net operating loss carryforwards as of December 31, 2018 . If not utilized, approximately $0.3 million of such carryforwards would expire during 2019 and the remainder would expire by the year 2038 . The Company has available for tax reporting purposes $28.2 million in statutory depletion deductions that may be carried forward indefinitely. The Company had approximately $43.9 million of carryforwards related to the limitation on deductible interest expense. The interest expense carryforward does not expire and is subject to a limitation of 30% of adjusted taxable income. Income tax expense (benefit) for each of the years ended December 31, 2018 , 2017 and 2016 was different than the amount computed using the federal statutory rate (21%) for the following reasons (amounts in thousands): For the Year Ended December 31, 2018 2017 2016 Amount computed using the statutory rate $ (1,973 ) $ (2,655 ) $ (31,623 ) Increase (reduction) in taxes resulting from: Impact of rate change on deferred tax — 64,915 — State & local taxes (1,731 ) (368 ) (2,000 ) Percentage depletion carryforward (256 ) (66 ) (163 ) Non-deductible stock option expense (1) 98 305 77 Share-based compensation (2) — 64 707 Restructuring costs 1,528 — — Other 93 (21 ) 1,415 Change in valuation allowance 2,393 (63,123 ) 32,130 Income tax expense (benefit) $ 152 $ (949 ) $ 543 (1) Relates to compensation expense related to Incentive Stock Options. (2) Relates to the write-off of deferred tax assets associated with share-based compensation that will not be deductible for tax purposes.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies The Company is involved in litigation relating to claims arising out of its operations in the normal course of business, including worker's compensation claims, tort claims and contractual disputes. Some of the existing known claims against us are covered by insurance subject to the limits of such policies and the payment of deductible amounts by us. Although we cannot predict the outcome of these proceedings with certainty, management believes that the ultimate disposition of all uninsured or unindemnified matters resulting from existing litigation will not have a material adverse effect on the Company's business or financial position. The commencement of the Chapter 11 Cases automatically stayed litigation and claims that were or could have been brought prior to November 6, 2018. The claims related to two class action lawsuits filed in October 2016 will be treated as general unsecured claims with a maximum amount that may be distributed to the holders of such claims not to exceed $400,000 under the Plan. Lease Commitments The Company has operating leases for office space and equipment, which expire on various dates through 2023. Future minimum lease commitments as of December 31, 2018 under these operating leases are as follows (in thousands): 2019 $ 1,240 2020 1,173 2021 445 2022 431 2023 392 Thereafter — $ 3,681 Total rent expense under operating leases was approximately $1.5 million for each of 2018 , 2017 and 2016 , respectively. Subsequent to December 31, 2018 and as part of the Chapter 11 Cases, the Company entered into a lease amendment with regard to its office space in The Woodlands, Texas, which reduced the above noted lease commitments by $1.3 million thru 2022.

Supplementary Information on Oi

Supplementary Information on Oil and Gas Operations—Unaudited	12 Months Ended
	Dec. 31, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Supplementary Information of Oil and Gas Operations—Unaudited	Supplementary Information on Oil and Gas Operations—Unaudited The following tables disclose certain financial data relative to the Company’s oil and gas producing activities, which are located onshore and offshore in the continental United States: Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities ( amounts in thousands ) For the Year-Ended December 31, 2018 2017 2016 Acquisition costs: Proved $ 241 $ 1,330 $ 3,346 Unproved (1) 6,190 12,762 2,197 Divestiture of proved leasehold (2,604 ) (4,795 ) (7,000 ) Exploration costs: Proved (51 ) 9,466 715 Unproved 233 (287 ) 603 Development costs (2) (18,928 ) 32,622 1,522 Capitalized general and administrative and interest costs 8,070 8,269 7,558 Total costs incurred $ (6,849 ) $ 59,367 $ 8,941 For the Year-Ended December 31, 2018 2017 2016 Accumulated depreciation, depletion and amortization (DD&A) Balance, beginning of year $ (1,285,660 ) $ (1,243,286 ) $ (1,157,455 ) Provision for DD&A (22,410 ) (31,667 ) (27,962 ) Ceiling test writedown — — (40,304 ) Sale of proved properties and other (3) 6,478 (10,707 ) (17,565 ) Balance, end of year $ (1,301,592 ) $ (1,285,660 ) $ (1,243,286 ) DD&A per Mcfe $ 1.05 $ 1.15 $ 1.19 (1) During 2017 , the Company acquired approximately 24,600 gross acres for approximately $9.3 million in cash and 2.0 million shares of common stock. In total for 2017 and 2018, the Company has invested approximately $15.0 million in leasing costs and geological and engineering data. (2) During 2018 , the Company sold its Gulf of Mexico properties and removed approximately $28.2 million of future discounted asset retirement obligations, which was recorded as a reduction in the capitalized costs of oil and gas properties. (3) During 2018 , the Company sold its Gulf of Mexico properties, receiving no cash consideration and funding amounts related to the future abandonment costs for the properties and purchase price adjustments. During 2017 , the Company sold its East Lake Verret assets for net proceeds of approximately $2.2 million and its East Texas saltwater disposal assets for net proceeds of $8.5 million . During 2016 , the Company sold its remaining Oklahoma producing assets for net proceeds of $17.6 million . At December 31, 2018 and 2017 , unevaluated oil and gas properties totaled $23.5 million and $21.9 million , respectively, and were not subject to depletion. Unevaluated costs at December 31, 2018 included $0.9 million of costs related to wells in progress at year-end. At December 31, 2017 , unevaluated costs included $0.7 million related to two facilities in progress at year-end, which were transferred to evaluated oil and gas properties during 2018 . The Company capitalized $1.8 million , $1.6 million and $0.9 million of interest during 2018 , 2017 and 2016 , respectively. Of the total unevaluated oil and gas property costs of $23.5 million at December 31, 2018 , $7.4 million , or 32% , was incurred in 2018 , $13.9 million , or 59% , was incurred in 2017 and $2.2 million , or 9% , was incurred in prior years. In connection with the sale of the Company's Gulf of Mexico assets, approximately $5.5 million , or 25% of the total unevaluated balance at December 31, 2017 , was transferred to evaluated oil and gas properties in 2018. Of the remaining unevaluated balance at December 31, 2018 , the Company expects the majority of the costs will be evaluated within the next three years, including $2.7 million expected to be evaluated during 2019 . Oil and Gas Reserve Information The Company’s net proved oil and gas reserves at December 31, 2018 have been estimated by independent petroleum engineers in accordance with guidelines established by the SEC using a historical 12-month, first of month, average pricing assumption. The estimates of proved oil and gas reserves constitute those quantities of oil, gas,and natural gas liquids, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. However, there are numerous uncertainties inherent in estimating quantities of proved reserves and in providing the future rates of production and timing of development expenditures. The following reserve data represents estimates only and should not be construed as being exact. In addition, the present values should not be construed as the current market value of the Company’s oil and gas properties or the cost that would be incurred to obtain equivalent reserves. The following table sets forth an analysis of the Company’s estimated quantities of net proved and proved developed oil (including condensate), gas and natural gas liquid reserves, all located onshore and offshore in the continental United States: Oil NGL Natural Gas Total Proved reserves as of December 31, 2015 1,806 34,826 132,344 178,004 Revisions of previous estimates 247 (4,380 ) (11,854 ) (14,748 ) Extensions, discoveries and other additions — — 1,485 1,485 Sale of reserves in place (154 ) — (24,834 ) (25,759 ) Production (502 ) (3,871 ) (16,617 ) (23,501 ) Proved reserves as of December 31, 2016 1,397 26,575 80,524 115,481 Revisions of previous estimates 308 (7,269 ) 381 (5,040 ) Extensions, discoveries and other additions 777 4,565 64,704 73,931 Purchase of producing properties 48 — 473 761 Sale of reserves in place (90 ) — (1,033 ) (1,573 ) Production (592 ) (4,450 ) (19,611 ) (27,613 ) Proved reserves as of December 31, 2017 1,848 19,421 125,438 155,947 Revisions of previous estimates 130 (1,469 ) 2,737 2,044 Extensions, discoveries and other additions 41 2,929 7,947 11,121 Sale of reserves in place (507 ) (486 ) (13,945 ) (17,472 ) Production (326 ) (3,373 ) (16,013 ) (21,335 ) Proved reserves as of December 31, 2018 1,186 17,022 106,164 130,305 Proved developed reserves As of December 31, 2016 1,212 13,073 47,349 67,694 As of December 31, 2017 1,078 12,564 57,409 76,441 As of December 31, 2018 567 10,220 47,516 61,143 Proved undeveloped reserves As of December 31, 2016 185 13,502 33,175 47,787 As of December 31, 2017 770 6,857 68,029 79,506 As of December 31, 2018 619 6,802 58,648 69,162 Year Ended December 31, 2018 During 2018 , the Company’s estimated proved reserves decrease d by 16% . The decrease in reserves was the result of 10.1 Bcfe removed as a result of the sale of our Gulf of Mexico assets in January 2018 and 7.3 Bcfe removed due to the selldown of certain of our PUDs in East Texas. Partially offsetting these decreases was an increase of 11.1 Bcfe of PUD reserves from third party drilling as well as the Company's leasing efforts in East Texas. Overall, the Company had a 100% drilling success rate on two wells completed during 2018 . Year Ended December 31, 2017 During 2017 , the Company’s estimated proved reserves increase d by 35% . The increase in reserves was the result of 73.9 Bcfe added due to the Company's drilling program in East Texas where it drilled eight gross wells during 2017 . In response to low ethane prices, during 2017 the Company elected to bypass ethane processing on a portion of its East Texas production. As a result, the Company reduced its estimated proved ngl reserves to reflect the assumption that ethane would continue to not be recovered as natural gas liquids. Overall, the Company had a 100% drilling success rate during 2017 . Year Ended December 31, 2016 During 2016 , the Company's estimated proved reserves decrease d by 35% primarily due to the divestiture of the Company's remaining Oklahoma assets and significant reductions in capital spending during 2016 . Extensions, discoveries and other additions of 1.5 Bcfe were primarily due to the successful completion of the Company's final Oklahoma wells. Revisions of previous estimates included the reclassification of certain PUD reserves to probable reserves as a result of the Company's assessment of the timing of development. Overall, the Company had a 100% drilling success rate during 2016 on 5 gross wells drilled. The following tables (amounts in thousands) present the standardized measure of future net cash flows related to proved oil and gas reserves together with changes therein, as defined by ASC Topic 932. Future production and development costs are based on current costs with no escalations. Estimated future cash flows have been discounted to their present values based on a 10% annual discount rate. Standardized Measure December 31, 2018 2017 2016 Future cash flows $ 482,766 $ 539,244 $ 299,035 Future production costs (171,999 ) (184,171 ) (117,283 ) Future development costs (73,258 ) (128,447 ) (83,720 ) Future income taxes — — — Future net cash flows 237,509 226,626 98,032 10% annual discount (113,484 ) (99,329 ) (30,763 ) Standardized measure of discounted future net cash flows $ 124,025 $ 127,297 $ 67,269 Changes in Standardized Measure Year Ended December 31, 2018 2017 2016 Standardized measure at beginning of year $ 127,297 $ 67,269 $ 127,685 Sales and transfers of oil and gas produced, net of production costs (64,148 ) (70,362 ) (35,993 ) Changes in price, net of future production costs 18,542 53,516 (30,427 ) Extensions and discoveries, net of future production and development costs 2,983 50,977 864 Changes in estimated future development costs, net of development costs incurred during this period 16,241 17,144 26,356 Revisions of quantity estimates 2,755 (7,482 ) (14,889 ) Accretion of discount 12,730 6,727 12,769 Purchase of reserves in place — 549 — Sale of reserves in place 1,614 (1,305 ) (16,701 ) Changes in production rates (timing) and other 6,011 10,264 (2,395 ) Net increase (decrease) in standardized measure (3,272 ) 60,028 (60,416 ) Standardized measure at end of year $ 124,025 $ 127,297 $ 67,269 The historical twelve-month, first day of the month, average prices of oil, gas and natural gas liquids used in determining standardized measure were: 2018 2017 2016 Oil, $/Bbl $68.71 $52.49 $40.85 Ngls, $/Mcfe 4.08 3.23 2.40 Natural Gas, $/Mcf 3.13 3.03 1.82

Summarized Quarterly Financial

Summarized Quarterly Financial Information - Unaudited	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Summarized Quarterly Financial Information - Unaudited	Summarized Quarterly Financial Information - Unaudited Summarized quarterly financial information is as follows (amounts in thousands except per share data): Quarter Ended March 31 June 30 September 30 December 31 2018 Revenues $ 24,917 $ 21,507 $ 20,886 $ 19,789 Income (loss) from operations (821 ) (1,326 ) (3,657 ) 701 Loss available to common stockholders (2,212 ) (2,611 ) (4,979 ) $ (4,117 ) Loss per share: Basic $ (0.09 ) $ (0.10 ) $ (0.19 ) $ (0.16 ) Diluted $ (0.09 ) $ (0.10 ) $ (0.19 ) $ (0.16 ) 2017 Revenues $ 20,772 $ 24,251 $ 28,184 $ 35,080 Income (loss) from operations (3,633 ) (2,289 ) (1,885 ) 221 Loss available to common stockholders (4,918 ) (3,385 ) (3,085 ) (389 ) Loss per share: Basic $ (0.23 ) $ (0.16 ) $ (0.15 ) $ (0.02 ) Diluted $ (0.23 ) $ (0.16 ) $ (0.15 ) $ (0.02 )

Organization and Summary of S_2

Organization and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	Principles of Consolidation The consolidated financial statements include the accounts of PetroQuest and its subsidiaries, PetroQuest Energy, L.L.C., PetroQuest Oil & Gas, L.L.C, Pittrans, Inc. and TDC Energy LLC (collectively, the "Company"). All intercompany accounts and transactions have been eliminated.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States ("US GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Estimates of proved oil and gas reserves and future net cash flows from estimated proved reserves are based on geological and engineering data and depend upon a number of variable factors and assumptions. Changes in estimated proved oil and gas reserves used in the calculation of depreciation, depletion and amortization of oil and gas properties or the present value of the estimated future net cash flows from estimated proved reserves used in the ceiling test could have a material impact on future results of operations.
Oil and Gas Properties	Oil and Gas Properties The Company utilizes the full cost method of accounting, which involves capitalizing all acquisition, exploration and development costs incurred for the purpose of finding oil and gas reserves including the costs of drilling and equipping productive wells, dry hole costs, lease acquisition costs and delay rentals. The Company also capitalizes the portion of general and administrative costs that can be directly identified with acquisition, exploration or development of oil and gas properties. Unevaluated property costs are transferred to evaluated property costs at such time as wells are completed on the properties, the properties are sold, or management determines these costs to have been impaired. Interest is capitalized on unevaluated property costs. Transactions involving sales of reserves in place are recorded as adjustments to accumulated depreciation, depletion and amortization with no gain or loss recognized, unless such adjustments would cause a significant alteration in the relationship between capitalized costs and proved reserves. Depreciation, depletion and amortization of oil and gas properties is computed using the unit-of-production method based on estimated proved reserves. All costs associated with evaluated oil and gas properties, including an estimate of future development costs associated therewith, are included in the depreciable base. The costs of investments in unevaluated properties are excluded from this calculation until the related properties are evaluated, proved reserves are established or the properties are determined to be impaired. Proved oil and gas reserves are estimated annually by independent petroleum engineers. The capitalized costs of proved oil and gas properties cannot exceed the present value of the estimated net future cash flows from proved reserves based on historical twelve-month, first day of the month, average oil, gas and natural gas liquid prices, including the effect of hedges in place (the full cost ceiling). If the capitalized costs of proved oil and gas properties exceed the full cost ceiling, the Company is required to write-down the value of its oil and gas properties to the full cost ceiling amount. The Company follows the provisions of Staff Accounting Bulletin (“SAB”) No. 106, regarding the application of ASC Topic 410-20 by companies following the full cost accounting method. SAB No. 106 indicates that estimated future dismantlement and abandonment costs that are recorded on the balance sheet are to be included in the costs subject to the full cost ceiling limitation. The estimated future cash outflows associated with settling the recorded asset retirement obligations are excluded from the computation of the present value of estimated future net revenues used in applying the ceiling test.
Cash and Cash Equivalents	Cash and Cash Equivalents The Company considers all highly liquid investments with a stated maturity of three months or less to be cash and cash equivalents. The majority of the Company’s cash and cash equivalents are in overnight securities made through its commercial bank accounts, which result in available funds the next business day.
Other Property and Equipment	Other Property and Equipment The costs related to other furniture and fixtures are depreciated on a straight line basis over estimated useful lives ranging from three to five years.
Accounts Receivable	Accounts Receivable In its capacity as operator, the Company incurs drilling and operating costs that are billed to its partners based on their respective working interests.
Deposit For Surety Bonds	Deposit For Surety Bonds The deposit for surety bonds of $3.6 million and $8.3 million at December 31, 2018 and 2017 , respectively, represent cash collateral paid with respect to the Company's surety bonds which secured its offshore decommissioning obligations.
Income Taxes	Income Taxes The Company accounts for income taxes in accordance with ASC Topic 740. Provisions for income taxes include deferred taxes resulting primarily from temporary differences due to different reporting methods for oil and gas properties for financial reporting purposes and income tax purposes. For financial reporting purposes, all exploratory and development expenditures are capitalized and depreciated, depleted and amortized on the unit-of-production method. For income tax purposes, only the equipment and leasehold costs relative to successful wells are capitalized and recovered through depreciation or depletion. Generally, most other exploratory and development costs are charged to expense as incurred; however, the Company may use certain provisions of the Internal Revenue Code that allow capitalization of intangible drilling costs. Other financial and income tax reporting differences occur primarily as a result of statutory depletion. Deferred tax assets are assessed for realizability and a valuation allowance is established for any portion of the asset for which it is more likely than not will not be realized.
Revenue Recognition	Revenue Recognition The Company records natural gas and oil revenue in accordance with Accounting Standards Update ("ASU") 2014-09 "Revenue from Contracts with Customers". The core principle of ASU 2014-09 is that an entity will recognize revenue when it transfers control of goods or services to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods and or services. The Company's sources of revenue are oil, natural gas and natural gas liquids ("NGL") production from its oil and gas properties. Oil and natural gas production is typically sold to purchasers through monthly contracts at negotiated sales prices based on published market indices. The sale takes place at the wellhead for oil production and at the wellhead or gas processing plant for natural gas. NGL production is sold once natural gas is processed and the related liquids are removed at the processing plant. The contracts for sale of NGL production are with the processing plant with prices based on what the processing plant is able to receive from third party purchasers. Sales of oil, natural gas and NGL production are recognized when the product is delivered and title transfers to the purchaser and payment is generally received one to two months after the sale has occurred.
Concentrations	Concentrations The Company’s production is sold on month to month contracts at prevailing prices. The Company attempts to diversify its sales among multiple purchasers and obtain credit protection such as letters of credit and parental guarantees when necessary.
Derivatives Instruments	Derivative Instruments Under ASC Topic 815, the nature of a derivative instrument must be evaluated to determine if it qualifies for hedge accounting treatment. Instruments qualifying for hedge accounting treatment are recorded as an asset or liability measured at fair value and subsequent changes in fair value are recognized in stockholders’ equity through other comprehensive income (loss), net of related taxes, to the extent the hedge is effective. If a hedge becomes ineffective because the hedged production does not occur, or the hedge otherwise does not qualify for hedge accounting treatment, the changes in the fair value of the derivative are recorded in the statement of operations as derivative income (expense). The Company does not offset fair value amounts recognized for derivative instruments. The Company’s hedges are specifically referenced to NYMEX prices for oil and natural gas. The effectiveness of hedges is evaluated at the time the contracts are entered into, as well as periodically over the life of the contracts, by analyzing the correlation between NYMEX prices and the posted prices received from the designated production. Through this analysis, the Company is able to determine if a high correlation exists between the prices received for its designated production and the NYMEX prices at which the hedges will be settled. At December 31, 2018 , the Company had no derivative instruments in place. See Note 8 for further discussion of the Company’s derivative instruments.
Recently Issued Accounting Standards	Recently Issued Accounting Standards In February 2016, the Financial Accounting Standards Board ("FASB") issued ASU 2016-02, " Leases (Topic 842), " to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. This ASU supersedes the lease requirements in Topic 840, Leases , and requires that a lessee recognize a right-of-use asset and lease liability for leases that do not meet the definition of a short-term lease. The right-of-use asset and lease liability are to be measured on the balance sheet at the present value of the lease payments. For income statement purposes, ASU 2016-02 retains a dual model requiring leases to be classified as either operating or finance within the Company’s consolidated statements of operations. Lease costs for operating leases are recognized as a single lease cost, calculated so that the cost of the lease is allocated over the lease term on a straight-line basis. For finance leases, interest expense is recognized on the lease liability separately from amortization of the right-to-use asset. ASU 2016-02 does not apply to mineral leases for oil and natural gas properties, but does apply to equipment used to explore and develop oil and natural gas reserves. This ASU is effective for fiscal years beginning after December 15, 2018, including the first quarter of 2019. The Company will adopt this standard using the modified retrospective method applied to all leases that exist on January 1, 2019. The Company made certain elections allowing it not to reassess contracts that commenced prior to adoption and to not recognize right-of-use assets or lease liabilities for short-term leases. Upon adoption, the Company expects the right-to-use asset and lease liability reported on its consolidated financial statements to be immaterial. In August 2017, the FASB issued ASU 2017-12, "Derivative and Hedging," to improve the financial reporting of hedging relationships to better portray the economic results of an entity's risk management activities in its consolidated financial statements and make certain targeted improvements to simplify the application of the hedge accounting guidance in current US GAAP. ASU 2017-12 is effective for public entities for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years, with earlier application permitted. The Company is currently evaluating the effect that this new standard may have on its consolidated financial statements.

Organization and Summary of S_3

Organization and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Disaggregation of Revenue	The following table includes a disaggregation of revenue by product including the effects of hedges in place (in thousands): Year Ended December 31, 2018 2017 2016 Total oil sales $ 21,027 $ 31,258 $ 20,614 Total gas sales 50,768 60,922 37,963 Total ngl sales 15,303 16,107 8,090 Total oil and gas sales $ 87,099 $ 108,287 $ 66,667
Schedule of significant concentration risk	The following table identifies customers from whom the Company derived 10% or more of its oil and gas revenues during the years presented. Based on the availability of other customers, the Company does not believe the loss of any of these customers would have a significant effect on its business or financial condition. Year Ended December 31, 2018 2017 2016 Superior Natural Gas 26% 29% 14% Shell Trading Company 21% 24% 23% Texla Energy Management 16% (a) (a) Harvest Pipeline Company 12% (a) (a) Laclede Energy Resources (a) (a) 17% BG Group (a) (a) 10% (a) Less than 10 percent

Voluntary Reorganization unde_2

Voluntary Reorganization under Chapter 11 of the Bankruptcy Code (Tables)	12 Months Ended
	Dec. 31, 2018
Reorganizations [Abstract]
Schedule Of Liabilities Subject To Compromise	Liabilities subject to compromise at December 31, 2018 consisted of the following (in thousands): December 31, 2018 10% Senior PIK Notes due 2021 $ 275,046 10% Senior Notes due 2021 9,427 Accrued interest 20,624 Accounts payable to vendors 874 Other long-term liabilities 510 Other accrued liabilities 2,724 Preferred stock dividend payable 14,649 Liabilities subject to compromise $ 323,854

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
A reconciliation between basic and diluted earnings per share computations	A reconciliation between the basic and diluted earnings per share computations (in thousands, except per share amounts) is as follows: For the Year Ended December 31, 2018 Loss(Numerator) Shares Per BASIC EPS Net loss available to common stockholders $ (13,919 ) 25,581 $ (0.54 ) Stock options — — Attributable to participating securities — — DILUTED EPS $ (13,919 ) 25,581 $ (0.54 ) For the Year Ended December 31, 2017 Loss(Numerator) Shares Per BASIC EPS Net loss available to common stockholders $ (11,776 ) 21,330 $ (0.55 ) Stock options — — Attributable to participating securities — — DILUTED EPS $ (11,776 ) 21,330 $ (0.55 ) For the Year Ended December 31, 2016 Loss(Numerator) Shares Per BASIC EPS Net loss available to common stockholders $ (96,245 ) 18,354 $ (5.24 ) Stock options — — Attributable to participating securities — — DILUTED EPS $ (96,245 ) 18,354 $ (5.24 )

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of share-based compensation	A detail of share-based compensation cost for the years ended December 31, 2018 , 2017 and 2016 is as follows (in thousands): Year Ended December 31, 2018 2017 2016 Stock options: Incentive Stock Options (share settled) $ 407 $ 820 $ 206 Non-Qualified Stock Options (share settled) 94 387 164 Restricted stock (share settled) 465 197 1,073 Cash settled stock units (241 ) 245 244 Share-based compensation $ 725 $ 1,649 $ 1,687
Schedule of stock option valuation assumptions	The following table outlines the assumptions used in computing the fair value of stock options granted during 2017 and 2016 . No such grants were made during 2018 . 2017 2016 Dividend yield —% —% Expected volatility 80.44% 62.0%-79.99% Risk-free rate 1.925% 1.255%-2.09% Expected term 6 years 6 years Stock options granted 219,130 1,168,754 Wgtd. avg. grant date fair value per share $1.28 $1.96 Fair value of grants $280,000 $2,293,000
Schedule of stock options activity	The following table details stock option activity during the year ended December 31, 2018 : Number of Options Wgtd. Avg. Exercise Price Wgtd. Avg. Remaining Life Aggregate Intrinsic Value (000’s) Outstanding at beginning of year 1,608,646 $ 6.20 Granted — — Expired/cancelled/forfeited (121,823 ) 4.98 Exercised — — Outstanding at end of year 1,486,823 6.34 7.03 $ — Options exercisable at end of year 1,047,590 $ 7.78 6.64 $ —
Schedule of stock option plans, by exercise price range	The following table summarizes information regarding stock options outstanding at December 31, 2018 : Range of Options Wgtd. Avg. Wgtd. Avg. Options Wgtd. Avg. Exercise Outstanding Remaining Exercise Exercisable Exercise Price 12/31/2018 Contractual Life Price 12/31/2018 Price $0.00-$2.37 250,477 8.43 $1.99 105,780 $2.07 $3.17-$4.36 1,013,663 7.68 $3.37 719,127 $3.36 $16.72-$19.52 68,190 4.42 $17.11 68,190 $17.11 $20.40-$30.32 154,493 1.73 $28.15 154,493 $28.15 1,486,823 1,047,590 $7.78
Schedule of restricted stock units activity	The following table details restricted stock activity during the year ended December 31, 2018 : Number of Shares Wgtd. Avg. Fair Value per Share Outstanding at beginning of year 487,502 $1.87 Cancelled/forfeited (34,946 ) $1.85 Lapse of restrictions (37,500 ) $2.15 Outstanding at December 31, 2018 415,056 $1.85 The following table details MRSU and RSU activity during the year ended December 31, 2018 : MRSU RSU Total Outstanding at beginning of year 277,733 889,587 1,167,320 Granted — — — Expired/Cancelled/Forfeited (270,269 ) (78,808 ) (349,077 ) Vested/Paid (7,464 ) (323,374 ) (330,838 ) Outstanding at December 31, 2018 — 487,405 487,405

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Changes to the Company's asset retirement obligation liability	The following table summarizes the changes to the Company’s asset retirement obligation (in thousands): Year Ended December 31, 2018 2017 Asset retirement obligation, beginning of period $ 31,310 $ 36,610 Liabilities incurred 7 574 Liabilities settled (863 ) (3,364 ) Accretion expense 322 2,252 Revisions in estimated cash flows (62 ) (4,514 ) Divestiture of oil and gas properties (28,234 ) (248 ) Asset retirement obligation, end of period 2,480 31,310 Less: current portion of asset retirement obligation (183 ) (687 ) Long-term asset retirement obligation $ 2,297 $ 30,623

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Effect of cash flow hedges on the consolidated balance sheet	Effect of Cash Flow Hedges on the Consolidated Balance Sheet at December 31, 2017 : Commodity Derivatives Period Balance Sheet Fair Value December 31, 2017 Derivative asset $ 1,174 December 31, 2017 Derivative liability $ (731 )
Effect of cash flow hedges on the consolidated statement of operations	Effect of Cash Flow Hedges on the Consolidated Statement of Operations for years ended December 31, 2018 , 2017 and 2016 : Instrument Amount of Gain (Loss) Location of Amount of Gain (Loss) Reclassified into Commodity Derivatives at December 31, 2018 $ (990 ) Oil and gas sales $ (622 ) Commodity Derivatives at December 31, 2017 $ 6,654 Oil and gas sales $ 1,461 Commodity Derivatives at December 31, 2016 $ (4,447 ) Oil and gas sales $ 1,811

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Net Valuation of Derivatives	The following table summarizes the Company’s assets (liabilities) that are subject to fair value measurement on a recurring basis as of December 31, 2017 (in thousands): Fair Value Measurements Using Instrument Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Commodity Derivatives: At December 31, 2017 $ — $ 443 $ —

Other Comprehensive Income (L_2

Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	The following table represents the changes in accumulated other comprehensive income (loss), net of tax, for the year ended December 31, 2016 (in thousands): Gains and Losses on Cash Flow Hedges Change in Valuation Allowance Total Balance as of December 31, 2015 $ 947 $ — $ 947 Other comprehensive income before reclassifications: Change in fair value of derivatives (4,447 ) — (4,447 ) Income tax effect 1,654 (1,654 ) — Net of tax (2,793 ) (1,654 ) (4,447 ) Amounts reclassified from accumulated other comprehensive income: Oil and gas sales (1,811 ) — (1,811 ) Income tax effect 674 (113 ) 561 Net of tax (1,137 ) (113 ) (1,250 ) Net other comprehensive loss (3,930 ) (1,767 ) (5,697 ) Balance as of December 31, 2016 $ (2,983 ) $ (1,767 ) $ (4,750 ) The following table represents the changes in accumulated other comprehensive income (loss), net of tax, for the year ended December 31, 2017 (in thousands): Gains and Losses on Cash Flow Hedges Change in Valuation Allowance Total Balance as of December 31, 2016 $ (2,983 ) $ (1,767 ) $ (4,750 ) Other comprehensive income before reclassifications: — Change in fair value of derivatives 6,654 — 6,654 Income tax effect (2,475 ) 1,767 (708 ) Net of tax 4,179 1,767 5,946 Amounts reclassified from accumulated other comprehensive income: Oil and gas sales (1,461 ) — (1,461 ) Income tax effect 543 — 543 Net of tax (918 ) — (918 ) Net other comprehensive loss $ 3,261 $ 1,767 $ 5,028 Balance as of December 31, 2017 $ 278 $ — $ 278 The following table represents the changes in accumulated other comprehensive income (loss), net of tax, for the year ended December 31, 2018 (in thousands): Gains and Losses on Cash Flow Hedges Balance as of December 31, 2017 $ 278 Other comprehensive income before reclassifications: Change in fair value of derivatives (990 ) Income tax effect 238 Net of tax (752 ) Amounts reclassified from accumulated other comprehensive income: Oil and gas sales 622 Income tax effect (148 ) Net of tax 474 Net other comprehensive loss (278 ) Balance as of December 31, 2018 $ —

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Schedule of Deferred Taxes	An analysis of the Company’s deferred tax assets and liabilities follows (amounts in thousands): December 31, 2018 2017 Net operating loss carryforwards $ 86,046 $ 78,541 Percentage depletion carryforward 6,011 5,701 Interest expense carryforward 10,540 — Contributions carryforward and other 194 192 Temporary differences: Oil and gas properties 3,673 8,279 Asset retirement obligation 602 7,602 Derivatives — (107 ) Share-based compensation 1,403 1,269 Original issue discount on debt exchanges 9,815 14,429 Other 432 — Valuation allowance (118,716 ) (115,906 ) Deferred tax asset (liability) $ — $ —
Income Tax Reconciliation	Income tax expense (benefit) for each of the years ended December 31, 2018 , 2017 and 2016 was different than the amount computed using the federal statutory rate (21%) for the following reasons (amounts in thousands): For the Year Ended December 31, 2018 2017 2016 Amount computed using the statutory rate $ (1,973 ) $ (2,655 ) $ (31,623 ) Increase (reduction) in taxes resulting from: Impact of rate change on deferred tax — 64,915 — State & local taxes (1,731 ) (368 ) (2,000 ) Percentage depletion carryforward (256 ) (66 ) (163 ) Non-deductible stock option expense (1) 98 305 77 Share-based compensation (2) — 64 707 Restructuring costs 1,528 — — Other 93 (21 ) 1,415 Change in valuation allowance 2,393 (63,123 ) 32,130 Income tax expense (benefit) $ 152 $ (949 ) $ 543 (1) Relates to compensation expense related to Incentive Stock Options. (2) Relates to the write-off of deferred tax assets associated with share-based compensation that will not be deductible for tax purposes.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Lease Commitments	Future minimum lease commitments as of December 31, 2018 under these operating leases are as follows (in thousands): 2019 $ 1,240 2020 1,173 2021 445 2022 431 2023 392 Thereafter — $ 3,681

Supplementary Information on _2

Supplementary Information on Oil and Gas Operations—Unaudited (Tables)	12 Months Ended
	Dec. 31, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Costs incurred in oil and gas property acquisition	The following tables disclose certain financial data relative to the Company’s oil and gas producing activities, which are located onshore and offshore in the continental United States: Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities ( amounts in thousands ) For the Year-Ended December 31, 2018 2017 2016 Acquisition costs: Proved $ 241 $ 1,330 $ 3,346 Unproved (1) 6,190 12,762 2,197 Divestiture of proved leasehold (2,604 ) (4,795 ) (7,000 ) Exploration costs: Proved (51 ) 9,466 715 Unproved 233 (287 ) 603 Development costs (2) (18,928 ) 32,622 1,522 Capitalized general and administrative and interest costs 8,070 8,269 7,558 Total costs incurred $ (6,849 ) $ 59,367 $ 8,941 For the Year-Ended December 31, 2018 2017 2016 Accumulated depreciation, depletion and amortization (DD&A) Balance, beginning of year $ (1,285,660 ) $ (1,243,286 ) $ (1,157,455 ) Provision for DD&A (22,410 ) (31,667 ) (27,962 ) Ceiling test writedown — — (40,304 ) Sale of proved properties and other (3) 6,478 (10,707 ) (17,565 ) Balance, end of year $ (1,301,592 ) $ (1,285,660 ) $ (1,243,286 ) DD&A per Mcfe $ 1.05 $ 1.15 $ 1.19 (1) During 2017 , the Company acquired approximately 24,600 gross acres for approximately $9.3 million in cash and 2.0 million shares of common stock. In total for 2017 and 2018, the Company has invested approximately $15.0 million in leasing costs and geological and engineering data. (2) During 2018 , the Company sold its Gulf of Mexico properties and removed approximately $28.2 million of future discounted asset retirement obligations, which was recorded as a reduction in the capitalized costs of oil and gas properties. (3) During 2018 , the Company sold its Gulf of Mexico properties, receiving no cash consideration and funding amounts related to the future abandonment costs for the properties and purchase price adjustments. During 2017 , the Company sold its East Lake Verret assets for net proceeds of approximately $2.2 million and its East Texas saltwater disposal assets for net proceeds of $8.5 million . During 2016 , the Company sold its remaining Oklahoma producing assets for net proceeds of $17.6 million .
Schedule of proved developed reserve quantities	The following table sets forth an analysis of the Company’s estimated quantities of net proved and proved developed oil (including condensate), gas and natural gas liquid reserves, all located onshore and offshore in the continental United States: Oil NGL Natural Gas Total Proved reserves as of December 31, 2015 1,806 34,826 132,344 178,004 Revisions of previous estimates 247 (4,380 ) (11,854 ) (14,748 ) Extensions, discoveries and other additions — — 1,485 1,485 Sale of reserves in place (154 ) — (24,834 ) (25,759 ) Production (502 ) (3,871 ) (16,617 ) (23,501 ) Proved reserves as of December 31, 2016 1,397 26,575 80,524 115,481 Revisions of previous estimates 308 (7,269 ) 381 (5,040 ) Extensions, discoveries and other additions 777 4,565 64,704 73,931 Purchase of producing properties 48 — 473 761 Sale of reserves in place (90 ) — (1,033 ) (1,573 ) Production (592 ) (4,450 ) (19,611 ) (27,613 ) Proved reserves as of December 31, 2017 1,848 19,421 125,438 155,947 Revisions of previous estimates 130 (1,469 ) 2,737 2,044 Extensions, discoveries and other additions 41 2,929 7,947 11,121 Sale of reserves in place (507 ) (486 ) (13,945 ) (17,472 ) Production (326 ) (3,373 ) (16,013 ) (21,335 ) Proved reserves as of December 31, 2018 1,186 17,022 106,164 130,305 Proved developed reserves As of December 31, 2016 1,212 13,073 47,349 67,694 As of December 31, 2017 1,078 12,564 57,409 76,441 As of December 31, 2018 567 10,220 47,516 61,143 Proved undeveloped reserves As of December 31, 2016 185 13,502 33,175 47,787 As of December 31, 2017 770 6,857 68,029 79,506 As of December 31, 2018 619 6,802 58,648 69,162
Standardized measure of discounted future cash flows	Standardized Measure December 31, 2018 2017 2016 Future cash flows $ 482,766 $ 539,244 $ 299,035 Future production costs (171,999 ) (184,171 ) (117,283 ) Future development costs (73,258 ) (128,447 ) (83,720 ) Future income taxes — — — Future net cash flows 237,509 226,626 98,032 10% annual discount (113,484 ) (99,329 ) (30,763 ) Standardized measure of discounted future net cash flows $ 124,025 $ 127,297 $ 67,269
Schedule of changes in standardized measure of discounted future net cash flows	Changes in Standardized Measure Year Ended December 31, 2018 2017 2016 Standardized measure at beginning of year $ 127,297 $ 67,269 $ 127,685 Sales and transfers of oil and gas produced, net of production costs (64,148 ) (70,362 ) (35,993 ) Changes in price, net of future production costs 18,542 53,516 (30,427 ) Extensions and discoveries, net of future production and development costs 2,983 50,977 864 Changes in estimated future development costs, net of development costs incurred during this period 16,241 17,144 26,356 Revisions of quantity estimates 2,755 (7,482 ) (14,889 ) Accretion of discount 12,730 6,727 12,769 Purchase of reserves in place — 549 — Sale of reserves in place 1,614 (1,305 ) (16,701 ) Changes in production rates (timing) and other 6,011 10,264 (2,395 ) Net increase (decrease) in standardized measure (3,272 ) 60,028 (60,416 ) Standardized measure at end of year $ 124,025 $ 127,297 $ 67,269
Average sales price and average production costs	The historical twelve-month, first day of the month, average prices of oil, gas and natural gas liquids used in determining standardized measure were: 2018 2017 2016 Oil, $/Bbl $68.71 $52.49 $40.85 Ngls, $/Mcfe 4.08 3.23 2.40 Natural Gas, $/Mcf 3.13 3.03 1.82

Summarized Quarterly Financia_2

Summarized Quarterly Financial Information - Unaudited (Tables)	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Summarized quarterly financial information is as follows (amounts in thousands except per share data): Quarter Ended March 31 June 30 September 30 December 31 2018 Revenues $ 24,917 $ 21,507 $ 20,886 $ 19,789 Income (loss) from operations (821 ) (1,326 ) (3,657 ) 701 Loss available to common stockholders (2,212 ) (2,611 ) (4,979 ) $ (4,117 ) Loss per share: Basic $ (0.09 ) $ (0.10 ) $ (0.19 ) $ (0.16 ) Diluted $ (0.09 ) $ (0.10 ) $ (0.19 ) $ (0.16 ) 2017 Revenues $ 20,772 $ 24,251 $ 28,184 $ 35,080 Income (loss) from operations (3,633 ) (2,289 ) (1,885 ) 221 Loss available to common stockholders (4,918 ) (3,385 ) (3,085 ) (389 ) Loss per share: Basic $ (0.23 ) $ (0.16 ) $ (0.15 ) $ (0.02 ) Diluted $ (0.23 ) $ (0.16 ) $ (0.15 ) $ (0.02 )

Organization and Summary of S_4

Organization and Summary of Significant Accounting Policies - Other Property and Equipment (Details) - Furniture and Fixtures	12 Months Ended
	Dec. 31, 2018
Minimum
Property, Plant and Equipment [Line Items]
Useful life (in years)	3 years
Maximum
Property, Plant and Equipment [Line Items]
Useful life (in years)	5 years

Organization and Summary of S_5

Organization and Summary of Significant Accounting Policies - Revenue Recognition (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disaggregation of Revenue [Line Items]
Revenue receivable	$ 6,364				$ 15,340				$ 6,364	$ 15,340
Revenues	19,789	$ 20,886	$ 21,507	$ 24,917	$ 35,080	$ 28,184	$ 24,251	$ 20,772	87,099	108,287	$ 66,667
Total oil sales
Disaggregation of Revenue [Line Items]
Revenue receivable	1,100								1,100
Revenues									21,027	31,258	20,614
Total gas sales
Disaggregation of Revenue [Line Items]
Revenue receivable	4,800								4,800
Revenues									50,768	60,922	37,963
Total ngl sales
Disaggregation of Revenue [Line Items]
Revenue receivable	$ 500								500
Revenues									$ 15,303	$ 16,107	$ 8,090
Minimum
Disaggregation of Revenue [Line Items]
Revenue recognized, period									1 month
Maximum
Disaggregation of Revenue [Line Items]
Revenue recognized, period									2 months

Organization and Summary of S_6

Organization and Summary of Significant Accounting Policies - Concentrations (Details) - Oil and Gas Revenue - Customer Concentration Risk	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Superior Natural Gas
Concentration Risk [Line Items]
Net oil and gas revenues (percent)	26.00%	29.00%	14.00%
Shell Trading Company
Concentration Risk [Line Items]
Net oil and gas revenues (percent)	21.00%	24.00%	23.00%
Texla Energy Management
Concentration Risk [Line Items]
Net oil and gas revenues (percent)	16.00%
Harvest Pipeline Company
Concentration Risk [Line Items]
Net oil and gas revenues (percent)	12.00%
Laclede Energy Resources
Concentration Risk [Line Items]
Net oil and gas revenues (percent)			17.00%
BG Group
Concentration Risk [Line Items]
Net oil and gas revenues (percent)			10.00%

Organization and Summary of S_7

Organization and Summary of Significant Accounting Policies - Other Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deposit for surety bonds	$ 3,550	$ 8,300
Other Noncurrent Assets
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deposit for surety bonds		$ 8,300

Acquisitions and Divestitures (

Acquisitions and Divestitures (Details) $ in Thousands, shares in Millions	Jan. 31, 2018USD ($)	Dec. 20, 2017USD ($)a	Jan. 31, 2018USD ($)	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)	Dec. 15, 2017USD ($)	Apr. 17, 2017USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Decrease in asset retirement obligation liabilities related to divestiture of oil and gas properties				$ 28,234	$ 248
Deposit for surety bonds				3,550	$ 8,300
Interests in East Lake Verret Field
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration received from sale							$ 2,200
Saltwater Disposal Assets in East Texas
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration received from sale						$ 8,500
Gulf of Mexico Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Purchase commitment	$ 3,800		$ 3,800
Decrease in asset retirement obligation liabilities related to divestiture of oil and gas properties			$ 28,200
Proceeds from refunds related to disposal	4,500
Deposit for surety bonds				3,600
Austin Chalk Acreage
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Acres acquired | a		24,600
Purchase price		$ 9,300		$ 15,000
Common shares issued in connection with acquisition | shares				2
Pro Forma | Gulf of Mexico Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Decrease in asset retirement obligation liabilities related to divestiture of oil and gas properties	$ 28,200

Voluntary Reorganization unde_3

Voluntary Reorganization under Chapter 11 of the Bankruptcy Code - Additional Information (Details) - Payment in Kind (PIK) Note - 10% Senior Secured PIK Notes due 2021 - USD ($) $ in Millions	Sep. 27, 2016	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Stated interest rate		10.00%	10.00%
PIK Interest
Class of Stock [Line Items]
Stated interest rate		10.00%
Cash interest payment due		$ 14.2
September Exchange and Consent Solicitation | PIK Interest
Class of Stock [Line Items]
Stated interest rate	1.00%
Basis spread on variable rate	9.00%

Voluntary Reorganization unde_4

Voluntary Reorganization under Chapter 11 of the Bankruptcy Code - Chapter 11 (Details) - USD ($)	Feb. 08, 2019	Dec. 28, 2017	Dec. 31, 2018	Nov. 06, 2018	Dec. 31, 2017
Restructuring Cost and Reserve [Line Items]
Post petition professional fees relating to Chapter 11 Cases			$ 3,800,000
Reorganization items related to adjustments to certain claims relating to Chapter 11 Cases			500,000
Liabilities Subject to Compromise [Abstract]
Accrued interest			20,624,000
Accounts payable to vendors			874,000
Other long-term liabilities			510,000
Other accrued liabilities			2,724,000
Preferred stock dividend payable			14,649,000
Liabilities subject to compromise			$ 323,854,000		$ 0
10% Senior Secured Notes due 2021
Restructuring Cost and Reserve [Line Items]
New shares issued (in shares)		2,200,000
10% Senior Secured Notes due 2021 | Restructuring Support Agreement
Restructuring Cost and Reserve [Line Items]
Debt instrument, ownership percentage				81.83%
Stated interest rate				10.00%
10% Senior Secured PIK Notes due 2021 | Restructuring Support Agreement
Restructuring Cost and Reserve [Line Items]
Debt instrument, ownership percentage				84.76%
Stated interest rate				10.00%
Payment in Kind (PIK) Note | 10% Senior Secured PIK Notes due 2021
Restructuring Cost and Reserve [Line Items]
Stated interest rate			10.00%		10.00%
Liabilities Subject to Compromise [Abstract]
10% Senior Secured Notes			$ 275,046,000
Senior Notes | 10% Senior Secured Notes due 2021
Restructuring Cost and Reserve [Line Items]
Stated interest rate			10.00%		10.00%
Liabilities Subject to Compromise [Abstract]
10% Senior Secured Notes			$ 9,427,000
Subsequent Event | Payment in Kind (PIK) Note | 10% Secured PIK Notes due 2024
Restructuring Cost and Reserve [Line Items]
Stated interest rate	10.00%
Principal amount	$ 80,000,000
Subsequent Event | Payment in Kind (PIK) Note | Former Holders Of Old Notes | 10% Secured PIK Notes due 2024 | Cancellation And Discharge Of Old Notes
Restructuring Cost and Reserve [Line Items]
Principal amount	80,000,000
Term Loan | Subsequent Event | Line of Credit | Exit Facility
Restructuring Cost and Reserve [Line Items]
Maximum borrowing capacity	$ 50,000,000
Class A Common Stock | Common Stock | Subsequent Event | Commitment To Backstop Exit Facility
Restructuring Cost and Reserve [Line Items]
New shares issued (in shares)	300,000
Class A Common Stock | Common Stock | Subsequent Event | 2019 Long Term Incentive Plan
Restructuring Cost and Reserve [Line Items]
Number of shares reserved for issuance (in shares)	1,344,000
Class A Common Stock | Common Stock | Subsequent Event | Former Holders Of Old Notes | Cancellation And Discharge Of Old Notes
Restructuring Cost and Reserve [Line Items]
New shares issued (in shares)	8,900,000
Class B Common Stock | Common Stock | Subsequent Event | Class B Holder
Restructuring Cost and Reserve [Line Items]
New shares issued (in shares)	1
Class C Common Stock | Common Stock | Subsequent Event | Class C Holder
Restructuring Cost and Reserve [Line Items]
New shares issued (in shares)	1

Equity - Common Stock (Details)

Equity - Common Stock (Details) shares in Millions	12 Months Ended
	Dec. 31, 2018shares
Austin Chalk Acreage
Class of Stock [Line Items]
Common shares issued in connection with acquisition	2

Equity - Convertible Preferred

Equity - Convertible Preferred Stock (Details)	12 Months Ended
	Dec. 31, 2018USD ($)payment$ / sharesRateshares	Dec. 31, 2017USD ($)shares
Class of Stock [Line Items]
Preferred stock, shares outstanding | shares	1,495,000	1,495,000
Dividends payable | $	$ 0	$ 10,278,000
Series B Preferred Stock
Class of Stock [Line Items]
Preferred stock, shares outstanding | shares	1,495,000
Series B cumulative convertible perpetual preferred stock interest rate | Rate	6.875%
Number of deferred dividend payments | payment	11
Number of trading days	20 days
Number of consecutive trading days	30 years
Closing price as percentage of conversion price	130.00%
Series B Preferred Stock converted into common stock (in shares) | shares	0.860825
Initial conversion price of common stock (in usd per share) | $ / shares	$ 58.08
Trading day averaging period for determining conversion value	20 days
Conversion rate numerator for Preferred Stock | $	$ 50
Other long-term liabilities | Series B Preferred Stock
Class of Stock [Line Items]
Dividends payable | $	$ 14,600,000

Earnings Per Share - Reconcilia

Earnings Per Share - Reconciliation Between Basic and Diluted EPS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
A reconciliation between basic and diluted earnings per share computations
Net loss available to common stockholders	$ (4,117)	$ (4,979)	$ (2,611)	$ (2,212)	$ (389)	$ (3,085)	$ (3,385)	$ (4,918)	$ (13,919)	$ (11,776)	$ (96,245)
Net loss available to common stockholders (in shares)									25,581	21,330	18,354
Net loss available to common stockholders (in usd per share)	$ (0.16)	$ (0.19)	$ (0.10)	$ (0.09)	$ (0.02)	$ (0.15)	$ (0.16)	$ (0.23)	$ (0.54)	$ (0.55)	$ (5.24)
Stock options, effect of dilutive securities									$ 0	$ 0
Stock options, effect of dilutive securities, (in shares)									0	0
Attributable to participating securities									$ 0	$ 0
Restricted stock, effect of dilutive securities (in shares)									0	0	0
DILUTED EPS, Loss									$ (13,919)	$ (11,776)	$ (96,245)
DILUTED EPS (in shares)									25,581	21,330	18,354
DILUTED EPS, per share amount (in usd per share)	$ (0.16)	$ (0.19)	$ (0.10)	$ (0.09)	$ (0.02)	$ (0.15)	$ (0.16)	$ (0.23)	$ (0.54)	$ (0.55)	$ (5.24)

Earnings Per Share - Additional

Earnings Per Share - Additional Information (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock issuable on conversion (in shares)	2	1.6	0.9
Convertible preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock issuable on conversion (in shares)	1.3

Share-Based Compensation - Shar

Share-Based Compensation - Share based Compensation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Summary of share-based compensation
Share-based compensation	$ 725	$ 1,649	$ 1,687
Incentive Stock Options (share settled)
Summary of share-based compensation
Share-based compensation	407	820	206
Non-Qualified Stock Options (share settled)
Summary of share-based compensation
Share-based compensation	94	387	164
Restricted stock (share settled)
Summary of share-based compensation
Share-based compensation	465	197	1,073
Cash settled stock units
Summary of share-based compensation
Share-based compensation	$ (241)	$ 245	$ 244

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) $ / shares in Units, $ in Thousands	1 Months Ended		12 Months Ended
	Nov. 30, 2017shares	Nov. 30, 2014shares	Dec. 31, 2018USD ($)companyshares	Dec. 31, 2017USD ($)$ / sharesshares	Dec. 31, 2016USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation costs capitalized in period				$ 103	$ 106
Tax benefit from compensation expense			$ 101	270	512
Deferred tax assets, operating loss carryforwards			86,046	78,541
Total compensation cost not yet recognized			400
Fair value of stock options that vested during period			$ 1,200	$ 1,600	400
Vested/Paid (in shares) | shares			(330,838)
Granted (in shares) | shares			0
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period until vesting			1 year
Granted (in dollars per share) | $ / shares				$ 1.87
Total value of stock that vested			$ 100	$ 1,300	$ 2,400
Vested/Paid (in shares) | shares			(37,500)
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
Period until vesting			1 year
Award expiration period			10 years
Cash settled stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
Total value of stock that vested			$ 24	$ 59
Vested/Paid (in shares) | shares			(323,374)	(31,703)
Granted (in shares) | shares			0
Market Based Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Annual vesting percentage			33.33%
Vested/Paid (in shares) | shares			(7,464)
Granted (in shares) | shares	270,269	60,767	0
Evaluation period (in days)			20 days
Number of peer group companies | company			12
Earned at end of performance period, percent				50.00%
Restricted Stock Units (RSUs) And Market Based Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred compensation share-based arrangements, liability, current				$ 300
Prior to 2011 | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Annual vesting percentage			25.00%
Minimum | Market Based Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Earning percentage			0.00%
Maximum | Market Based Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Earning percentage			200.00%
Accounting Standards Update 2016-09
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred tax assets, operating loss carryforwards				$ 4,700

Share-Based Compensation - Fair

Share-Based Compensation - Fair Value Assumption (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Stock options granted (shares)	0
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Dividend yield		0.00%	0.00%
Expected volatility		80.44%
Risk-free rate		1.925%
Expected term		6 years	6 years
Stock options granted (shares)	0	219,130	1,168,754
Weighted average grant date fair value (usd per share)		$ 1.28	$ 1.96
Fair value of grants		$ 280	$ 2,293
Minimum | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected volatility			62.00%
Risk-free rate			1.255%
Maximum | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected volatility			79.99%
Risk-free rate			2.09%

Share-Based Compensation - Acti

Share-Based Compensation - Activity (Details) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)$ / sharesshares
Number of Options
Outstanding at beginning of year (in shares) | shares	1,608,646
Granted (in shares) | shares	0
Expired/canceled/forfeited (in shares) | shares	(121,823)
Exercised (in shares) | shares	0
Outstanding at end of year (in shares) | shares	1,486,823
Wgtd. Avg. Exercise Price
Outstanding at beginning of year (in dollars per share) | $ / shares	$ 6.20
Granted (in dollars per share) | $ / shares	0
Expired/canceled/forfeited (in dollars per share) | $ / shares	4.98
Exercised (in dollars per share) | $ / shares	0
Outstanding at end of year (in dollars per share) | $ / shares	$ 6.34
Additional Disclosures
Options exercisable at end of year (in shares) | shares	1,047,590
Options exercisable at end of year (usd per share) | $ / shares	$ 7.78
Outstanding, remaining contractual term	7 years 11 days
Exercisable, remaining contractual term	6 years 7 months 21 days
Outstanding, intrinsic value | $	$ 0
Exercisable, intrinsic value | $	$ 0

Share-Based Compensation - Exer

Share-Based Compensation - Exercise Prices (Details) - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Outstanding at end of year (in shares)	1,486,823	1,608,646
Wgtd. Avg. Remaining Contractual Life	7 years 11 days
Wgtd. Avg. Exercise Price (in dollars per share)	$ 6.34	$ 6.20
Options exercisable (in shares)	1,047,590
Wgtd. Avg. Exercise Price (usd per share)	$ 7.78
$0.00-$2.37
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price range, lower range limit	0
Exercise price range, upper range limit	$ 2.37
Outstanding at end of year (in shares)	250,477
Wgtd. Avg. Remaining Contractual Life	8 years 5 months 5 days
Wgtd. Avg. Exercise Price (in dollars per share)	$ 1.99
Options exercisable (in shares)	105,780
Wgtd. Avg. Exercise Price (usd per share)	$ 2.07
$3.17-$4.36
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price range, lower range limit	3.17
Exercise price range, upper range limit	$ 4.36
Outstanding at end of year (in shares)	1,013,663
Wgtd. Avg. Remaining Contractual Life	7 years 8 months 5 days
Wgtd. Avg. Exercise Price (in dollars per share)	$ 3.37
Options exercisable (in shares)	719,127
Wgtd. Avg. Exercise Price (usd per share)	$ 3.36
$16.72-$19.52
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price range, lower range limit	16.72
Exercise price range, upper range limit	$ 19.52
Outstanding at end of year (in shares)	68,190
Wgtd. Avg. Remaining Contractual Life	4 years 5 months 1 day
Wgtd. Avg. Exercise Price (in dollars per share)	$ 17.11
Options exercisable (in shares)	68,190
Wgtd. Avg. Exercise Price (usd per share)	$ 17.11
$20.40-$30.32
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price range, lower range limit	20.40
Exercise price range, upper range limit	$ 30.32
Outstanding at end of year (in shares)	154,493
Wgtd. Avg. Remaining Contractual Life	1 year 8 months 23 days
Wgtd. Avg. Exercise Price (in dollars per share)	$ 28.15
Options exercisable (in shares)	154,493
Wgtd. Avg. Exercise Price (usd per share)	$ 28.15

Share-Based Compensation - Rest

Share-Based Compensation - Restricted Stock (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Number of Shares
Outstanding at beginning of year (in shares)	1,167,320
Canceled/forfeited (in shares)	(349,077)
Lapse of restrictions (in shares)	(330,838)
Outstanding at end of year (in shares)	487,405	1,167,320
Restricted Stock
Number of Shares
Outstanding at beginning of year (in shares)	487,502
Canceled/forfeited (in shares)	(34,946)
Lapse of restrictions (in shares)	(37,500)
Outstanding at end of year (in shares)	415,056	487,502
Wgtd. Avg. Fair Value per Share
Outstanding at beginning of year (in dollars per share)	$ 1.87
Cancelled/forfeited (in dollars per share)	1.85
Lapse of restrictions (in dollars per share)	2.15
Outstanding at end of year (in dollars per share)	$ 1.85	$ 1.87
Additional Information
Weighted average grant date fair value (in dollars per share)		$ 1.87
Total value of stock that vested	$ 0.1	$ 1.3	$ 2.4

Share-Based Compensation - Re_2

Share-Based Compensation - Restricted Stock Units (Details) - shares	1 Months Ended		12 Months Ended
	Nov. 30, 2017	Nov. 30, 2014	Dec. 31, 2018	Dec. 31, 2017
Number of Shares
Outstanding at beginning of year (in shares)			1,167,320
Granted (in shares)			0
Canceled/forfeited (in shares)			(349,077)
Vested/Paid (in shares)			(330,838)
Outstanding at end of year (in shares)			487,405	1,167,320
MRSU
Number of Shares
Outstanding at beginning of year (in shares)			277,733
Granted (in shares)	270,269	60,767	0
Canceled/forfeited (in shares)			(270,269)
Vested/Paid (in shares)			(7,464)
Outstanding at end of year (in shares)			0	277,733
RSU
Number of Shares
Outstanding at beginning of year (in shares)			889,587
Granted (in shares)			0
Canceled/forfeited (in shares)			(78,808)
Vested/Paid (in shares)			(323,374)	(31,703)
Outstanding at end of year (in shares)			487,405	889,587

Asset Retirement Obligation (De

Asset Retirement Obligation (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Jan. 31, 2018	Dec. 31, 2018	Dec. 31, 2017
Changes to the Company's asset retirement obligation liability
Asset retirement obligation, beginning of period	$ 31,310	$ 31,310	$ 36,610
Liabilities incurred		7	574
Liabilities settled		(863)	(3,364)
Accretion expense		322	2,252
Revisions in estimated cash flows		(62)	(4,514)
Divestiture of oil and gas properties		(28,234)	(248)
Asset retirement obligation, end of period		2,480	31,310
Less: current portion of asset retirement obligation		(183)	(687)
Long-term asset retirement obligation		$ 2,297	$ 30,623
Gulf of Mexico Properties
Changes to the Company's asset retirement obligation liability
Divestiture of oil and gas properties	$ (28,200)

Derivative Instruments - Effect

Derivative Instruments - Effect of Cash Flow Hedges on the Balance Sheet (Details) - Designated as Hedging Instrument - Commodity Derivatives $ in Thousands	Dec. 31, 2017USD ($)
Derivative asset
Effect of Cash Flow Hedges on the Consolidated Balance Sheet
Derivative asset	$ 1,174
Derivative liability
Effect of Cash Flow Hedges on the Consolidated Balance Sheet
Derivative liability	$ (731)

Derivative Instruments - Effe_2

Derivative Instruments - Effect of Cash Flow Hedges on the Statement of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Other Comprehensive Income	$ (278)	$ 5,028	$ (5,697)
Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Other Comprehensive Income	(990)	6,654	(4,447)
Designated as Hedging Instrument | Oil and gas sales
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified into Income	$ (622)	$ 1,461	$ 1,811

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - USD ($)	Jun. 14, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Gas hedges
Derivatives, Fair Value [Line Items]
Net settlement of hedges		$ 800,000	$ 1,500,000	$ 1,800,000
Crude Oil
Derivatives, Fair Value [Line Items]
Net settlement of hedges		$ (1,427,540)	$ 0	$ 0
Koch Supply & Trading LP
Derivatives, Fair Value [Line Items]
Net settlement of hedges	$ 500,000

Fair Value Measurements - Commo

Fair Value Measurements - Commodity Derivatives at Fair Value (Details) $ in Thousands	Dec. 31, 2017USD ($)
Quoted Prices in Active Markets (Level 1)
Net valuation of the Company's derivatives subject to fair value measurement on a recurring basis
Commodity derivatives	$ 0
Significant Other Observable Inputs (Level 2)
Net valuation of the Company's derivatives subject to fair value measurement on a recurring basis
Commodity derivatives	443
Significant Unobservable Inputs (Level 3)
Net valuation of the Company's derivatives subject to fair value measurement on a recurring basis
Commodity derivatives	$ 0

Fair Value Measurements - Fair

Fair Value Measurements - Fair Value and Carrying Value (Details) - Fair Value - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Senior Notes | 2021 Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt, fair value	$ 2.8	$ 7.3
Payment in Kind (PIK) Note | 2021 PIK Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt, fair value	$ 82.5	$ 198.7

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details) shares in Millions

Sep. 14, 2018USD ($)

Aug. 31, 2018USD ($)

Dec. 28, 2017USD ($)shares

Mar. 31, 2017USD ($)

Sep. 27, 2016USD ($)paymentshares

Feb. 17, 2016USD ($)shares

Dec. 31, 2018USD ($)

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Nov. 06, 2018

Sep. 30, 2018

Oct. 17, 2016USD ($)

Jan. 14, 2016

Jul. 03, 2013USD ($)

Aug. 19, 2010USD ($)

Debt Instrument [Line Items]

Gain (loss) on extinguishment of debt

$ 0

$ 403,000

$ 0

10% Senior Unsecured Notes Due 2017

Debt Instrument [Line Items]

Repayments of debt

$ 22,800,000

10% Senior Unsecured Notes Due 2017 | Senior Notes

Debt Instrument [Line Items]

Principal amount

$ 200,000,000

$ 150,000,000

Stated interest rate

10.00%

10.00%

Long-term debt

$ 135,600,000

10% Senior Secured Notes due 2021

Debt Instrument [Line Items]

Debt extinguished

$ 4,800,000

Common shares issued related to extinguishment of debt | shares

2.2

10% Senior Secured Notes due 2021 | Senior Notes

Debt Instrument [Line Items]

Stated interest rate

10.00%

10.00%

10% Senior Secured PIK Notes due 2021 | Payment in Kind (PIK) Note

Debt Instrument [Line Items]

Stated interest rate

10.00%

10.00%

10% Senior Secured PIK Notes due 2021 | PIK Interest | Payment in Kind (PIK) Note

Debt Instrument [Line Items]

Stated interest rate

10.00%

10 Percent Senior Notes And PIK Notes Due 2021 | Senior Notes

Debt Instrument [Line Items]

Loan forbearance, non payment of interest, period

30 days

Private Exchange Offer and Consent Solicitation

Debt Instrument [Line Items]

Repayments of debt

53,600,000

Private Exchange Offer and Consent Solicitation | 10% Senior Unsecured Notes Due 2017 | Senior Notes

Debt Instrument [Line Items]

Debt conversion, original debt, amount

$ 214,400,000

Debt conversion, original debt, percent of total

61.00%

Gain (loss) on extinguishment of debt

$ 0

Private Exchange Offer and Consent Solicitation | 10% Senior Secured Notes due 2021 | Senior Notes

Debt Instrument [Line Items]

Stated interest rate

10.00%

Debt conversion, converted instrument, amount

144,700,000

Long-term debt

$ 13,900,000

Private Exchange Offer and Consent Solicitation | 10% Senior Secured PIK Notes due 2021 | Payment in Kind (PIK) Note

Debt Instrument [Line Items]

Stated interest rate

10.00%

Excess (shortfall) carrying value

$ (600,000)

September Exchange and Consent Solicitation | 10% Senior Unsecured Notes Due 2017 | Senior Notes

Debt Instrument [Line Items]

Debt conversion, original debt, amount

$ 113,000,000

Debt conversion, original debt, percent of total

83.00%

Long-term debt

$ 22,700,000

September Exchange and Consent Solicitation | 10% Senior Secured Notes due 2021 | Senior Notes

Debt Instrument [Line Items]

Debt conversion, original debt, amount

$ 130,500,000

Debt conversion, original debt, percent of total

90.00%

Long-term debt

$ 14,200,000

September Exchange and Consent Solicitation | 10% Senior Secured PIK Notes due 2021 | Payment in Kind (PIK) Note

Debt Instrument [Line Items]

Debt conversion, converted instrument, amount

$ 243,500,000

Number of interest payments with variable rate | payment

3

September Exchange and Consent Solicitation | 10% Senior Secured PIK Notes due 2021 | PIK Interest | Payment in Kind (PIK) Note

Debt Instrument [Line Items]

Stated interest rate

1.00%

Adjusted LIBO rate (as a percent)

9.00%

Common Stock | Private Exchange Offer and Consent Solicitation

Debt Instrument [Line Items]

Debt conversion, converted instrument, shares issued | shares

3.5

1.1

Term Loan | Line of Credit

Debt Instrument [Line Items]

Deferred finance costs

$ (300,000)

$ (2,000,000)

Term Loan | Loan Agreement | Line of Credit

Debt Instrument [Line Items]

Repayments of debt

$ 32,500,000

Term Loan | Multidraw Term Loan Agreement | Line of Credit

Debt Instrument [Line Items]

Remaining borrowing capacity

$ 0

Long-term debt

$ 50,000,000

Revolving credit facility

$ 50,000,000

2021 Notes Supporting Holders | Forbearance Agreement | Senior Notes

Debt Instrument [Line Items]

Long-term debt

$ 7,300,000

Outstanding principal amount, percent

77.90%

2021 PIK Notes Supporting Holders | Forbearance Agreement | Payment in Kind (PIK) Note

Debt Instrument [Line Items]

Long-term debt

$ 194,600,000

Outstanding principal amount, percent

70.70%

Restructuring Support Agreement | 10% Senior Secured Notes due 2021

Debt Instrument [Line Items]

Stated interest rate

10.00%

Restructuring Support Agreement | 10% Senior Secured PIK Notes due 2021

Debt Instrument [Line Items]

Stated interest rate

10.00%

Long-Term Debt - Face Value to

Long-Term Debt - Face Value to Carrying Value Reconciliation (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017	Feb. 17, 2016	Jul. 03, 2013	Aug. 19, 2010
Senior Notes | 10% Senior Unsecured Notes Due 2017
Debt Instrument [Line Items]
Principal amount				$ 200,000,000	$ 150,000,000
Long-term debt			$ 135,600,000
Term Loan | Line of Credit
Debt Instrument [Line Items]
Unamortized deferred finance costs	$ (300,000)	$ (2,000,000)

Long-Term Debt - Exit Facility

Long-Term Debt - Exit Facility (Details) - Subsequent Event	Feb. 08, 2019USD ($)
Payment in Kind (PIK) Note | 10% Secured PIK Notes due 2024
Debt Instrument [Line Items]
Stated interest rate	10.00%
Principal amount	$ 80,000,000
Payment in Kind (PIK) Note | 10% Secured PIK Notes due 2024 | February 8, 2019 to February 7, 2020
Debt Instrument [Line Items]
Redemption price, percentage	102.00%
Payment in Kind (PIK) Note | 10% Secured PIK Notes due 2024 | February 8, 2020 to February 7, 2021
Debt Instrument [Line Items]
Redemption price, percentage	101.00%
Payment in Kind (PIK) Note | 10% Secured PIK Notes due 2024 | February 8, 2021 and thereafter
Debt Instrument [Line Items]
Redemption price, percentage	100.00%
Payment in Kind (PIK) Note | 10% Secured PIK Notes due 2024 | Upon occurrence of change of control events
Debt Instrument [Line Items]
Redemption price, percentage	101.00%
Term Loan | Line of Credit | Exit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 50,000,000
Present value of estimated future net revenues, discount percent	10.00%
Ratio of present value of estimated future net revenues to sum of outstanding term loans and commitments	1.5
Term Loan | Line of Credit | Exit Facility | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Stated interest rate	7.50%
Term Loan | Line of Credit | Exit Facility | Base Rate
Debt Instrument [Line Items]
Stated interest rate	6.50%

Related Party Transactions (Det

Related Party Transactions (Details) - Officer $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)party	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Related Party Transaction [Line Items]
Number of related parties | party	2
Mr. Goodson
Related Party Transaction [Line Items]
Proceeds from affiliates	$ 0	$ (107)	$ (15)
Mr. Green
Related Party Transaction [Line Items]
Payments of distributions to related parties	$ 20	$ 41	$ 25

Ceiling Test Write-down (Detail

Ceiling Test Write-down (Details)	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)$ / mcf$ / bbl$ / Mcfe
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Rate for discounting future cash flows	10.00%
Ceiling test write-down	$ 0	$ 0	$ 40,304,000
Mcf of natural gas
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Average sales prices (usd per unit) | $ / mcf			2.51
Barrel of oil
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Average sales prices (usd per unit) | $ / bbl			40.85
Mcfe of natural gas liquids
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Average sales prices (usd per unit) | $ / Mcfe			1.82
Cash Flow Hedging | Commodity Contract
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Ceiling test write-downs decrease			$ 8,000,000

Other Comprehensive Income (L_3

Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	$ (248,935)	$ (251,095)	$ (163,067)
Other comprehensive income before reclassifications:
Change in fair value of derivatives		6,654	(4,447)
Income tax effect		(708)	0
Net of tax		5,946	(4,447)
Amounts reclassified from accumulated other comprehensive income:
Oil and gas sales		(1,461)	(1,811)
Income tax effect		543	561
Net of tax		(918)	(1,250)
Net other comprehensive loss		5,028	(5,697)
Ending balance	(262,167)	(248,935)	(251,095)
Gains and Losses on Cash Flow Hedges
Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	278	(2,983)	947
Other comprehensive income before reclassifications:
Change in fair value of derivatives	(990)	6,654	(4,447)
Income tax effect	238	(2,475)	1,654
Net of tax	(752)	4,179	(2,793)
Amounts reclassified from accumulated other comprehensive income:
Oil and gas sales	622	(1,461)	(1,811)
Income tax effect	(148)	543	674
Net of tax	474	(918)	(1,137)
Net other comprehensive loss	(278)	3,261	(3,930)
Ending balance	0	278	(2,983)
Change in Valuation Allowance
Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	0	(1,767)	0
Other comprehensive income before reclassifications:
Change in fair value of derivatives		0	0
Income tax effect		1,767	(1,654)
Net of tax		1,767	(1,654)
Amounts reclassified from accumulated other comprehensive income:
Oil and gas sales		0	0
Income tax effect		0	(113)
Net of tax		0	(113)
Net other comprehensive loss		1,767	(1,767)
Ending balance		0	(1,767)
Total
Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	278	(4,750)	947
Amounts reclassified from accumulated other comprehensive income:
Ending balance	$ 0	$ 278	$ (4,750)

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Taxes (Textual) [Abstract]
Income taxes at a statutory rate		35.00%	35.00%
Cumulative loss period	3 years
Valuation allowance	$ 118,716	$ 115,906
Tax Cuts and Jobs Act, provisional Income tax expense (benefit)		64,900
Deferred tax assets, operating loss carryforwards	86,046	78,541
Operating loss carryforwards	355,400
Operating loss carryforwards, not subject to expiration, subject to limitation	20,300
Depletion Deduction
Income Taxes (Textual) [Abstract]
Tax credit carryforward	28,200
Deductible Interest Expense [Member]
Income Taxes (Textual) [Abstract]
Tax credit carryforward	43,900
Louisiana
Income Taxes (Textual) [Abstract]
Operating loss carryforwards	180,700
Operating loss carryforwards subject to expiration	300
Accounting Standards Update 2016-09
Income Taxes (Textual) [Abstract]
Deferred tax assets, operating loss carryforwards		$ 4,700
Tax Year 2025
Income Taxes (Textual) [Abstract]
Operating loss carryforwards subject to expiration	6,900
Tax Year 2037
Income Taxes (Textual) [Abstract]
Operating loss carryforwards subject to expiration	$ 328,200

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Net operating loss carryforwards	$ 86,046	$ 78,541
Percentage depletion carryforward	6,011	5,701
Interest expense carryforward	10,540	0
Contributions carryforward and other	194	192
Oil and gas properties	3,673	8,279
Asset retirement obligation	602	7,602
Derivatives	0	(107)
Share-based compensation	1,403	1,269
Original issue discount on debt exchanges	9,815	14,429
Other	432	0
Valuation allowance	(118,716)	(115,906)
Deferred tax asset (liability)	$ 0	$ 0

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Benefit) Reconciliation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Amount computed using the statutory rate	$ (1,973)	$ (2,655)	$ (31,623)
Impact of rate change on deferred tax	0	64,915	0
State & local taxes	(1,731)	(368)	(2,000)
Percentage depletion carryforward	(256)	(66)	(163)
Non-deductible stock option expense	98	305	77
Share-based compensation	0	64	707
Restructuring costs	1,528	0	0
Other	93	(21)	1,415
Change in valuation allowance	2,393	(63,123)	32,130
Income tax expense (benefit)	$ 152	$ (949)	$ 543

Commitments and Contingencies -

Commitments and Contingencies - Litigation (Details) - Class Action Lawsuits, General Unsecured Claims - Pending Litigation	Oct. 01, 2016claim	Dec. 31, 2018USD ($)
Loss Contingencies [Line Items]
Number of claims filed | claim	2
Maximum
Loss Contingencies [Line Items]
Estimate of possible loss | $		$ 400,000

Commitments and Contingencies_2

Commitments and Contingencies - Lease Commitments (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	$ 1,240
2020	1,173
2021	445
2022	431
2023	392
Thereafter	0
Total	3,681
Operating leases rent expense	1,500
Lease amendment, decrease in rent expense	$ 1,300

Supplementary Information on _3

Supplementary Information on Oil and Gas Operations—Unaudited - Costs Incurred (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)$ / Mcfe	Dec. 31, 2017USD ($)$ / Mcfe	Dec. 31, 2016USD ($)$ / Mcfe
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Acquisition costs: Proved	$ 241	$ 1,330	$ 3,346
Acquisition costs: Unproved	6,190	12,762	2,197
Divestiture of proved leasehold	(2,604)	(4,795)	(7,000)
Exploration costs: Proved	(51)	9,466	715
Exploration costs: Unproved	233	(287)	603
Development costs (2)	(18,928)	32,622	1,522
Capitalized general and administrative and interest costs	8,070	8,269	7,558
Total costs incurred	(6,849)	59,367	8,941
Accumulated depreciation, depletion and amortization (DD&A)
Balance, beginning of year	(1,285,660)	(1,243,286)	(1,157,455)
Provision for DD&A	(22,410)	(31,667)	(27,962)
Ceiling test writedown	0	0	(40,304)
Sale of proved properties and other	6,478	(10,707)	(17,565)
Balance, end of year	$ (1,301,592)	$ (1,285,660)	$ (1,243,286)
DD&A per Mcfe (usd per mcfe) | $ / Mcfe	1.05	1.15	1.19

Supplementary Information on _4

Supplementary Information on Oil and Gas Operations—Unaudited - Investment in Oil and Gas Properties (Details) $ in Thousands, shares in Millions	Jan. 31, 2018USD ($)	Dec. 20, 2017USD ($)a	Jan. 31, 2018USD ($)	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)Wells	Dec. 31, 2016USD ($)	Dec. 15, 2017USD ($)	Apr. 17, 2017USD ($)
Reserve Quantities [Line Items]
Decrease in asset retirement obligation liabilities related to divestiture of oil and gas properties				$ 28,234	$ 248
Sale of oil and gas properties				(6,478)	10,707	$ 25,482
Unevaluated oil and gas properties				23,500	21,900
Interest costs capitalized				$ 1,800	1,600	900
Expected period to evaluate existing unevaluated properties				3 years
Unevaluated costs expected to be evaluated in 2017				$ 2,700
Uncompleted Wells Equipment and Facilities
Reserve Quantities [Line Items]
Unevaluated oil and gas properties				900	$ 700
Exploratory wells drilled, unevaluated | Wells					2
Incurred In 2017
Reserve Quantities [Line Items]
Unevaluated oil and gas properties				$ 7,400
Percentage of unevaluated costs capitalized in period				32.00%
Incurred In 2016
Reserve Quantities [Line Items]
Unevaluated oil and gas properties					$ 13,900
Percentage of unevaluated costs capitalized in period					59.00%
Incurred Prior 2016
Reserve Quantities [Line Items]
Unevaluated oil and gas properties						$ 2,200
Percentage of unevaluated costs capitalized in period						9.00%
Austin Chalk Acreage
Reserve Quantities [Line Items]
Acres acquired | a		24,600
Purchase price		$ 9,300		$ 15,000
Common shares issued in connection with acquisition | shares				2
Oklahoma Assets
Reserve Quantities [Line Items]
Consideration received from sale						$ 17,600
Gulf of Mexico Properties
Reserve Quantities [Line Items]
Decrease in asset retirement obligation liabilities related to divestiture of oil and gas properties			$ 28,200
Unevaluated oil and gas properties				$ 5,500
Percentage of unevaluated costs capitalized in period				25.00%
Interests in East Lake Verret Field
Reserve Quantities [Line Items]
Consideration received from sale								$ 2,200
Saltwater Disposal Assets in East Texas
Reserve Quantities [Line Items]
Consideration received from sale							$ 8,500
Pro Forma | Gulf of Mexico Properties
Reserve Quantities [Line Items]
Decrease in asset retirement obligation liabilities related to divestiture of oil and gas properties	$ 28,200

Supplementary Information on _5

Supplementary Information on Oil and Gas Operations—Unaudited - Proved Reserves (Details) Mcfe in Thousands, MMcf in Thousands, MBbls in Thousands	12 Months Ended
	Dec. 31, 2018McfeMBblsMMcf	Dec. 31, 2017McfeMBblsMMcf	Dec. 31, 2016McfeMBblsMMcf
Oil
Proved Developed and Undeveloped Reserves [Abstract]
Proved reserves beginning balance | MBbls	1,848	1,397	1,806
Revisions of previous estimates | MBbls	130	308	247
Extensions, discoveries and other additions | MBbls	41	777	0
Purchase of producing properties | MBbls		48
Sale of reserves in place | MBbls	(507)	(90)	(154)
Production | MBbls	(326)	(592)	(502)
Proved reserves ending balance | MBbls	1,186	1,848	1,397
Proved developed reserves | MBbls	567	1,078	1,212
Proved undeveloped reserve | MBbls	619	770	185
Mcfe of natural gas liquids
Proved Developed and Undeveloped Reserves [Abstract]
Proved reserves, ending balance	19,421	26,575	34,826
Revisions of previous estimates	(1,469)	(7,269)	(4,380)
Extensions, discoveries and other additions	2,929	4,565	0
Purchase of producing properties		0
Sale of reserves in place	(486)	0	0
Production	(3,373)	(4,450)	(3,871)
Proved reserves, ending balance	17,022	19,421	26,575
Proved undeveloped reserve	10,220	12,564	13,073
Proved developed reserves	6,802	6,857	13,502
Natural Gas
Proved Developed and Undeveloped Reserves [Abstract]
Proved reserves beginning balance | MMcf	125,438	80,524	132,344
Revisions of previous estimates | MMcf	2,737	381	(11,854)
Extensions, discoveries and other additions | MMcf	7,947	64,704	1,485
Purchase of producing properties | MMcf		473
Sale of reserves in place | MMcf	(13,945)	(1,033)	(24,834)
Production | MMcf	(16,013)	(19,611)	(16,617)
Proved reserves ending balance | MMcf	106,164	125,438	80,524
Proved developed reserves | MMcf	47,516	57,409	47,349
Proved undeveloped reserve | MMcf	58,648	68,029	33,175
Oil and Natural Gas Reserves
Proved Developed and Undeveloped Reserves [Abstract]
Proved reserves, ending balance	155,947	115,481	178,004
Revisions of previous estimates	2,044	(5,040)	(14,748)
Extensions, discoveries and other additions	11,121	73,931	1,485
Purchase of producing properties		761
Sale of reserves in place	(17,472)	(1,573)	(25,759)
Production	(21,335)	(27,613)	(23,501)
Proved reserves, ending balance	130,305	155,947	115,481
Proved undeveloped reserve	61,143	76,441	67,694
Proved developed reserves	69,162	79,506	47,787

Supplementary Information on _6

Supplementary Information on Oil and Gas Operations—Unaudited - Average Price and Text (Details) Mcfe in Thousands, MMcf in Thousands, MBbls in Thousands	12 Months Ended
	Dec. 31, 2018McfeWells$ / mcf$ / bbl$ / McfeMBblsMMcf	Dec. 31, 2017McfeWells$ / mcf$ / bbl$ / McfeMBblsMMcf	Dec. 31, 2016McfeWells$ / mcf$ / bbl$ / McfeMBblsMMcf
Reserve Quantities [Line Items]
Company drilling success rate	100.00%	100.00%	100.00%
Gross wells drilled | Wells	2	8	5
Oil
Reserve Quantities [Line Items]
Number of Bcfe additions | MBbls	41	777	0
Consolidated oil and gas production costs per unit of production | $ / bbl	68.71	52.49	40.85
Mcfe of natural gas liquids
Reserve Quantities [Line Items]
Extensions, discoveries and other additions of Bcfe	2,929	4,565	0
Consolidated oil and gas production costs per unit of production | $ / Mcfe	4.08	3.23	2.40
Oil and Natural Gas Reserves
Reserve Quantities [Line Items]
Increase in proved developed and undeveloped reserves	(16.00%)	35.04646%	(35.12449%)
Extensions, discoveries and other additions of Bcfe	11,121	73,931	1,485
Natural Gas
Reserve Quantities [Line Items]
Number of Bcfe additions | MMcf	7,947	64,704	1,485
Consolidated oil and gas production costs per unit of production | $ / mcf	3.13	3.03	1.82
Gulf of Mexico Properties | Oil and Natural Gas Reserves
Reserve Quantities [Line Items]
Removal of Bcfe	10,148
Certain PUDs In East Texas | Oil and Natural Gas Reserves
Reserve Quantities [Line Items]
Removal of Bcfe	7,324

Supplementary Information on _7

Supplementary Information on Oil and Gas Operations—Unaudited - Standardized Measure (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows [Abstract]
Future cash flows	$ 482,766	$ 539,244	$ 299,035
Future production costs	(171,999)	(184,171)	(117,283)
Future development costs	(73,258)	(128,447)	(83,720)
Future income taxes	0	0	0
Future net cash flows	237,509	226,626	98,032
10% annual discount	(113,484)	(99,329)	(30,763)
Standardized measure of discounted future net cash flows	$ 124,025	$ 127,297	$ 67,269	$ 127,685

Supplementary Information on _8

Supplementary Information on Oil and Gas Operations—Unaudited - Changes in Standardized Measure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Standardized measure at beginning of year	$ 127,297	$ 67,269	$ 127,685
Sales and transfers of oil and gas produced, net of production costs	(64,148)	(70,362)	(35,993)
Changes in price, net of future production costs	18,542	53,516	(30,427)
Extensions and discoveries, net of future production and development costs	2,983	50,977	864
Changes in estimated future development costs, net of development costs incurred during this period	16,241	17,144	26,356
Revisions of quantity estimates	2,755	(7,482)	(14,889)
Accretion of discount	12,730	6,727	12,769
Purchase of reserves in place	0	549	0
Sale of reserves in place	1,614	(1,305)	(16,701)
Changes in production rates (timing) and other	6,011	10,264	(2,395)
Net increase (decrease) in standardized measure	(3,272)	60,028	(60,416)
Standardized measure at end of year	$ 124,025	$ 127,297	$ 67,269

Summarized Quarterly Financia_3

Summarized Quarterly Financial Information - Unaudited (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 19,789	$ 20,886	$ 21,507	$ 24,917	$ 35,080	$ 28,184	$ 24,251	$ 20,772	$ 87,099	$ 108,287	$ 66,667
Loss from operations	701	(3,657)	(1,326)	(821)	221	(1,885)	(2,289)	(3,633)	(5,103)	(7,586)	(90,353)
Loss available to common stockholders	$ (4,117)	$ (4,979)	$ (2,611)	$ (2,212)	$ (389)	$ (3,085)	$ (3,385)	$ (4,918)	$ (13,919)	$ (11,776)	$ (96,245)
Loss per share, Basic (in usd per share)	$ (0.16)	$ (0.19)	$ (0.10)	$ (0.09)	$ (0.02)	$ (0.15)	$ (0.16)	$ (0.23)	$ (0.54)	$ (0.55)	$ (5.24)
Loss per share, Diluted (in usd per share)	$ (0.16)	$ (0.19)	$ (0.10)	$ (0.09)	$ (0.02)	$ (0.15)	$ (0.16)	$ (0.23)	$ (0.54)	$ (0.55)	$ (5.24)