Goodrich Petroleum 10-K 5 Mar 20 2019 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Mar. 02, 2020	Jun. 30, 2019
Document Information [Line Items]
Entity Registrant Name	GOODRICH PETROLEUM CORP
Entity Central Index Key	0000943861
Trading Symbol	gdp
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Emerging Growth Company	false
Entity Small Business	true
Entity Interactive Data Current	Yes
Entity Common Stock, Shares Outstanding (in shares)		12,532,950
Entity Public Float			$ 67.9
Entity Shell Company	false
Document Type	10-K
Document Period End Date	Dec. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false
Title of 12(b) Security	Common stock, par value $0.01 per share

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
CURRENT ASSETS:
Cash and cash equivalents	$ 1,452	$ 4,068
Accounts receivable, trade and other, net of allowance	1,131	744
Accrued oil and natural gas revenue	11,345	14,464
Fair value of oil and natural gas derivatives	8,537	803
Inventory	234	596
Prepaid expenses and other	549	533
Total current assets	23,248	21,208
PROPERTY AND EQUIPMENT:
Unevaluated properties	123	180
Oil and gas properties (full cost method)	302,859	206,097
Furniture, fixtures and equipment	4,450	1,360
	307,432	207,637
Less: Accumulated depletion, depreciation and amortization	(94,124)	(42,447)
Net property and equipment	213,308	165,190
Fair value of oil and natural gas derivatives	31
Deferred tax asset	393	786
Other	2,338	580
TOTAL ASSETS	239,318	187,764
CURRENT LIABILITIES:
Accounts payable	26,348	25,734
Accrued liabilities	16,615	16,518
Total current liabilities	42,963	42,252
Long term debt, net	104,435	76,820
Accrued abandonment costs	4,169	3,791
Fair value of oil and natural gas derivatives	2,786	471
Non-current operating lease liability	800
Total liabilities	155,153	123,334
Commitments and contingencies (See Note 10)
STOCKHOLDERS’ EQUITY:
Preferred stock: 10,000,000 shares $1.00 par value authorized, and none issued and outstanding	0	0
Common stock: $0.01 par value, 75,000,000 shares authorized, and 12,532,550 shares issued and outstanding at December 31, 2019 and $0.01 par value, 75,000,000 shares authorized, and 12,150,918 shares issued and outstanding at December 31, 2018	125	122
Additional paid-in capital	81,305	74,861
Retained earnings (deficit)	2,735	(10,553)
Total stockholders’ equity	84,165	64,430
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$ 239,318	$ 187,764

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Preferred Stock, Par Value (in dollars per share)	$ 1	$ 1
Preferred Stock, Shares Authorized (in shares)	10,000,000	10,000,000
Preferred Stock, Shares Issued (in shares)	0	0
Preferred Stock, Shares Outstanding (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	75,000,000	75,000,000
Common stock, shares issued (in shares)	12,532,550	12,150,918
Common stock, shares outstanding (in shares)	12,532,550	12,150,918

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
REVENUES:
Revenues	$ 118,350	$ 87,996
OPERATING EXPENSES:
Lease operating expense	12,371	10,446
Production and other taxes	2,573	2,605
Transportation and processing	20,703	11,046
Depreciation, depletion, and amortization	50,722	26,809
General and administrative	20,775	19,663
Other	106	7
	107,250	70,576
Operating income	11,100	17,420
OTHER INCOME (EXPENSE):
Interest expense	(11,001)	(11,944)
Interest income and other	25	508
Gain (loss) on derivatives not designated as hedges	15,010	(3,986)
Loss on early extinguishment of debt	(1,846)
	2,188	(15,422)
Reorganization items, net		(305)
Income before income taxes	13,288	1,693
Income tax benefit	0	57
Net income	$ 13,288	$ 1,750
PER COMMON SHARE:
Net income per common share—basic (in dollars per share)	$ 1.09	$ 0.15
Net income per common share—diluted (in dollars per share)	$ 0.96	$ 0.13
Weighted average shares of common stock outstanding—basic (in shares)	12,233	11,622
Weighted average shares of common stock outstanding—diluted (in shares)	13,895	13,665
Oil and Gas [Member]
REVENUES:
Revenues	$ 118,353	$ 87,943
Service, Other [Member]
REVENUES:
Revenues	$ (3)	$ 53

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 13,288	$ 1,750
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, and amortization	50,722	26,809
Right of use asset depreciation	1,252
Deferred income taxes		(57)
(Gain) loss on derivatives not designated as hedges	(15,010)	3,986
Net cash received (paid) in settlement of derivative instruments	9,560	(3,236)
Share-based compensation (non-cash)	6,400	6,545
Loss on early extinguishment of debt	1,846
Amortization of finance cost, debt discount, paid-in-kind interest and accretion	7,097	10,983
Reorganization items (non-cash)		(476)
Loss (gain) from material transfers & inventory sales & write-downs	327	(32)
Change in assets and liabilities:
Accounts receivable, trade and other, net of allowance	6	835
Accrued oil and natural gas revenue	3,119	(9,506)
Inventory	35
Prepaid expenses and other	(45)	(249)
Accounts payable	614	8,530
Accrued liabilities	(140)	3,304
Net cash provided by operating activities	79,071	49,186
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(99,301)	(105,088)
Proceeds from sale of assets	1,334	26,839
Net cash used in investing activities	(97,967)	(78,249)
CASH FLOWS FROM FINANCING ACTIVITIES:
Principal payments of bank borrowings	(49,500)	(16,723)
Proceeds from bank borrowings	115,400	27,000
Repayment of Convertible Second Lien Notes	(56,728)
Proceeds from New 2L Notes	12,000
Issuance cost, net	(2,795)	(49)
Other including purchase of treasury stock	(2,097)	(3,089)
Net cash provided by financing activities	16,280	7,139
Decrease in cash and cash equivalents	(2,616)	(21,924)
Cash and cash equivalents, beginning of period	4,068	25,992
Cash and cash equivalents, end of period	1,452	4,068
Supplemental disclosures of cash flow information:
Cash paid during the year for interest	4,137	575
Cash paid during the year for taxes
Decrease in non-cash capital expenditures	$ (1,911)	$ (2,425)

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity/(Deficit) - USD ($) $ in Thousands	Convertible Second Lien Notes [Member]Preferred Stock [Member]	Convertible Second Lien Notes [Member]Common Stock [Member]	Convertible Second Lien Notes [Member]Additional Paid-in Capital [Member]	Convertible Second Lien Notes [Member]Treasury Stock [Member]	Convertible Second Lien Notes [Member]Retained Earnings [Member]	Convertible Second Lien Notes [Member]	New 2L Notes [Member]Preferred Stock [Member]	New 2L Notes [Member]Common Stock [Member]	New 2L Notes [Member]Additional Paid-in Capital [Member]	New 2L Notes [Member]Treasury Stock [Member]	New 2L Notes [Member]Retained Earnings [Member]	New 2L Notes [Member]	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Total
Balance (in shares) at Dec. 31, 2017														10,771,000
Balance at Dec. 31, 2017														$ 108	$ 68,446		$ (12,303)	$ 56,251
Net income (loss)																	1,750	1,750
Share-based compensation															7,322			7,322
Restricted stock vesting & other (in shares)														690,000		(230,000)
Restricted stock vesting & other														$ 7	2,186	$ (2,970)		(777)
Conversion of convertible securities (in shares)		920,000
Conversion of convertible securities		$ 9	$ (5)			$ 4
Issuance cost															(120)			$ (120)
Treasury stock activity (in shares)														(230,000)
Treasury stock activity														$ (2)
Treasury stock activity															(2,968)
Treasury Stock, Shares, Acquired																230,000		230,013
Treasury stock activity																$ 2,970
Balance (in shares) at Dec. 31, 2018														12,151,000
Balance at Dec. 31, 2018														$ 122	74,861		(10,553)	64,430
Net income (loss)																	13,288	13,288
Share-based compensation															7,221			7,221
Restricted stock vesting & other (in shares)														232,000		(208,000)
Restricted stock vesting & other														$ 4	(90)	$ (2,098)		$ (2,184)
Conversion of convertible securities (in shares)		150,000
Conversion of convertible securities		$ 1	$ (20)			$ (19)			$ 1,429			$ 1,429
Treasury stock activity (in shares)
Treasury stock activity														$ (2)
Treasury stock activity															(2,096)
Treasury Stock, Shares, Acquired																208,000		208,000
Treasury stock activity																$ 2,098
Balance (in shares) at Dec. 31, 2019														12,533,000
Balance at Dec. 31, 2019														$ 125	$ 81,305		$ 2,735	$ 84,165

Note 1 - Description of Busines

Note 1 - Description of Business and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Significant Accounting Policies [Text Block]	NOTE 1—Description Goodrich Petroleum Corporation (“Goodrich” and, together with its subsidiary, Goodrich Petroleum Company, L.L.C. (the “Subsidiary”), “we,” “our,” or the “Company”) is an independent oil and natural gas company engaged in the exploration, development and production of oil and natural gas on properties primarily in (i) Northwest Louisiana and East Texas, which includes the Haynesville Shale Trend, (ii) Southwest Mississippi and Southeast Louisiana, which includes the Tuscaloosa Marine Shale Trend (“TMS”), and (iii) South Texas, which includes the Eagle Ford Shale Trend. Basis of Presentation Principles of Consolidation 10 Use of Estimates Cash and Cash Equivalents ninety Accounts Payable December 31, 2019 2018 December 31, 2019 2018 Trade payables $ 11,461 $ 8,633 Revenue payables 14,483 16,665 Prepayments from partners - 132 Other 404 304 Total Accounts payable $ 26,348 $ 25,734 Accrued Liabilities December 31, 2019 2018 December 31, 2019 2018 Accrued capital expenditures $ 6,175 $ 8,086 Accrued lease operating expense 989 1,100 Accrued production and other taxes 430 338 Accrued transportation and gathering 2,258 1,888 Accrued performance bonus 4,642 3,420 Accrued interest 208 443 Accrued office lease 1,414 598 Accrued general and administrative expense and other 499 645 Total Accrued liabilities $ 16,615 $ 16,518 Inventory ent, casing and tubulars tha Property and Equipment two il and gas have the option of selecting either method for application in the accounting for their properties. The principal differences between the two We have elected to adopt the Full Cost Method of Accounting. We believe that the true cost of developing a “portfolio” of reserves should reflect both successful and unsuccessful attempts at exploration and production. Application of the Full Cost Method of accounting better reflects the true economics of exploring for and developing our oil and gas reserves. Under the Full Cost Method, we capitalize all costs associated with acquisitions, exploration, development and estimated abandonment costs. We capitalize internal costs that can be directly identified with the acquisition of leasehold, as well as drilling and completion activities, but do not irment. We review our unevaluated properties at the end of each quarter to determine whether the costs should be reclassified to proved oil and natural gas properties and therefore subject to DD&A and the full cost ceiling test. For the years ended December 31, 2019 and December 31, 2018 , we transferred $0.3 $6.0 no Under the Full Cost Method, we amortize our investment in oil and natural gas properties through DD&A expense using the units of production method. An amortization rate is calculated based on total proved reserves converted to equivalent thousand cubic feet of natural gas (“Mcfe”) as the denominator and the net book value of evaluated oil and gas asset together with the estimated future development cost of the proved undeveloped reserves as the numerator. The rate calculated per Mcfe is applied against the periods' production also converted to Mcfe to arrive at the periods' DD&A expense. Depreciation of furniture, fixtures and equipment, consisting of office furniture, computer hardware and software and leasehold improvements, is computed using the straight-line method over their estimated useful lives, which vary from three five Full Cost Ceiling Test 12 The Full Cost Ceiling Test performed as of December 31, 2019 December 31, 2018 no Fair Value Measurement We use various methods, including the income approach and market approach, to determine the fair values of our financial instruments that are measured at fair value on a recurring basis, which depend on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. For some of our instruments, the fair value is calculated based on directly observable market data or data available for similar instruments in similar markets. For other instruments, the fair value may three 1, 2 3 Each of these levels and our corresponding instruments classified by level are further described below: • Level 1 no 1 • Level 2 our senior credit facilities and third third • Level 3 As of December 31, 2019 December 31, 2018 Asset Retirement Obligations Note 4 The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the initial measurement of the asset retirement obligations was classified as Level 3 Revenue Recognition onth our production is delivered to the purchaser. However, settlement statements and payments for our oil and natural gas sales may not 60 December 31, 2019 and 2018, Derivative Instruments not Note 9 Income Taxes not not We recognize, as required, the financial statement benefit of an uncertain tax position only after determining that the relevant tax authority would more likely than not not 50 Note 7 Net Income or Net Loss Per Common Share Note 6 Commitments and Contingencies third not Note 10 Concentration of Credit Risk December 31, 2019 2018 Year Ended December 31, 2019 2018 CIMA Energy, LP 39 % 41 % Shell 19 % 0 % ETC 19 % 15 % CES 10 % 8 % Genesis Crude Oil LP 8 % 13 % Sunoco, Inc. 1 % 4 % Williams Energy Resources LLC 0 % 1 % Occidental Energy MA 0 % 1 % Share-based Compensation Note 3 Guarantee December 31, 2019 LC, the wholly owned subsidiary of Goodrich Petroleum Corporation, was the Subsidiary Guarantor of our New 2L no no Debt Issuance Cost 2L New Accounting Pronouncements In December 2019, “ ”) issued Accounting Standards Update (“ASU”) 2019 12, 740 December 15, 2020, not In August 2018, 2018 13, 820 820 December 15, 2019, no

Note 2 - Revenue Recognition

Note 2 - Revenue Recognition	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Revenue from Contract with Customer [Text Block]	NOTE 2 —Revenue Recognition On January 1, 2018, 2014 09, Revenue from Contracts with Customers, 606 606” 606, 606, no Our revenue stream does not We record revenue in the month our production is delivered to the purchaser. However, settlement statements and payments for our oil and natural gas sales may not 60 not December 31, 2019 and December 31, 2018 , receivables from contracts with customers were $11.3 $14.5 Topic 606 not 606, January 1, 2018 not not The following tables present our oil and natural gas revenues disaggregated by revenue source and by operated and non-operated properties: Year Ended December 31, 2019 (In thousands) Oil Revenue Gas Revenue NGL Revenue Total Oil and Natural Gas Revenues Operated $ 9,961 $ 91,811 $ - $ 101,772 Non-operated 426 16,142 13 16,581 Total oil and natural gas revenues $ 10,387 $ 107,953 $ 13 $ 118,353 Year Ended December 31, 2018 (In thousands) Oil Revenue Gas Revenue NGL Revenue Total Oil and Natural Gas Revenues Operated $ 14,189 $ 58,911 $ - $ 73,100 Non-operated 556 14,236 51 14,843 Total oil and natural gas revenues $ 14,745 $ 73,147 $ 51 $ 87,943

Note 3 - Share-based Compensati

Note 3 - Share-based Compensation Plans	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Share-based Payment Arrangement [Text Block]	NOTE 3—Share Overview The Company had one December 31, 2019 December 31, 2018 the 2016 2016 Our 2016 may may may In 2019, 205,000 three 205,000 three 81,000 12 2018, no 201,969 2017. December 2018, 45,160 12 December 31, 2019, no 2017 2019 250% 200%, Performance Share Unit Awards In December 2019, 205,000 3 three may zero 200% • Volatility factor • Dividend yield zero not • Risk-free interest rate three • Expected term three The grant date fair value of each PSU as determined by the Monte Carlo simulation model was $10.43, 2019 Number of simulations 250,000 Grant price $ 10.43 Volatility factor 49.3 % Dividend yield — Risk-free interest rate 2 % Expected term (in years) P3Y The fair value of the PSUs granted in 2019 $2.1 3 not December 31, 2019, 2019 $2.1 2.95 Share-based Compensation The following tables summarizes the pre-tax components of our share-based compensation program under the LTIP, recognized as a component of general and administrative expenses in the Consolidated Statements of Operations (in thousands), for the years ended December 31, 2019 2018 Year Ended December 31, 2016 Long Term Incentive Plan 2019 2018 RSU expense - employees $ 4,521 $ 4,702 PSU expense 1,952 1,893 RSU expense - directors 664 595 Total share-based compensation $ 7,137 $ 7,190 Capitalized and lease operating expense share-based compensation (835 ) (747 ) Net share-based compensation - general and administrative expense $ 6,302 $ 6,443 RSUs and PSUs awarded under the LTIP generally have a vesting period between one three not RSU and PSU activity and changes under the LTIP for the years ended December 31, 2019 2018 2016 Long Term Incentive Plan Number of Units Weighted Average Grant-Date Fair Value Total Value (thousands) RSU PSU Total RSU PSU Total RSU PSU Total Unvested at December 31, 2017 1,171,353 402,679 1,574,032 $ 9.91 $ 15.29 $ 11.29 $ 11,647 $ 6,157 $ 17,804 Granted (1) 249,751 - 249,751 11.54 - 11.54 2,882 - 2,882 Vested (1) (742,607 ) - (742,607 ) 10.20 - 10.20 (9,681 ) - (9,681 ) Forfeited (17,360 ) (3,291 ) (20,651 ) 11.25 15.29 11.90 (195 ) (50 ) (245 ) Unvested at December 31, 2018 661,137 399,388 1,060,525 10.16 15.29 12.09 4,653 6,107 10,760 Granted 294,871 204,755 499,626 9.96 10.43 10.16 2,938 2,136 5,074 Vested (530,446 ) - (530,446 ) 10.18 - 10.18 (5,138 ) - (5,138 ) Forfeited (9,032 ) - (9,032 ) 13.84 - 13.84 (125 ) - (125 ) Unvested at December 31, 2019 416,530 604,143 1,020,673 $ 9.92 $ 13.64 $ 12.12 $ 2,328 $ 8,243 $ 10,571 ( 1 201,969 2017 2018. As of December 31, 2019 2018 2016 Long Term Incentive Plan Unrecognized compensation costs Weighted Average years to recognition (thousands) (years) RSU PSU Total RSU PSU Total December 31, 2019 $ 3,969 $ 4,283 $ 8,252 1.95 1.93 1.94 December 31, 2018 $ 6,340 $ 4,100 $ 10,440 1.35 1.96 1.59

Note 4 - Asset Retirement Oblig

Note 4 - Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Asset Retirement Obligation Disclosure [Text Block]	NOTE 4—Asset The table below is the reconciliation of the beginning and ending asset retirement obligation for the periods as noted (in thousands): December 31, 2019 December 31, 2018 Beginning balance $ 3,791 $ 3,367 Liabilities incurred 224 303 Revisions in estimated liabilities (1) 63 47 Liabilities settled (4 ) (13 ) Accretion expense 297 262 Dispositions (2) (202 ) (175 ) Ending balance $ 4,169 $ 3,791 Current liability $ - $ - Long term liability $ 4,169 $ 3,791 ( 1 ( 2 Note 12 for further information on the dispositions during the year ended December 31, 2019.

Note 5 - Debt

Note 5 - Debt	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Debt Disclosure [Text Block]	NOTE 5—Debt Debt consisted of the following balances as of the dates indicated (in thousands): December 31, 2019 December 31, 2018 Principal Carrying Amount Fair Value Principal Carrying Amount Fair Value 2017 Senior Credit Facility (1) $ - $ - $ - $ 27,000 $ 27,000 $ 27,000 2019 Senior Credit Facility (1) 92,900 92,900 92,900 - - - Convertible Second Lien Notes (2) - - - 53,691 49,820 60,857 New 2L Notes (3) 12,969 11,535 12,952 - - - Total debt $ 105,869 $ 104,435 $ 105,852 $ 80,691 $ 76,820 $ 87,857 ( 1 The carrying amount for the 2017 2019 ( 2 The debt discount was being amortized using the effective interest rate method based upon a maturity date of August 30, 2019 May 29, 2019. ( 3 The debt discount is being amortized using the effective interest rate method based upon a maturity date of May 31, 2021. $1.0 December 31, 2019. $1.1 $0.3 December 31, 2019. 2L 2 December 31, 2019. The following table summarizes the total interest expense (contractual interest expense, amortization of debt discount, accretion and financing costs) and the effective interest rate on the liability component of the debt (amounts in thousands, except effective interest rates) for the periods as noted below: Year Ended December 31, 2019 Year Ended December 31, 2018 Interest Expense Effective Interest Rate Interest Expense Effective Interest Rate 2017 Senior Credit Facility $ 872 7.2 % $ 1,130 8.9 % 2019 Senior Credit Facility 3,409 6.0 % - - Convertible Second Lien Notes (1) 5,304 24.1 % 10,814 23.9 % New 2L Notes (2) 1,416 21.6 % - - Total $ 11,001 $ 11,944 ( 1 13.50%; 24.1% December 31, 2019 ( May 29, 2019) 23.9% December 31, 2018. December 31, 2019 $2.3 $3.0 December 31, 2018 $4.1 $6.7 ( 2 2L 13.50%; 21.6% December 31, 2019. December 31, 2019 $0.3 $1.0 2017 On October 17, 2017, “2017 “2017 2017 October 17, 2021 December 30, 2019, not December 30, 2019. 2017 May 14, 2019 $250.0 $75.0 All amounts outstanding under the 2017 1.75% 2.75%, 2.75% 3.75%, 2017 0.50% The obligations under the 2017 first On May 14, 2019, 2017 2019 $0.2 2019 On May 14, 2019, “2019 “2019 The 2019 May 14, 2024 December 3, 2020, 2L not December 3, 2020, 180 2L 2L 2L 2019 $500 $115 $125 August 2019 March September may one may 2019 $10 All amounts outstanding under the 2019 1.50% 2.50%, 2.50% 3.50%, 2019 0.375% 0.50%, 2019 2.0% December 31, 2019 2019 5.047%. 2019 first The 2019 may 2019 2019 not 4.00 1.00 2019 not 1.00 1.00 no 2L 10 not $10 not 1.50 1.00 May 14, 2019, 2019 2017 As of December 31, 2019 $125.0 $92.9 ompany also had $2.2 December 31, 2019 2019 As of December 31, 2019 2019 Convertible Second Lien Notes In October 2016, $40.0 13.50% 2019 10 2.5 second two The Convertible Second Lien Notes were scheduled to mature on August 30, 2019 six no March 30, 2020. 13.50% January 15, April 15, July 15 October 15 second Upon issuance of the Convertible Second Lien Notes in October 2016, may $11.0 $40.0 $29.0 $11.0 August 30, 2019. May 29, 2019 $56.7 2019 $1.6 New Convertible Second Lien Notes On May 14, 2019, 2L 2L 2L $12.0 13.50% 2021 2L 2L May 31, 2019. 2L 2019 2L second The New 2L 2L May 31, 2021. 2L 13.50% January 15, April 15, July 15 October 15 may 2L 2L The New 2L 2L 10 2L not $10.0 not 1.50 1.00. The New 2L 2L $21.33, 2L 1 2L 2 3 2L 2019 The New 2L 2L 1933, 4 2 2L 2L Upon issuance of the New 2L May 31, 2019, may $1.4 $12.0 $10.6 $1.4 May 31, 2021. As of December 31, 2019 , $1.1 $0.3 2L As of December 31, 2019 2L

Note 6 - Net Income (Loss) Per

Note 6 - Net Income (Loss) Per Common Share	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Earnings Per Share [Text Block]	NOTE 6—Net Net income (loss) applicable to common stock was used as the numerator in computing basic and diluted net income (loss) per common share for the periods as noted below. The Company used the treasury stock method in determining the effects of potentially dilutive restricted stock. The following table sets forth information related to the computations of basic and diluted net income (loss) per common share: Year Ended December 31, 2019 Year Ended December 31, 2018 Basic net income per common share: Net income applicable to common stock $ 13,288 $ 1,750 Weighted-average shares of common stock outstanding 12,233 11,622 Basic net income per common share $ 1.09 $ 0.15 Diluted net income per common share: Net income applicable to common stock $ 13,288 $ 1,750 Weighted-average shares of common stock outstanding 12,233 11,622 Common shares issuable upon conversion of the Convertible Second Lien Notes associated warrants - 150 Common shares issuable upon conversion of warrants of unsecured claim holders 1,314 1,418 Common shares issuable on assumed conversion of restricted stock * 348 475 Diluted weighted average shares of common stock outstanding 13,895 13,665 Diluted net income per common share (1) $ 0.96 $ 0.13 (1) Common shares issuable upon conversion of the New 2L Notes and Convertible Second Lien Notes were not included in the computation of diluted loss per common share since their inclusion would have been anti-dilutive. 608 1,875 * Common shares issuable on assumed conversion of restricted stock from share-based compensation assumes a payout of the Company's performance share awards at 100% one one may zero 250%

Note 7 - Income Taxes

Note 7 - Income Taxes	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Income Tax Disclosure [Text Block]	NOTE 7—Income The following table summarizes the tax expense (benefit) for the periods as noted below (in thousands): Year Ended December 31, 2019 Year Ended December 31, 2018 Current tax expense (benefit) Federal $ (393 ) $ (208 ) State - - Total current tax expense (benefit) (393 ) (208 ) Deferred tax expense (benefit) Federal 393 151 State - - Total deferred tax expense (benefit) 393 151 Total tax expense (benefit) $ - $ (57 ) The following is a reconciliation of the U.S. statutory income tax rate at 21% Year Ended December 31, 2019 Year Ended December 31, 2018 Income tax expense (benefit) Tax expense at U.S. statutory rate $ 2,790 $ 356 Disallowed executive compensation 821 841 Valuation allowance (5,499 ) (2,530 ) State income taxes, net of federal benefit 718 1,194 Nondeductible expenses and other 1,170 82 Total tax expense (benefit) $ - $ (57 ) The tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities are presented below (in thousands) for the years ended December 31, 2019 and 2018 : December 31, 2019 2018 Non-current deferred tax assets: Operating loss carry-forwards $ 45,280 $ 38,958 State tax NOL and credits 11,611 10,278 Statutory depletion carry-forward - 4,221 AMT tax credit carry-forward 393 786 Compensation 1,461 1,426 Contingent liabilities and other 378 784 Lease liabilities 465 - Debt discount - 54 Property and equipment 16,813 28,530 Total gross non-current deferred tax assets 76,401 85,037 Less valuation allowance (74,150 ) (84,181 ) Net non-current deferred tax assets 2,251 856 Non-current deferred tax liabilities: Derivatives (1,214 ) (70 ) Right of use asset (350 ) Other (97 ) Debt discount (197 ) - Total non-current deferred tax liabilities (1,858 ) (70 ) Net non-current deferred tax asset $ 393 $ 786 The valuation allowance for deferred tax assets decreased by $10.0 $74.2 2019. $5.5 $4.5 would never be recognized and therefore, we reduced both the deferred tax asset and the related valuation allowance for this in 2019. 2018 not $0.4 AMT ) credits that are expected to be monetized. The tax benefit recorded for 2018 2016 2018 $0.4 2019. $0.4 2019 2021 no no As of December 31, 2019 , we have federal net operating loss carry-forwards of approximately $846.6 382 $215.6 IRC Sections 382 383 October 2016 382. October 12, 2016. $630.7 $77.0 $151.5 We did not December 31, 2019 . The amount of unrecognized tax benefits may twelve not no 2010. Our continuing practice is to recognize estimated interest and penalties related to potential underpayment on any unrecognized tax benefits as a component of income tax expense in the Consolidated Statement of Operations. We do not December 31, 2019 .

Note 8 - Stockholders' Equity

Note 8 - Stockholders' Equity	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Stockholders' Equity Note Disclosure [Text Block]	NOTE 8—Stockholders’ At December 31, 2019 there were 12,532,550 75,000,000 $0.01 During the year ended December 31, 2019 150,000 10 one 150,000 December 31, 2019 share-based compensation units representing a total fair value of $5.1 530,000 December 31, 2019, $2.1 208,000 December 31, 2019 . In connection with the issuance of the New 2L $1.4 Note 5 . During the year ended December 31, 2018, 10 920,312 one one 373,437 December 31, 2018, 150,000 December 31, 2018, 201,969 2017 December 31, 2018, $3.1 230,013 December 31, 2018.

Note 9 - Derivative Activities

Note 9 - Derivative Activities	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Derivative Instruments and Hedging Activities Disclosure [Text Block]	NOTE 9—Derivative We use commodity and financial derivative contracts to manage fluctuations in commodity prices and interest rates. We are currently not 2019 2018 The following table summarizes the gains and losses we recognized on our oil and natural gas derivatives for the periods as noted below: Oil and Natural Gas Derivatives (in thousands) Year Ended December 31, 2019 Year Ended December 31, 2018 Gain (loss) on commodity derivatives not designated as hedges, settled $ 9,560 $ (3,236 ) Gain (loss) on commodity derivatives not designated as hedges, not settled 5,450 (750 ) Total gain (loss) on commodity derivatives not designated as hedges $ 15,010 $ (3,986 ) Commodity Derivative Activity We enter into swap contracts, costless collars or other derivative agreements from time to time to manage commodity price risk for a portion of our production. Our policy is that all derivative contracts are approved by the Hedging Committee of our Board and reviewed periodically by the Board. Despite the measures taken by us to attempt to control price risk, we remain subject to price fluctuations for natural gas and crude oil sold in the spot market. Prices received for natural gas sold on the spot market are volatile due primarily to seasonality of demand and other factors beyond our control. Decreases in domestic crude oil and natural gas spot prices will have a material adverse effect on our financial position, results of operations and quantities of reserves recoverable on an economic basis. W e routinely exercise our contractual right to net realized gains against realized losses when settling with our financial counterparties. Neither our counterparties nor we require any collateral upon entering into derivative contracts. We would have been at risk of losing $8.2 December 31, 2019. As of December 31, 2019 Contract Type Average Daily Volume Total Volume Weighted Average Fixed Price December 31, 2019 Crude oil swaps (Bbls) 2020 221 80,945 $ 59.02 $ 35 2021 220 18,000 $56.58 24 Total oil 59 Natural gas swaps (MMBtu) 2020 51,631 18,897,000 $ 2.67 $ 7,502 2021 42,656 3,839,000 $2.64 11 Natural gas collars (MMBtu) 2020 18,287 6,693,000 $2.40-$2.625 901 2021 27,000 2,430,000 $2.40-$2.625 (314 ) Total natural gas 8,100 Natural gas basis swaps (MMBtu) 2020 50,000 18,300,000 NYMEX - $0.209 $ 99 2021 50,000 18,250,000 NYMEX - $0.209 (239 ) 2022 50,000 18,250,000 NYMEX - $0.209 (518 ) 2023 50,000 18,250,000 NYMEX - $0.209 (679 ) 2024 50,000 18,300,000 NYMEX - $0.209 (1,040 ) Total natural gas basis (2,377 ) Total $ 5,782 The following table summarizes the fair values of our derivative financial instruments that are recorded at fair value classified in each level as of December 31, 2019 Note 1 Description Level 1 Level 2 Level 3 Total Fair value of oil and natural gas derivatives - Current Assets $ - $ 8,537 $ - $ 8,537 Fair value of oil and natural gas derivatives - Non-current Assets - 31 - 31 Fair value of oil and natural gas derivatives - Current Liabilities - - - - Fair value of oil and natural gas derivatives - Non-current Liabilities - (2,786 ) - (2,786 ) Total $ - $ 5,782 $ - $ 5,782 We enter into oil and natural gas derivative contracts under which we have netting arrangements with each counter-party. The following table discloses and reconciles the gross amounts to the amounts as presented on the Consolidated Balance Sheets for the periods ending December 31, 2019 December 31, 2019 Fair Value of Oil and Natural Gas Derivatives (in thousands) Gross Amount Amount Offset As Presented Fair value of oil and natural gas derivatives - Current Assets $ 9,401 $ (864 ) $ 8,537 Fair value of oil and natural gas derivatives - Non-current Assets 847 (816 ) 31 Fair value of oil and natural gas derivatives - Current Liabilities (864 ) 864 - Fair value of oil and natural gas derivatives - Non-current Liabilities (3,602 ) 816 (2,786 ) Total $ 5,782 $ - $ 5,782

Note 10 - Commitments and Conti

Note 10 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	NOTE 10—Commitments We are party to various lawsuits from time to time arising in the normal course of business, including, but not not The table below provides estimates of the timing of future payments that we are obligated to make based on agreements in place at December 31, 2019 Payment due by Period Note Total 2020 2021 2022 2023 2024 and After Debt 5 $ 105,869 $ - $ 12,969 $ - $ - $ 92,900 Office space leases 11 2,353 $ 1,540 $ 813 $ - $ - $ - Operations contracts 2,491 $ 2,491 $ - $ - $ - $ - Total contractual obligations (1) $ 110,713 $ 4,031 $ 13,782 $ - $ - $ 92,900 ( 1 This table does not $4.2 December 31, 2019. Note 4 Operating Leases December 31, 2019 2018 y $1.7 $1.6

Note 11 - Leases

Note 11 - Leases	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Lessee, Operating Leases [Text Block]	NOTE 11—Leases We adopted ASU 2016 02, January 1, 2019, 12 not not not The lease cost components for the year ended December 31, 2019 (in thousands) Year Ended December 31, 2019 Consolidated Statements of Operations Classification Building lease cost $ 1,540 General and administrative expense Variable lease cost (1) 118 General and administrative expense $ 1,658 (1) Includes building operating expenses. The following are additional details related to our lease portfolio as of December 31, 2019 (in thousands) December 31, 2019 Consolidated Balance Sheets Classification Lease asset, gross $ 2,922 Furniture, fixtures and equipment and other capital assets Accumulated depreciation (1,252 ) Accumulated depletion, depreciation and amortization Lease asset, net $ 1,670 Current lease liability $ 1,414 Accrued liabilities Non-current lease liability 800 Other non-current liabilities Total lease liabilities $ 2,214 The following table presents operating lease liability maturities as of December 31, 2019 (in thousands) December 31, 2019 2020 1,540 2021 813 2022 - 2023 - Thereafter - Total lease payments $ 2,353 Less imputed interest $ 139 Present value of lease liabilities $ 2,214 As of December 31, 2019 , our office building operating lease has a weighted-average remaining lease term of 1.3 8.0 $1.6 December 31, 2019 .

Note 12 - Dispositions and Acqu

Note 12 - Dispositions and Acquisitions	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	NOTE 12—Dispositions On March 1, 2019, $1.3 On May 21, 2018, $3.3 May 1, 2018. On February 28, 2018, two $23.0 January 1, 2018. 2017 March 2, 2018 The Company also sold other miscellaneous acreage during the year ended December 31, 2018 $0.7

Note 13 - Oil and Natural Gas P

Note 13 - Oil and Natural Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2019
Notes to Financial Statements
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	NOTE 13—Oil Overview All of our reserve information related to crude oil, condensate and natural gas was compiled based on estimates prepared and reviewed by our engineers. The technical persons primarily responsible for overseeing the preparation of the reserves estimates meet the requirements regarding qualifications. Our principal internal engineer has over 35 30 35 December 31, 2019 2018 December 31, 2019 2018 December 31, 2019 2018 2019 99.1 99.2, 10 Many assumptions and judgmental decisions are required to estimate reserves. Quantities reported are considered reasonable but are subject to future revisions, some of which may may Regulations published by the SEC define proved oil and natural gas reserves as those quantities of oil and natural gas 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 regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether the estimate is a deterministic estimate or probabilistic estimate. Proved developed oil and natural gas reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared with the cost of a new well or through installed extraction equipment and infrastructure operational at the time of the reserves estimates if the extraction is by means not Prices we used to value our reserves are based on the twelve first January December 2019. $55.69 $2.58 Capitalized Costs The table below reflects our capitalized costs related to our oil and natural gas producing activities at December 31, 2019 and 2018 (in thousands): Year Ended December 31, 2019 Year Ended December 31, 2018 Proved properties $ 302,859 $ 206,097 Unproved properties 123 180 302,982 206,277 Less: accumulated depreciation, depletion and amortization (91,958 ) (41,886 ) Net oil and natural gas properties $ 211,024 $ 164,391 We did not December 31, 2019 and 2018 , respectively. Costs Incurred Costs incurred in oil and natural gas property acquisition, exploration and development activities, whether capitalized or expensed, are summarized as follows (in thousands): Year Ended December 31, 2019 Year Ended December 31, 2018 Property Acquisition Unproved $ 269 $ 178 Proved - - Exploration - - Development (1) 98,141 106,583 Total (2) $ 98,410 $ 106,761 ( 1 Includes asset retirement costs of $0.1 2019 $0.1 2018. ( 2 Substantially all the costs incurred related to the Haynesville Shale Trend. The following table sets forth our net proved oil and natural gas reserves at December 31, 2019 , 2018 and 2017 and the changes in net proved oil and natural gas reserves during such years, as well as proved developed and proved undeveloped reserves at the beginning and end of each year: Natural Gas (Mmcf) Oil, Condensate and NGLs (MBbls) 2019 2018 2017 2019 2018 2017 Net proved reserves at beginning of period 470,937 415,224 286,038 1,441 2,130 2,815 Revisions of previous estimates (1) 37,136 (16,993 ) 106,639 (166 ) (388 ) (381 ) Extensions, discoveries and improved recovery (2) 218,015 100,499 32,871 - - - Purchases of minerals in place - - - - - - Sales of minerals in place (169,310 ) (3,349 ) - - (84 ) - Production (46,712 ) (24,444 ) (10,324 ) (171 ) (217 ) (304 ) Net proved reserves at end of period 510,066 470,937 415,224 1,104 1,441 2,130 Net proved developed reserves: Beginning of period 92,118 52,861 21,872 1,441 2,130 2,815 End of period 138,607 92,118 52,861 1,104 1,441 2,130 Net proved undeveloped reserves: Beginning of period 378,819 362,363 264,166 - - - End of period 371,459 378,819 362,363 - - - Natural Gas Equivalents (Mmcfe) 2019 2018 2017 Net proved reserves at beginning of period 479,583 428,002 302,927 Revisions of previous estimates (1) 36,141 (19,320 ) 104,354 Extensions, discoveries and improved recovery (2) 218,015 100,499 32,871 Purchases of minerals in place - - - Sales of minerals in place (3) (169,310 ) (3,852 ) - Production (47,738 ) (25,746 ) (12,150 ) Net proved reserves at end of period 516,691 479,583 428,002 Net proved developed reserves: Beginning of period 100,764 65,639 44,432 End of period 145,232 100,764 65,639 Net proved undeveloped reserves: Beginning of period 378,819 362,363 258,495 End of period 371,459 378,819 362,363 ( 1 Revisions of previous estimates in 2019 2018 2017 ( 2 Extensions and discoveries were positive on an overall basis in all three ( 3 In 2019, 54,571 2018, 2,500 Standardized Measure The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves as of year-end is shown below (in thousands): 2019 2018 2017 Future revenues $ 1,272,504 $ 1,494,557 $ 1,260,490 Future lease operating expenses and production taxes (377,851 ) (410,957 ) (430,048 ) Future development costs (1) (338,116 ) (349,552 ) (329,938 ) Future income tax expense (13,552 ) (56,784 ) (17,113 ) Future net cash flows 542,985 677,264 483,391 10% annual discount for estimated timing of cash flows (246,031 ) (279,679 ) (223,081 ) Standardized measure of discounted future net cash flows $ 296,954 $ 397,585 $ 260,310 Index price used to calculate reserves (2) Natural gas (per Mcf) $ 2.58 $ 3.10 $ 2.98 Oil (per Bbl) $ 55.69 $ 65.56 $ 51.34 ( 1 Includes cumulative asset retirement obligations of $7.4 $7.3 2019 2018, ( 2 These index prices, used to estimate our reserves at these dates, are before deducting or adding applicable transportation and quality differentials on a well-by-well basis. The estimated future net cash flows are discounted using a rate of 10 Changes in the Standardized Measure The following are the principal sources of change in the standardized measure of discounted net cash flows for the years shown (in thousands): Year Ended December 31, 2019 2018 2017 Balance, beginning of year $ 397,585 $ 260,310 $ 56,922 Net changes in prices and production costs related to future production (337,911 ) 95,927 113,319 Sales and transfers of oil and natural gas produced, net of production costs (82,706 ) (63,846 ) (32,012 ) Net change due to revisions in quantity estimates 33,181 (25,595 ) 107,499 Net change due to extensions, discoveries and improved recovery 101,012 129,207 8,970 Net change due to purchases and sales of minerals in place (2,009 ) (3,382 ) - Changes in future development costs 125,179 (4,608 ) (59,560 ) Previously estimated development cost incurred in period 31,340 7,923 8,114 Net change in income taxes 20,185 (16,336 ) (3,686 ) Accretion of discount 41,777 26,416 5,709 Change in production rates (timing) and other (30,679 ) (8,431 ) 55,035 Net increase (decrease) in standardized measures (100,631 ) 137,275 203,388 Balance, end of year $ 296,954 $ 397,585 $ 260,310

Significant Accounting Policies

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Consolidation, Policy [Policy Text Block]	Principles of Consolidation 10
Use of Estimates, Policy [Policy Text Block]	Use of Estimates
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents ninety
Accounts Payable, Policy [Policy Text Block]	Accounts Payable December 31, 2019 2018 December 31, 2019 2018 Trade payables $ 11,461 $ 8,633 Revenue payables 14,483 16,665 Prepayments from partners - 132 Other 404 304 Total Accounts payable $ 26,348 $ 25,734
Accrued Liabilities, Policy [Policy Text Block]	Accrued Liabilities December 31, 2019 2018 December 31, 2019 2018 Accrued capital expenditures $ 6,175 $ 8,086 Accrued lease operating expense 989 1,100 Accrued production and other taxes 430 338 Accrued transportation and gathering 2,258 1,888 Accrued performance bonus 4,642 3,420 Accrued interest 208 443 Accrued office lease 1,414 598 Accrued general and administrative expense and other 499 645 Total Accrued liabilities $ 16,615 $ 16,518
Inventory, Policy [Policy Text Block]	Inventory ent, casing and tubulars tha
Property, Plant and Equipment, Policy [Policy Text Block]	Property and Equipment two il and gas have the option of selecting either method for application in the accounting for their properties. The principal differences between the two We have elected to adopt the Full Cost Method of Accounting. We believe that the true cost of developing a “portfolio” of reserves should reflect both successful and unsuccessful attempts at exploration and production. Application of the Full Cost Method of accounting better reflects the true economics of exploring for and developing our oil and gas reserves. Under the Full Cost Method, we capitalize all costs associated with acquisitions, exploration, development and estimated abandonment costs. We capitalize internal costs that can be directly identified with the acquisition of leasehold, as well as drilling and completion activities, but do not irment. We review our unevaluated properties at the end of each quarter to determine whether the costs should be reclassified to proved oil and natural gas properties and therefore subject to DD&A and the full cost ceiling test. For the years ended December 31, 2019 and December 31, 2018 , we transferred $0.3 $6.0 no Under the Full Cost Method, we amortize our investment in oil and natural gas properties through DD&A expense using the units of production method. An amortization rate is calculated based on total proved reserves converted to equivalent thousand cubic feet of natural gas (“Mcfe”) as the denominator and the net book value of evaluated oil and gas asset together with the estimated future development cost of the proved undeveloped reserves as the numerator. The rate calculated per Mcfe is applied against the periods' production also converted to Mcfe to arrive at the periods' DD&A expense. Depreciation of furniture, fixtures and equipment, consisting of office furniture, computer hardware and software and leasehold improvements, is computed using the straight-line method over their estimated useful lives, which vary from three five
Full Cost or Successful Efforts, Policy [Policy Text Block]	Full Cost Ceiling Test 12 The Full Cost Ceiling Test performed as of December 31, 2019 December 31, 2018 no
Fair Value of Financial Instruments, Policy [Policy Text Block]	Fair Value Measurement We use various methods, including the income approach and market approach, to determine the fair values of our financial instruments that are measured at fair value on a recurring basis, which depend on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. For some of our instruments, the fair value is calculated based on directly observable market data or data available for similar instruments in similar markets. For other instruments, the fair value may three 1, 2 3 Each of these levels and our corresponding instruments classified by level are further described below: • Level 1 no 1 • Level 2 our senior credit facilities and third third • Level 3 As of December 31, 2019 December 31, 2018
Asset Retirement Obligation [Policy Text Block]	Asset Retirement Obligations Note 4 The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the initial measurement of the asset retirement obligations was classified as Level 3
Revenue from Contract with Customer [Policy Text Block]	Revenue Recognition onth our production is delivered to the purchaser. However, settlement statements and payments for our oil and natural gas sales may not 60 December 31, 2019 and 2018,
Derivatives, Policy [Policy Text Block]	Derivative Instruments not Note 9
Income Tax, Policy [Policy Text Block]	Income Taxes not not We recognize, as required, the financial statement benefit of an uncertain tax position only after determining that the relevant tax authority would more likely than not not 50 Note 7
Earnings Per Share, Policy [Policy Text Block]	Net Income or Net Loss Per Common Share Note 6
Commitments and Contingencies, Policy [Policy Text Block]	Commitments and Contingencies third not Note 10
Concentration Risk, Credit Risk, Policy [Policy Text Block]	Concentration of Credit Risk December 31, 2019 2018 Year Ended December 31, 2019 2018 CIMA Energy, LP 39 % 41 % Shell 19 % 0 % ETC 19 % 15 % CES 10 % 8 % Genesis Crude Oil LP 8 % 13 % Sunoco, Inc. 1 % 4 % Williams Energy Resources LLC 0 % 1 % Occidental Energy MA 0 % 1 %
Share-based Payment Arrangement [Policy Text Block]	Share-based Compensation Note 3
Guarantee, Policy [Policy Text Block]	Guarantee December 31, 2019 LC, the wholly owned subsidiary of Goodrich Petroleum Corporation, was the Subsidiary Guarantor of our New 2L no no
Debt, Policy [Policy Text Block]	Debt Issuance Cost 2L
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In December 2019, “ ”) issued Accounting Standards Update (“ASU”) 2019 12, 740 December 15, 2020, not In August 2018, 2018 13, 820 820 December 15, 2019, no

Note 1 - Description of Busin_2

Note 1 - Description of Business and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Accounts Payable and Accrued Liabilities [Table Text Block]	December 31, 2019 2018 Trade payables $ 11,461 $ 8,633 Revenue payables 14,483 16,665 Prepayments from partners - 132 Other 404 304 Total Accounts payable $ 26,348 $ 25,734 December 31, 2019 2018 Accrued capital expenditures $ 6,175 $ 8,086 Accrued lease operating expense 989 1,100 Accrued production and other taxes 430 338 Accrued transportation and gathering 2,258 1,888 Accrued performance bonus 4,642 3,420 Accrued interest 208 443 Accrued office lease 1,414 598 Accrued general and administrative expense and other 499 645 Total Accrued liabilities $ 16,615 $ 16,518
Schedules of Concentration of Risk, by Risk Factor [Table Text Block]	Year Ended December 31, 2019 2018 CIMA Energy, LP 39 % 41 % Shell 19 % 0 % ETC 19 % 15 % CES 10 % 8 % Genesis Crude Oil LP 8 % 13 % Sunoco, Inc. 1 % 4 % Williams Energy Resources LLC 0 % 1 % Occidental Energy MA 0 % 1 %

Note 2 - Revenue Recognition (T

Note 2 - Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Disaggregation of Revenue [Table Text Block]	Year Ended December 31, 2019 (In thousands) Oil Revenue Gas Revenue NGL Revenue Total Oil and Natural Gas Revenues Operated $ 9,961 $ 91,811 $ - $ 101,772 Non-operated 426 16,142 13 16,581 Total oil and natural gas revenues $ 10,387 $ 107,953 $ 13 $ 118,353 Year Ended December 31, 2018 (In thousands) Oil Revenue Gas Revenue NGL Revenue Total Oil and Natural Gas Revenues Operated $ 14,189 $ 58,911 $ - $ 73,100 Non-operated 556 14,236 51 14,843 Total oil and natural gas revenues $ 14,745 $ 73,147 $ 51 $ 87,943

Note 3 - Share-based Compensa_2

Note 3 - Share-based Compensation Plans (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Share-based Payment Award, Valuation Assumptions [Table Text Block]	2019 Number of simulations 250,000 Grant price $ 10.43 Volatility factor 49.3 % Dividend yield — Risk-free interest rate 2 % Expected term (in years) P3Y
Share-based Payment Arrangement, Cost by Plan [Table Text Block]	Year Ended December 31, 2016 Long Term Incentive Plan 2019 2018 RSU expense - employees $ 4,521 $ 4,702 PSU expense 1,952 1,893 RSU expense - directors 664 595 Total share-based compensation $ 7,137 $ 7,190 Capitalized and lease operating expense share-based compensation (835 ) (747 ) Net share-based compensation - general and administrative expense $ 6,302 $ 6,443
Schedule of Nonvested Share Activity [Table Text Block]	2016 Long Term Incentive Plan Number of Units Weighted Average Grant-Date Fair Value Total Value (thousands) RSU PSU Total RSU PSU Total RSU PSU Total Unvested at December 31, 2017 1,171,353 402,679 1,574,032 $ 9.91 $ 15.29 $ 11.29 $ 11,647 $ 6,157 $ 17,804 Granted (1) 249,751 - 249,751 11.54 - 11.54 2,882 - 2,882 Vested (1) (742,607 ) - (742,607 ) 10.20 - 10.20 (9,681 ) - (9,681 ) Forfeited (17,360 ) (3,291 ) (20,651 ) 11.25 15.29 11.90 (195 ) (50 ) (245 ) Unvested at December 31, 2018 661,137 399,388 1,060,525 10.16 15.29 12.09 4,653 6,107 10,760 Granted 294,871 204,755 499,626 9.96 10.43 10.16 2,938 2,136 5,074 Vested (530,446 ) - (530,446 ) 10.18 - 10.18 (5,138 ) - (5,138 ) Forfeited (9,032 ) - (9,032 ) 13.84 - 13.84 (125 ) - (125 ) Unvested at December 31, 2019 416,530 604,143 1,020,673 $ 9.92 $ 13.64 $ 12.12 $ 2,328 $ 8,243 $ 10,571
Share-based Payment Arrangement, Nonvested Award, Cost [Table Text Block]	2016 Long Term Incentive Plan Unrecognized compensation costs Weighted Average years to recognition (thousands) (years) RSU PSU Total RSU PSU Total December 31, 2019 $ 3,969 $ 4,283 $ 8,252 1.95 1.93 1.94 December 31, 2018 $ 6,340 $ 4,100 $ 10,440 1.35 1.96 1.59

Note 4 - Asset Retirement Obl_2

Note 4 - Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Asset Retirement Obligations [Table Text Block]	December 31, 2019 December 31, 2018 Beginning balance $ 3,791 $ 3,367 Liabilities incurred 224 303 Revisions in estimated liabilities (1) 63 47 Liabilities settled (4 ) (13 ) Accretion expense 297 262 Dispositions (2) (202 ) (175 ) Ending balance $ 4,169 $ 3,791 Current liability $ - $ - Long term liability $ 4,169 $ 3,791

Note 5 - Debt (Tables)

Note 5 - Debt (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Long-term Debt Instruments [Table Text Block]	December 31, 2019 December 31, 2018 Principal Carrying Amount Fair Value Principal Carrying Amount Fair Value 2017 Senior Credit Facility (1) $ - $ - $ - $ 27,000 $ 27,000 $ 27,000 2019 Senior Credit Facility (1) 92,900 92,900 92,900 - - - Convertible Second Lien Notes (2) - - - 53,691 49,820 60,857 New 2L Notes (3) 12,969 11,535 12,952 - - - Total debt $ 105,869 $ 104,435 $ 105,852 $ 80,691 $ 76,820 $ 87,857
Schedule of Interest Expense and Effective Interest on Liability Component [Table Text Block]	Year Ended December 31, 2019 Year Ended December 31, 2018 Interest Expense Effective Interest Rate Interest Expense Effective Interest Rate 2017 Senior Credit Facility $ 872 7.2 % $ 1,130 8.9 % 2019 Senior Credit Facility 3,409 6.0 % - - Convertible Second Lien Notes (1) 5,304 24.1 % 10,814 23.9 % New 2L Notes (2) 1,416 21.6 % - - Total $ 11,001 $ 11,944

Note 6 - Net Income (Loss) Pe_2

Note 6 - Net Income (Loss) Per Common Share (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	Year Ended December 31, 2019 Year Ended December 31, 2018 Basic net income per common share: Net income applicable to common stock $ 13,288 $ 1,750 Weighted-average shares of common stock outstanding 12,233 11,622 Basic net income per common share $ 1.09 $ 0.15 Diluted net income per common share: Net income applicable to common stock $ 13,288 $ 1,750 Weighted-average shares of common stock outstanding 12,233 11,622 Common shares issuable upon conversion of the Convertible Second Lien Notes associated warrants - 150 Common shares issuable upon conversion of warrants of unsecured claim holders 1,314 1,418 Common shares issuable on assumed conversion of restricted stock * 348 475 Diluted weighted average shares of common stock outstanding 13,895 13,665 Diluted net income per common share (1) $ 0.96 $ 0.13 (1) Common shares issuable upon conversion of the New 2L Notes and Convertible Second Lien Notes were not included in the computation of diluted loss per common share since their inclusion would have been anti-dilutive. 608 1,875

Note 7 - Income Taxes (Tables)

Note 7 - Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Year Ended December 31, 2019 Year Ended December 31, 2018 Current tax expense (benefit) Federal $ (393 ) $ (208 ) State - - Total current tax expense (benefit) (393 ) (208 ) Deferred tax expense (benefit) Federal 393 151 State - - Total deferred tax expense (benefit) 393 151 Total tax expense (benefit) $ - $ (57 )
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Year Ended December 31, 2019 Year Ended December 31, 2018 Income tax expense (benefit) Tax expense at U.S. statutory rate $ 2,790 $ 356 Disallowed executive compensation 821 841 Valuation allowance (5,499 ) (2,530 ) State income taxes, net of federal benefit 718 1,194 Nondeductible expenses and other 1,170 82 Total tax expense (benefit) $ - $ (57 )
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	December 31, 2019 2018 Non-current deferred tax assets: Operating loss carry-forwards $ 45,280 $ 38,958 State tax NOL and credits 11,611 10,278 Statutory depletion carry-forward - 4,221 AMT tax credit carry-forward 393 786 Compensation 1,461 1,426 Contingent liabilities and other 378 784 Lease liabilities 465 - Debt discount - 54 Property and equipment 16,813 28,530 Total gross non-current deferred tax assets 76,401 85,037 Less valuation allowance (74,150 ) (84,181 ) Net non-current deferred tax assets 2,251 856 Non-current deferred tax liabilities: Derivatives (1,214 ) (70 ) Right of use asset (350 ) Other (97 ) Debt discount (197 ) - Total non-current deferred tax liabilities (1,858 ) (70 ) Net non-current deferred tax asset $ 393 $ 786

Note 9 - Derivative Activities

Note 9 - Derivative Activities (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Schedule of Realized and Unrealized Gains and Losses [Table Text Block]	Oil and Natural Gas Derivatives (in thousands) Year Ended December 31, 2019 Year Ended December 31, 2018 Gain (loss) on commodity derivatives not designated as hedges, settled $ 9,560 $ (3,236 ) Gain (loss) on commodity derivatives not designated as hedges, not settled 5,450 (750 ) Total gain (loss) on commodity derivatives not designated as hedges $ 15,010 $ (3,986 )
Schedule of Price Risk Derivatives [Table Text Block]	Contract Type Average Daily Volume Total Volume Weighted Average Fixed Price December 31, 2019 Crude oil swaps (Bbls) 2020 221 80,945 $ 59.02 $ 35 2021 220 18,000 $56.58 24 Total oil 59 Natural gas swaps (MMBtu) 2020 51,631 18,897,000 $ 2.67 $ 7,502 2021 42,656 3,839,000 $2.64 11 Natural gas collars (MMBtu) 2020 18,287 6,693,000 $2.40-$2.625 901 2021 27,000 2,430,000 $2.40-$2.625 (314 ) Total natural gas 8,100 Natural gas basis swaps (MMBtu) 2020 50,000 18,300,000 NYMEX - $0.209 $ 99 2021 50,000 18,250,000 NYMEX - $0.209 (239 ) 2022 50,000 18,250,000 NYMEX - $0.209 (518 ) 2023 50,000 18,250,000 NYMEX - $0.209 (679 ) 2024 50,000 18,300,000 NYMEX - $0.209 (1,040 ) Total natural gas basis (2,377 ) Total $ 5,782
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	Description Level 1 Level 2 Level 3 Total Fair value of oil and natural gas derivatives - Current Assets $ - $ 8,537 $ - $ 8,537 Fair value of oil and natural gas derivatives - Non-current Assets - 31 - 31 Fair value of oil and natural gas derivatives - Current Liabilities - - - - Fair value of oil and natural gas derivatives - Non-current Liabilities - (2,786 ) - (2,786 ) Total $ - $ 5,782 $ - $ 5,782
Offsetting Liabilities [Table Text Block]	December 31, 2019 Fair Value of Oil and Natural Gas Derivatives (in thousands) Gross Amount Amount Offset As Presented Fair value of oil and natural gas derivatives - Current Assets $ 9,401 $ (864 ) $ 8,537 Fair value of oil and natural gas derivatives - Non-current Assets 847 (816 ) 31 Fair value of oil and natural gas derivatives - Current Liabilities (864 ) 864 - Fair value of oil and natural gas derivatives - Non-current Liabilities (3,602 ) 816 (2,786 ) Total $ 5,782 $ - $ 5,782

Note 10 - Commitments and Con_2

Note 10 - Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Recorded Unconditional Purchase Obligations [Table Text Block]	Payment due by Period Note Total 2020 2021 2022 2023 2024 and After Debt 5 $ 105,869 $ - $ 12,969 $ - $ - $ 92,900 Office space leases 11 2,353 $ 1,540 $ 813 $ - $ - $ - Operations contracts 2,491 $ 2,491 $ - $ - $ - $ - Total contractual obligations (1) $ 110,713 $ 4,031 $ 13,782 $ - $ - $ 92,900

Note 11 - Leases (Tables)

Note 11 - Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Lease, Cost [Table Text Block]	(in thousands) Year Ended December 31, 2019 Consolidated Statements of Operations Classification Building lease cost $ 1,540 General and administrative expense Variable lease cost (1) 118 General and administrative expense $ 1,658 (1) Includes building operating expenses. The following are additional details related to our lease portfolio as of December 31, 2019
Operating Lease, Assets and Liabilities [Table Text Block]	(in thousands) December 31, 2019 Consolidated Balance Sheets Classification Lease asset, gross $ 2,922 Furniture, fixtures and equipment and other capital assets Accumulated depreciation (1,252 ) Accumulated depletion, depreciation and amortization Lease asset, net $ 1,670 Current lease liability $ 1,414 Accrued liabilities Non-current lease liability 800 Other non-current liabilities Total lease liabilities $ 2,214
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	(in thousands) December 31, 2019 2020 1,540 2021 813 2022 - 2023 - Thereafter - Total lease payments $ 2,353 Less imputed interest $ 139 Present value of lease liabilities $ 2,214

Note 13 - Oil and Natural Gas_2

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Notes Tables
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Year Ended December 31, 2019 Year Ended December 31, 2018 Proved properties $ 302,859 $ 206,097 Unproved properties 123 180 302,982 206,277 Less: accumulated depreciation, depletion and amortization (91,958 ) (41,886 ) Net oil and natural gas properties $ 211,024 $ 164,391
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	Year Ended December 31, 2019 Year Ended December 31, 2018 Property Acquisition Unproved $ 269 $ 178 Proved - - Exploration - - Development (1) 98,141 106,583 Total (2) $ 98,410 $ 106,761
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	Natural Gas (Mmcf) Oil, Condensate and NGLs (MBbls) 2019 2018 2017 2019 2018 2017 Net proved reserves at beginning of period 470,937 415,224 286,038 1,441 2,130 2,815 Revisions of previous estimates (1) 37,136 (16,993 ) 106,639 (166 ) (388 ) (381 ) Extensions, discoveries and improved recovery (2) 218,015 100,499 32,871 - - - Purchases of minerals in place - - - - - - Sales of minerals in place (169,310 ) (3,349 ) - - (84 ) - Production (46,712 ) (24,444 ) (10,324 ) (171 ) (217 ) (304 ) Net proved reserves at end of period 510,066 470,937 415,224 1,104 1,441 2,130 Net proved developed reserves: Beginning of period 92,118 52,861 21,872 1,441 2,130 2,815 End of period 138,607 92,118 52,861 1,104 1,441 2,130 Net proved undeveloped reserves: Beginning of period 378,819 362,363 264,166 - - - End of period 371,459 378,819 362,363 - - - Natural Gas Equivalents (Mmcfe) 2019 2018 2017 Net proved reserves at beginning of period 479,583 428,002 302,927 Revisions of previous estimates (1) 36,141 (19,320 ) 104,354 Extensions, discoveries and improved recovery (2) 218,015 100,499 32,871 Purchases of minerals in place - - - Sales of minerals in place (3) (169,310 ) (3,852 ) - Production (47,738 ) (25,746 ) (12,150 ) Net proved reserves at end of period 516,691 479,583 428,002 Net proved developed reserves: Beginning of period 100,764 65,639 44,432 End of period 145,232 100,764 65,639 Net proved undeveloped reserves: Beginning of period 378,819 362,363 258,495 End of period 371,459 378,819 362,363
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	2019 2018 2017 Future revenues $ 1,272,504 $ 1,494,557 $ 1,260,490 Future lease operating expenses and production taxes (377,851 ) (410,957 ) (430,048 ) Future development costs (1) (338,116 ) (349,552 ) (329,938 ) Future income tax expense (13,552 ) (56,784 ) (17,113 ) Future net cash flows 542,985 677,264 483,391 10% annual discount for estimated timing of cash flows (246,031 ) (279,679 ) (223,081 ) Standardized measure of discounted future net cash flows $ 296,954 $ 397,585 $ 260,310 Index price used to calculate reserves (2) Natural gas (per Mcf) $ 2.58 $ 3.10 $ 2.98 Oil (per Bbl) $ 55.69 $ 65.56 $ 51.34
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	Year Ended December 31, 2019 2018 2017 Balance, beginning of year $ 397,585 $ 260,310 $ 56,922 Net changes in prices and production costs related to future production (337,911 ) 95,927 113,319 Sales and transfers of oil and natural gas produced, net of production costs (82,706 ) (63,846 ) (32,012 ) Net change due to revisions in quantity estimates 33,181 (25,595 ) 107,499 Net change due to extensions, discoveries and improved recovery 101,012 129,207 8,970 Net change due to purchases and sales of minerals in place (2,009 ) (3,382 ) - Changes in future development costs 125,179 (4,608 ) (59,560 ) Previously estimated development cost incurred in period 31,340 7,923 8,114 Net change in income taxes 20,185 (16,336 ) (3,686 ) Accretion of discount 41,777 26,416 5,709 Change in production rates (timing) and other (30,679 ) (8,431 ) 55,035 Net increase (decrease) in standardized measures (100,631 ) 137,275 203,388 Balance, end of year $ 296,954 $ 397,585 $ 260,310

Note 1 - Description of Busin_3

Note 1 - Description of Business and Summary of Significant Accounting Policies (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Oil and Gas Property Full Cost Method Period Increase (Decrease)	$ 300	$ 6,000
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	$ 0	$ 0
Minimum [Member]
Property, Plant and Equipment, Useful Life	3 years
Maximum [Member]
Property, Plant and Equipment, Useful Life	5 years

Note 1 - Description of Busin_4

Note 1 - Description of Business and Summary of Significant Accounting Policies - Accounts Payable and Accrued Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Trade payables	$ 11,461	$ 8,633
Revenue payables	14,483	16,665
Prepayments from partners		132
Other	404	304
Total Accounts payable	26,348	25,734
Accrued capital expenditures	6,175	8,086
Accrued lease operating expense	989	1,100
Accrued production and other taxes	430	338
Accrued transportation and gathering	2,258	1,888
Accrued performance bonus	4,642	3,420
Accrued interest	208	443
Accrued office lease	1,414	598
Accrued general and administrative expense and other	499	645
Total Accrued liabilities	$ 16,615	$ 16,518

Note 1 - Description of Busin_5

Note 1 - Description of Business and Summary of Significant Accounting Policies - Concentration of Credit Risk (Details) - Revenue Benchmark [Member] - Customer Concentration Risk [Member]	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
CIMA [Member]
Concentration risk percentage	39.00%	41.00%
Shell [Member]
Concentration risk percentage	19.00%	0.00%
ETC [Member]
Concentration risk percentage	19.00%	15.00%
CES [Member]
Concentration risk percentage	10.00%	8.00%
Genesis Crude Oil LP [Member]
Concentration risk percentage	8.00%	13.00%
Sunoco, Inc. [Member]
Concentration risk percentage	1.00%	4.00%
Williams Energy Resources LLC [Member]
Concentration risk percentage	0.00%	1.00%
Occidental Energy MA [Member]
Concentration risk percentage	0.00%	1.00%

Note 2 - Revenue Recognition (D

Note 2 - Revenue Recognition (Details Textual) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Accrued Oil and Gas Revenue	$ 11,345	$ 14,464

Note 2 - Revenue Recognition -

Note 2 - Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Revenue from Contract with Customer	$ 118,350	$ 87,996
Oil Revenue [Member]
Revenue from Contract with Customer	10,387	14,745
Oil Revenue [Member] | Operated [Member]
Revenue from Contract with Customer	9,961	14,189
Oil Revenue [Member] | Non-operated [Member]
Revenue from Contract with Customer	426	556
Gas Revenue [Member]
Revenue from Contract with Customer	107,953	73,147
Gas Revenue [Member] | Operated [Member]
Revenue from Contract with Customer	91,811	58,911
Gas Revenue [Member] | Non-operated [Member]
Revenue from Contract with Customer	16,142	14,236
NGL Revenue [Member]
Revenue from Contract with Customer	13	51
NGL Revenue [Member] | Operated [Member]
Revenue from Contract with Customer
NGL Revenue [Member] | Non-operated [Member]
Revenue from Contract with Customer	13	51
Oil and Gas [Member]
Revenue from Contract with Customer	118,353	87,943
Oil and Gas [Member] | Operated [Member]
Revenue from Contract with Customer	101,772	73,100
Oil and Gas [Member] | Non-operated [Member]
Revenue from Contract with Customer	$ 16,581	$ 14,843

Note 3 - Share-based Compensa_3

Note 3 - Share-based Compensation Plans (Details Textual) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		499,626	249,751	[1]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value		$ 10.16	$ 11.54	[1]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition		1 year 343 days	1 year 215 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period		530,446	742,607	[1]
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		294,871	249,751	[1]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value		$ 9.96	$ 11.54	[1]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition		1 year 346 days	1 year 127 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period		530,446	742,607	[1]
Performance Stock Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		204,755		[1]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Award Requisite Service Period		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate		0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value		$ 10.43		[1]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition		1 year 339 days	1 year 350 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period				[1]
Performance Stock Units (PSUs) [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Percentage of Stock That May be Awarded		0.00%
Performance Stock Units (PSUs) [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Percentage of Stock That May be Awarded		200.00%
Performance Stock Units (PSUs) Granted in 2019 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Fair Value		$ 2.1
Share-based Payment Arrangement, Nonvested Award, Excluding Option, Cost Not yet Recognized, Amount		$ 2.1
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition		2 years 346 days
The 2017 Performance Bonus Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			201,969
Long Term Incentive Plan 2016 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		0
Long Term Incentive Plan 2016 [Member] | Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		205,000
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
Long Term Incentive Plan 2016 [Member] | Restricted Stock Units (RSUs) [Member] | Non-employee Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	45,160	81,000
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	1 year	1 year
Long Term Incentive Plan 2016 [Member] | Restricted Stock Units (RSUs) [Member] | Employee [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			0
Long Term Incentive Plan 2016 [Member] | Performance Stock Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		205,000
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
Long Term Incentive Plan 2016 [Member] | Performance Stock Units (PSUs) [Member] | Share-based Payment Arrangement, Tranche One [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Maximum Payout		250.00%
Long Term Incentive Plan 2016 [Member] | Performance Stock Units (PSUs) [Member] | Share-based Payment Arrangement, Tranche Two [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Maximum Payout		200.00%
Long Term Incentive Plan 2016 [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			201,969
Long Term Incentive Plan 2016 [Member] | RSUs and PSUs [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		1 year
Long Term Incentive Plan 2016 [Member] | RSUs and PSUs [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
[1]	Includes 201,969 shares of common stock issued in settlement for 2017 performance bonuses, which were paid in 2018.

Note 3 - Share-based Compensa_4

Note 3 - Share-based Compensation Plans - Valuation Assumptions (Details)	12 Months Ended
	Dec. 31, 2019USD ($)$ / shares	Dec. 31, 2018$ / shares	[1]
Grant price (in dollars per share)	$ 10.16	$ 11.54
Performance Stock Units (PSUs) [Member]
Number of simulations	250,000
Grant price (in dollars per share)	$ 10.43
Volatility factor	49.30%
Dividend yield | $
Risk-free interest rate	2.00%
Expected term (Year)	3 years
[1]	Includes 201,969 shares of common stock issued in settlement for 2017 performance bonuses, which were paid in 2018.

Note 3 - Share-based Compensa_5

Note 3 - Share-based Compensation Plans - Components of Share-based Compensation (Details) - Long Term Incentive Plan 2016 [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Share-based compensation	$ 7,137	$ 7,190
Capitalized and lease operating expense share-based compensation	(835)	(747)
Share-based compensation	6,302	6,443
Restricted Stock Units (RSUs) [Member] | Employee [Member]
Share-based compensation	4,521	4,702
Restricted Stock Units (RSUs) [Member] | Director [Member]
Share-based compensation	664	595
Performance Stock Units (PSUs) [Member]
Share-based compensation	$ 1,952	$ 1,893

Note 3 - Share-based Compensa_6

Note 3 - Share-based Compensation Plans - Stock Activity (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018		Dec. 31, 2017
Unvested units (in shares)	1,060,525	1,574,032
Unvested, weighted average grant date fair value (in dollars per share)	$ 12.09	$ 11.29
Unvested, value	$ 10,571	$ 10,760		$ 17,804
Granted units (in shares)	499,626	249,751	[1]
Grant price (in dollars per share)	$ 10.16	$ 11.54	[1]
Granted, value	$ 5,074	$ 2,882	[1]
Vested units (in shares)	(530,446)	(742,607)	[1]
Vested, weighted average grant date fair value (in dollars per share)	$ 10.18	$ 10.20	[1]
Vested, value	$ (5,138)	$ (9,681)	[1]
Forfeited units (in shares)	(9,032)	(20,651)
Forfeited, weighted average grant date fair value (in dollars per share)	$ 13.84	$ 11.90
Forfeited, value	$ (125)	$ (245)
Unvested units (in shares)	1,020,673	1,060,525
Unvested, weighted average grant date fair value (in dollars per share)	$ 12.12	$ 12.09
Restricted Stock Units (RSUs) [Member]
Unvested units (in shares)	661,137	1,171,353
Unvested, weighted average grant date fair value (in dollars per share)	$ 10.16	$ 9.91
Unvested, value	$ 2,328	$ 4,653		11,647
Granted units (in shares)	294,871	249,751	[1]
Grant price (in dollars per share)	$ 9.96	$ 11.54	[1]
Granted, value	$ 2,938	$ 2,882	[1]
Vested units (in shares)	(530,446)	(742,607)	[1]
Vested, weighted average grant date fair value (in dollars per share)	$ 10.18	$ 10.20	[1]
Vested, value	$ (5,138)	$ (9,681)	[1]
Forfeited units (in shares)	(9,032)	(17,360)
Forfeited, weighted average grant date fair value (in dollars per share)	$ 13.84	$ 11.25
Forfeited, value	$ (125)	$ (195)
Unvested units (in shares)	416,530	661,137
Unvested, weighted average grant date fair value (in dollars per share)	$ 9.92	$ 10.16
Performance Stock Units (PSUs) [Member]
Unvested units (in shares)	399,388	402,679
Unvested, weighted average grant date fair value (in dollars per share)	$ 15.29	$ 15.29
Unvested, value	$ 8,243	$ 6,107		$ 6,157
Granted units (in shares)	204,755		[1]
Grant price (in dollars per share)	$ 10.43		[1]
Granted, value	$ 2,136		[1]
Vested units (in shares)			[1]
Vested, weighted average grant date fair value (in dollars per share)			[1]
Vested, value			[1]
Forfeited units (in shares)		(3,291)
Forfeited, weighted average grant date fair value (in dollars per share)		$ 15.29
Forfeited, value		$ (50)
Unvested units (in shares)	604,143	399,388
Unvested, weighted average grant date fair value (in dollars per share)	$ 13.64	$ 15.29
[1]	Includes 201,969 shares of common stock issued in settlement for 2017 performance bonuses, which were paid in 2018.

Note 3 - Share-based Compensa_7

Note 3 - Share-based Compensation Plans - Unrecognized Compensation Cost (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Unrecognized compensation costs	$ 8,252	$ 10,440
Weighted Average years to recognition (Year)	1 year 343 days	1 year 215 days
Restricted Stock Units (RSUs) [Member]
Unrecognized compensation costs	$ 3,969	$ 6,340
Weighted Average years to recognition (Year)	1 year 346 days	1 year 127 days
Performance Stock Units (PSUs) [Member]
Unrecognized compensation costs	$ 4,283	$ 4,100
Weighted Average years to recognition (Year)	1 year 339 days	1 year 350 days

Note 4 - Asset Retirement Obl_3

Note 4 - Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018
Balance		$ 3,791	$ 3,367
Liabilities incurred		224	303
Revisions in estimated liabilities (1)	[1]	63	47
Liabilities settled		(4)	(13)
Accretion expense		297	262
Dispositions (2)	[2]	(202)	(175)
Balance		4,169	3,791
Current liability		0	0
Long term liability		$ 4,169	$ 3,791
[1]	Changes in estimated costs and timing of plugging and abandoning gave rise to the revision in estimated liabilities.
[2]	See Note 12 for further information on the dispositions during the year ended December 31, 2019.

Note 5 - Debt (Details Textual)

Note 5 - Debt (Details Textual) $ / shares in Units, $ in Thousands, shares in Millions		May 31, 2019USD ($)$ / shares	May 29, 2019USD ($)	May 14, 2019USD ($)	Oct. 17, 2017	Oct. 12, 2016USD ($)shares	Dec. 31, 2019USD ($)		Dec. 31, 2018USD ($)		Oct. 11, 2019USD ($)	Aug. 31, 2019USD ($)	May 30, 2019USD ($)
Gain (Loss) on Extinguishment of Debt, Total							$ (1,846)
Debt Instrument, Face Amount							105,869		80,691
Long-term Debt, Gross							104,435		$ 76,820
Costless Warrants Associated with the Convertible Second Lien Notes [Member]
Warrants and Rights Outstanding, Term						10 years
Class of Warrant or Right, Number of Securities Called by Warrants or Rights | shares						2.5
New Convertible Second Lien Notes, New 2L Notes [Member]
Long-term Debt Gross Paid in Kind Interest							1,000
Debt Instrument, Unamortized Discount, Total		$ 1,400					1,100
Debt Issuance Costs, Net, Total							$ 300
Debt Instrument, Interest Rate, Stated Percentage		13.50%					13.50%
Debt Instrument, Interest Rate During Period	[1]						21.60%
Amortization of Debt Discount (Premium)							$ 300
Paid-in-Kind Interest							1,000
Debt Instrument, Covenant Compliance Unrestricted Cash, Maximum		$ 10,000
Debt Instrument, Covenant, Compliance Total Proved Asset Coverage Ratio		1.5
Debt Instrument, Face Amount		$ 12,000					12,969	[2]		[2]
Long-term Debt, Gross		$ 10,600					$ 11,535	[2]		[2]			$ 12,000
Debt Instrument, Convertible, Conversion Price | $ / shares		$ 21.33
Debt Instrument, Convertible, Carrying Amount of Equity Component		$ 1,400
Convertible Second Lien Notes [Member]
Debt Instrument, Unamortized Discount, Total						$ 11,000
Debt Instrument, Interest Rate, Stated Percentage						13.50%	13.50%
Debt Instrument, Interest Rate During Period	[3]						24.10%		23.90%
Amortization of Debt Discount (Premium)							$ 2,300		$ 4,100
Paid-in-Kind Interest							3,000		6,700
Gain (Loss) on Extinguishment of Debt, Total			$ (1,600)
Debt Instrument, Face Amount						$ 40,000		[4]	53,691	[4]
Long-term Debt, Gross						29,000		[4]	$ 49,820	[4]	$ 40,000
Adjustments to Additional Paid in Capital, Convertible Debt with Conversion Feature						$ 11,000
Debt Conversion, Original Debt, Amount			$ 56,700
The 2017 Senior Credit Facility [Member]
Debt Instrument, Interest Rate During Period							7.20%		8.90%
Line of Credit Facility, Maximum Borrowing Capacity				$ 250,000
Line of Credit Facility, Current Borrowing Capacity				75,000
Line of Credit Facility, Commitment Fee Percentage					0.50%
Gain (Loss) on Extinguishment of Debt, Total				(200)
Debt Instrument, Face Amount	[5]								$ 27,000
Long-term Debt, Gross	[5]								$ 27,000
The 2017 Senior Credit Facility [Member] | Minimum [Member] | Base Rate [Member]
Debt Instrument, Basis Spread on Variable Rate					1.75%
The 2017 Senior Credit Facility [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Basis Spread on Variable Rate					2.75%
The 2017 Senior Credit Facility [Member] | Maximum [Member] | Base Rate [Member]
Debt Instrument, Basis Spread on Variable Rate					2.75%
The 2017 Senior Credit Facility [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Basis Spread on Variable Rate					3.75%
The 2019 Senior Credit Facility [Member]
Debt Issuance Costs, Net, Total							$ 2,200
Debt Instrument, Interest Rate During Period							6.00%
Line of Credit Facility, Maximum Borrowing Capacity				500,000
Line of Credit Facility, Current Borrowing Capacity				$ 115,000			$ 125,000					$ 125,000
Line of Credit Facility, Interest Rate at Period End, Default Rate				2.00%
Line of Credit Facility, Interest Rate at Period End							5.047%
Debt Instrument, Covenant Compliance Debt to EBITDAX				4
Debt Instrument, Covenant, Current Ratio				1
Debt Instrument, Covenant Compliance Unrestricted Cash, Maximum				$ 10,000
Debt Instrument, Covenant, Compliance Total Proved Asset Coverage Ratio				1.5
Long-term Line of Credit, Total							$ 92,900
Debt Instrument, Face Amount	[5]						92,900
Long-term Debt, Gross	[5]						$ 92,900
The 2019 Senior Credit Facility [Member] | Letter of Credit [Member]
Line of Credit Facility, Maximum Borrowing Capacity				$ 10,000
The 2019 Senior Credit Facility [Member] | Minimum [Member]
Line of Credit Facility, Commitment Fee Percentage				0.375%
The 2019 Senior Credit Facility [Member] | Minimum [Member] | Base Rate [Member]
Debt Instrument, Basis Spread on Variable Rate				1.50%
The 2019 Senior Credit Facility [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Basis Spread on Variable Rate				2.50%
The 2019 Senior Credit Facility [Member] | Maximum [Member]
Line of Credit Facility, Commitment Fee Percentage				0.50%
The 2019 Senior Credit Facility [Member] | Maximum [Member] | Base Rate [Member]
Debt Instrument, Basis Spread on Variable Rate				2.50%
The 2019 Senior Credit Facility [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Basis Spread on Variable Rate				3.50%
[1]	The New 2L Notes have a coupon interest rate of 13.50%; however, the discount recorded due to the convertibility of the notes increased the effective interest rate to 21.6% for the year ended December 31, 2019. Interest expense for the year ended December 31, 2019 included $0.3 million of debt discount amortization and $1.0 million of accrued interest to be paid in-kind.
[2]	The debt discount is being amortized using the effective interest rate method based upon a maturity date of May 31, 2021. The principal includes paid-in-kind interest of $1.0 million as of December 31, 2019. The carrying value includes $1.1 million of unamortized debt discount and $0.3 million of unamortized issuance cost at December 31, 2019. The fair value of the New 2L Notes, a Level 2 fair value estimate, was obtained by using the last known sale price for the value on December 31, 2019.
[3]	The Convertible Second Lien Notes had a coupon interest rate of 13.50%; however, the discount recorded due to the convertibility of the notes increased the effective interest rate to 24.1% for the year ended December 31, 2019 (until payoff on May 29, 2019) and 23.9% for the year ended December 31, 2018. Interest expense for the year ended December 31, 2019 included $2.3 million of debt discount amortization and $3.0 million of paid-in-kind interest. Interest expense for the year ended December 31, 2018 included $4.1 million of debt discount amortization and $6.7 million of paid-in-kind interest.
[4]	The debt discount was being amortized using the effective interest rate method based upon a maturity date of August 30, 2019 until the Convertible Second Lien Notes were fully paid off on May 29, 2019.
[5]	The carrying amount for the 2017 Senior Credit Facility and the 2019 Senior Credit Facility represent fair value as they were fully secured.

Note 5 - Debt - Components of D

Note 5 - Debt - Components of Debt (Details) - USD ($) $ in Thousands		Dec. 31, 2019		Oct. 11, 2019	May 31, 2019	May 30, 2019	Dec. 31, 2018		Oct. 12, 2016
Principal		$ 105,869					$ 80,691
Carrying amount		104,435					76,820
Fair value		105,852					87,857
The 2017 Senior Credit Facility [Member]
Principal	[1]						27,000
Carrying amount	[1]						27,000
Fair value	[1]						27,000
The 2019 Senior Credit Facility [Member]
Principal	[1]	92,900
Carrying amount	[1]	92,900
Fair value	[1]	92,900
Convertible Second Lien Notes [Member]
Principal			[2]				53,691	[2]	$ 40,000
Carrying amount			[2]	$ 40,000			49,820	[2]	$ 29,000
Fair value	[2]						60,857
New Convertible Second Lien Notes, New 2L Notes [Member]
Principal		12,969	[3]		$ 12,000			[3]
Carrying amount		11,535	[3]		$ 10,600	$ 12,000		[3]
Fair value	[3]	$ 12,952
[1]	The carrying amount for the 2017 Senior Credit Facility and the 2019 Senior Credit Facility represent fair value as they were fully secured.
[2]	The debt discount was being amortized using the effective interest rate method based upon a maturity date of August 30, 2019 until the Convertible Second Lien Notes were fully paid off on May 29, 2019.
[3]	The debt discount is being amortized using the effective interest rate method based upon a maturity date of May 31, 2021. The principal includes paid-in-kind interest of $1.0 million as of December 31, 2019. The carrying value includes $1.1 million of unamortized debt discount and $0.3 million of unamortized issuance cost at December 31, 2019. The fair value of the New 2L Notes, a Level 2 fair value estimate, was obtained by using the last known sale price for the value on December 31, 2019.

Note 5 - Debt - Components of_2

Note 5 - Debt - Components of Debt, Interest Expense and Effective Interest Rate (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018
Interest Expense		$ 11,001	$ 11,944
The 2017 Senior Credit Facility [Member]
Interest Expense		$ 872	$ 1,130
Effective Interest Rate		7.20%	8.90%
The 2019 Senior Credit Facility [Member]
Interest Expense		$ 3,409
Effective Interest Rate		6.00%
Convertible Second Lien Notes [Member]
Interest Expense	[1]	$ 5,304	$ 10,814
Effective Interest Rate	[1]	24.10%	23.90%
New Convertible Second Lien Notes, New 2L Notes [Member]
Interest Expense	[2]	$ 1,416
Effective Interest Rate	[2]	21.60%
[1]	The Convertible Second Lien Notes had a coupon interest rate of 13.50%; however, the discount recorded due to the convertibility of the notes increased the effective interest rate to 24.1% for the year ended December 31, 2019 (until payoff on May 29, 2019) and 23.9% for the year ended December 31, 2018. Interest expense for the year ended December 31, 2019 included $2.3 million of debt discount amortization and $3.0 million of paid-in-kind interest. Interest expense for the year ended December 31, 2018 included $4.1 million of debt discount amortization and $6.7 million of paid-in-kind interest.
[2]	The New 2L Notes have a coupon interest rate of 13.50%; however, the discount recorded due to the convertibility of the notes increased the effective interest rate to 21.6% for the year ended December 31, 2019. Interest expense for the year ended December 31, 2019 included $0.3 million of debt discount amortization and $1.0 million of accrued interest to be paid in-kind.

Note 6 - Net Income (Loss) Pe_3

Note 6 - Net Income (Loss) Per Common Share (Details Textual)	12 Months Ended
	Dec. 31, 2019
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Performance Award of Initial Units Granted, Percent	0.00%
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Performance Award of Initial Units Granted, Percent	250.00%

Note 6 - Net Income (Loss) Pe_4

Note 6 - Net Income (Loss) Per Common Share - Schedule of Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018
Net income applicable to common stock		$ 13,288	$ 1,750
Weighted average shares of common stock outstanding—basic (in shares)		12,233	11,622
Net income per common share—basic (in dollars per share)		$ 1.09	$ 0.15
Common shares issuable on assumed conversion of restricted stock * (in shares)	[1]	348	475
Weighted average shares of common stock outstanding—diluted (in shares)		13,895	13,665
Net income per common share—diluted (in dollars per share)		$ 0.96	$ 0.13
Convertible Debt Securities [Member]
(1) Common shares issuable upon conversion of the New 2L Notes and Convertible Second Lien Notes were not included in the computation of diluted loss per common share since their inclusion would have been anti-dilutive. (in shares)	[2]	608	1,875
Costless Warrants Associated with Convertible Second Lien Notes [Member]
Common shares issuable upon conversion of warrants (in shares)			150
Warrants Associated with Unsecured Claim Holders [Member]
Common shares issuable upon conversion of warrants (in shares)		1,314	1,418
[1]	Common shares issuable on assumed conversion of restricted stock from share-based compensation assumes a payout of the Company's performance share awards at 100% of the initial performance units granted (or a ratio of one unit to one common share). The range of common stock shares which may be earned ranges from zero to 250% of the initial performance units granted.
[2]	Common shares issuable upon conversion of the New 2L Notes and Convertible Second Lien Notes were not included in the computation of diluted loss per common share since their inclusion would have been anti-dilutive. 608 1,875

Note 7 - Income Taxes (Details

Note 7 - Income Taxes (Details Textual) - USD ($) $ in Thousands	Oct. 12, 2016	Dec. 31, 2019	Dec. 31, 2018
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		21.00%
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount		$ (10,000)
Deferred Tax Assets, Valuation Allowance, Total		74,150	$ 84,181
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax		393	$ 786
Proceeds From Deferred Tax Assets		400
Unrecognized Tax Benefits, Ending Balance		0
Domestic Tax Authority [Member]
Operating Loss Carryforwards, Total		846,600
Operating Loss Carryforwards, Available to Offset Future Taxable Income		215,600
Operating Loss Carryforwards, Increase (Decrease)	$ (630,700)
State and Local Jurisdiction [Member] | Louisiana Department of Revenue [Member]
Operating Loss Carryforwards, Increase (Decrease)		77,000
State and Local Jurisdiction [Member] | Mississippi Department of Revenue [Member]
Operating Loss Carryforwards, Increase (Decrease)		151,500
Current Year Activity [Member]
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount		(5,500)
Deferred Tax Asset Which Carried a Full Valuation Allowance [Member]
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount		$ (4,500)

Note 7 - Income Taxes - Tax Exp

Note 7 - Income Taxes - Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Current tax expense (benefit)
Federal	$ (393)	$ (208)
State
Total current tax expense (benefit)	(393)	(208)
Deferred tax expense (benefit)
Federal	393	151
State
Total deferred tax expense (benefit)	393	151
Total tax expense (benefit)	$ 0	$ (57)

Note 7 - Income Taxes - Reconci

Note 7 - Income Taxes - Reconciliation of Income Tax (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Tax expense at U.S. statutory rate	$ 2,790	$ 356
Disallowed executive compensation	821	841
Valuation allowance	(5,499)	(2,530)
State income taxes, net of federal benefit	718	1,194
Nondeductible expenses and other	1,170	82
Total tax expense (benefit)	$ 0	$ (57)

Note 7 - Income Taxes - Deferre

Note 7 - Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Operating loss carry-forwards	$ 45,280	$ 38,958
State tax NOL and credits	11,611	10,278
Statutory depletion carry-forward		4,221
AMT tax credit carry-forward	393	786
Compensation	1,461	1,426
Contingent liabilities and other	378	784
Lease liabilities	465
Debt discount		54
Property and equipment	16,813	28,530
Total gross non-current deferred tax assets	76,401	85,037
Less valuation allowance	(74,150)	(84,181)
Net non-current deferred tax assets	2,251	856
Derivatives	(1,214)	(70)
Right of use asset	(350)
Other	(97)
Debt discount	(197)
Total non-current deferred tax liabilities	(1,858)	(70)
Net non-current deferred tax asset	$ 393	$ 786

Note 8 - Stockholders' Equity (

Note 8 - Stockholders' Equity (Details Textual) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	May 31, 2019
Common Stock, Shares, Outstanding, Ending Balance	12,532,550	12,150,918
Common Stock, Shares Authorized	75,000,000	75,000,000
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	$ 5,100
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	530,000
Payments for Repurchase of Common Stock	$ 2,097	$ 3,089
Treasury Stock, Shares, Acquired	208,000	230,013
Stock Issued During Period, Shares, Warrants		373,437
Long Term Incentive Plan 2016 [Member]
Stock Issued During Period, Shares, New Issues		201,969
New Convertible Second Lien Notes, New 2L Notes [Member]
Debt Instrument, Convertible, Carrying Amount of Equity Component			$ 1,400
Costless Warrants Associated with Convertible Second Lien Notes [Member]
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Class of Warrant or Right, Exercised During Period	150,000	920,312
Warrants and Rights Outstanding, Term	10 years	10 years
Stock Issued During Period, Shares, New Issues	150,000
Class of Warrant or Right, Outstanding		150,000

Note 9 - Derivative Activitie_2

Note 9 - Derivative Activities (Details Textual) $ in Millions	Dec. 31, 2019USD ($)
Commodity Contract [Member]
Loss Contingency, Estimate of Possible Loss	$ 8.2

Note 9 - Derivative Activitie_3

Note 9 - Derivative Activities - Summary of Gains and Losses on Derivatives (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Gain (loss) on derivatives not designated as hedges	$ 15,010	$ (3,986)
Commodity Contract [Member]
Gain (loss) on commodity derivatives not designated as hedges, settled	9,560	(3,236)
Gain (loss) on commodity derivatives not designated as hedges, not settled	5,450	(750)
Gain (loss) on derivatives not designated as hedges	$ 15,010	$ (3,986)

Note 9 - Derivative Activitie_4

Note 9 - Derivative Activities - Outstanding Commodity (Details) - Not Designated as Hedging Instrument [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)MMBTU$ / MMBTU$ / bblbbl
Fair value | $	$ 5,782
The 2020 Oil Swaps [Member]
Average daily volume, oil swaps (Barrel of Oil) | bbl	221
Total volume, oil swaps (Barrel of Oil) | bbl	80,945
Fixed price (in USD per Barrel of Oil) | $ / bbl	59.02
Fair value | $	$ 35
The 2021 Oil Swaps [Member]
Average daily volume, oil swaps (Barrel of Oil) | bbl	220
Total volume, oil swaps (Barrel of Oil) | bbl	18,000
Fixed price (in USD per Barrel of Oil) | $ / bbl	56.58
Fair value | $	$ 24
Total Crude Oil [Member]
Fair value | $	$ 59
The 2020 Natural Gas Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	2.67
Fair value | $	$ 7,502
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	51,631
Total volume, natural gas swaps (Millions of British Thermal Unit)	18,897,000
The 2021 Natural Gas Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	2.64
Fair value | $	$ 11
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	42,656
Total volume, natural gas swaps (Millions of British Thermal Unit)	3,839,000
The 2020 Natural Gas Collar [Member]
Fair value | $	$ 901
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	18,287
Total volume, natural gas swaps (Millions of British Thermal Unit)	6,693,000
The 2020 Natural Gas Collar [Member] | Minimum [Member]
Fixed price (in USD per Millions of British Thermal Unit) | $ / MMBTU	2.4
The 2020 Natural Gas Collar [Member] | Maximum [Member]
Fixed price (in USD per Millions of British Thermal Unit) | $ / MMBTU	2.625
The 2021 Natural Gas Collar [Member]
Fair value | $	$ (314)
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	27,000
Total volume, natural gas swaps (Millions of British Thermal Unit)	2,430,000
The 2021 Natural Gas Collar [Member] | Minimum [Member]
Fixed price (in USD per Millions of British Thermal Unit) | $ / MMBTU	2.4
The 2021 Natural Gas Collar [Member] | Maximum [Member]
Fixed price (in USD per Millions of British Thermal Unit) | $ / MMBTU	2.625
Total Natural Gas [Member]
Fair value | $	$ 8,100
The 2020 Natural Gas Basis Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	0.209
Fair value | $	$ 99
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	50,000
Total volume, natural gas swaps (Millions of British Thermal Unit)	18,300,000
The 2021 Natural Gas Basis Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	0.209
Fair value | $	$ (239)
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	50,000
Total volume, natural gas swaps (Millions of British Thermal Unit)	18,250,000
The 2022 Natural Gas Basis Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	0.209
Fair value | $	$ (518)
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	50,000
Total volume, natural gas swaps (Millions of British Thermal Unit)	18,250,000
The 2023 Natural Gas Basis Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	0.209
Fair value | $	$ (679)
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	50,000
Total volume, natural gas swaps (Millions of British Thermal Unit)	18,250,000
The 2024 Natural Gas Basis Swaps [Member]
Fixed price (in USD per Barrel of Oil) | $ / MMBTU	0.209
Fair value | $	$ (1,040)
Average daily volume, natural gas swaps (Millions of British Thermal Unit)	50,000
Total volume, natural gas swaps (Millions of British Thermal Unit)	18,300,000
Total Natural Gas Basis Swap [Member]
Fair value | $	$ (2,377)

Note 9 - Derivative Activitie_5

Note 9 - Derivative Activities - Reconciliation of Gross Amounts to Amounts As Presented on Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Fair value of oil and natural gas derivatives - Current Assets	$ 8,537	$ 803
Fair value of oil and natural gas derivatives - Non-current Assets	31
Fair value of oil and natural gas derivatives - Non-current Liabilities	(2,786)	$ (471)
Not Designated as Hedging Instrument [Member]
Total	5,782
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Fair value of oil and natural gas derivatives - Current Assets	8,537
Fair value of oil and natural gas derivatives - Non-current Assets	31
Fair value of oil and natural gas derivatives - Current Liabilities
Fair value of oil and natural gas derivatives - Non-current Liabilities	(2,786)
Total	5,782
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value of oil and natural gas derivatives - Current Assets
Fair value of oil and natural gas derivatives - Non-current Assets
Fair value of oil and natural gas derivatives - Current Liabilities
Fair value of oil and natural gas derivatives - Non-current Liabilities
Total
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value of oil and natural gas derivatives - Current Assets	8,537
Fair value of oil and natural gas derivatives - Non-current Assets	31
Fair value of oil and natural gas derivatives - Current Liabilities
Fair value of oil and natural gas derivatives - Non-current Liabilities	(2,786)
Total	5,782
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value of oil and natural gas derivatives - Current Assets
Fair value of oil and natural gas derivatives - Non-current Assets
Fair value of oil and natural gas derivatives - Current Liabilities
Fair value of oil and natural gas derivatives - Non-current Liabilities
Total

Note 9 - Derivative Activitie_6

Note 9 - Derivative Activities - Derivative Table, Fair Value with Netting (Details) - Not Designated as Hedging Instrument [Member] - Commodity Contract [Member] $ in Thousands	Dec. 31, 2019USD ($)
Derivative Asset, Gross Amount	$ 5,782
Derivative Asset, Amount Offset
Derivative Asset, As Presented	5,782
Current Assets [Member]
Derivative Asset, Gross Amount	9,401
Derivative Asset, Amount Offset	(864)
Derivative Asset, As Presented	8,537
Non-current Assets [Member]
Derivative Asset, Gross Amount	847
Derivative Asset, Amount Offset	(816)
Derivative Asset, As Presented	31
Current Liabilities [Member]
Derivative Asset, Gross Amount	(864)
Derivative Asset, Amount Offset	864
Derivative Asset, As Presented
Non-current Liabilities [Member]
Derivative Asset, Gross Amount	(3,602)
Derivative Asset, Amount Offset	816
Derivative Asset, As Presented	$ (2,786)

Note 10 - Commitments and Con_3

Note 10 - Commitments and Contingencies (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation, Ending Balance	$ 4,169	$ 3,791	$ 3,367
Operating Leases, Rent Expense, Total	$ 1,700	$ 1,600

Note 10 - Commitments and Con_4

Note 10 - Commitments and Contingencies - Timing of Future Payments Obligations (Details) $ in Thousands	Dec. 31, 2019USD ($)
Debt	$ 105,869
Debt, 2020
Debt, 2021	12,969
Debt, 2022
Debt, 2023
Debt, 2024 and thereafter	92,900
Operating lease	2,353
Operating lease, 2020	1,540
Operating lease, 2021	813
Operating lease, 2022
Operating lease, 2023
Operating lease, 2024 and thereafter
Operations contracts	2,491
Operations contracts, 2020	2,491
Operations contracts, 2021
Operations contracts, 2022
Operations contracts, 2023
Operations contracts, 2024 and thereafter
Total contractual obligations	110,713	[1]
Total contractual obligations, 2020	4,031	[1]
Total contractual obligations, 2021	13,782	[1]
Total contractual obligations, 2022		[1]
Total contractual obligations, 2023		[1]
Total contractual obligations. 2024 and thereafter	$ 92,900	[1]
[1]	This table does not include the estimated liability for dismantlement, abandonment and restoration costs of oil and natural gas properties of $4.2 million as of December 31, 2019. We record a separate liability for the asset retirement obligations. See Note 4.

Note 11 - Leases (Details Textu

Note 11 - Leases (Details Textual) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Operating Lease, Weighted Average Remaining Lease Term	1 year 109 days
Operating Lease, Weighted Average Discount Rate, Percent	8.00%
Operating Lease, Payments	$ 1.6

Note 11 - Leases - Lease Cost a

Note 11 - Leases - Lease Cost and Information (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
	$ 1,658
General and Administrative Expense [Member]
Building lease cost	1,540
Variable lease cost (1)	$ 118	[1]
[1]	Includes building operating expenses.

Note 11 - Leases - Assets and L

Note 11 - Leases - Assets and Liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Accumulated depreciation	$ 1,252
Lease asset, net	1,670
Non-current lease liability	800
Furniture, Fixtures and Equipment and Other Capital Assets [Member]
Lease asset, gross	2,922
Accounts Payable and Accrued Liabilities [Member]
Current lease liability	1,414
Other Noncurrent Liabilities [Member]
Non-current lease liability	800
Furniture, Fixtures and Equipment and Other Capital Assets Accrued Liabilities and Other Noncurrent Liabilities [Member]
Total lease liabilities	$ 2,214

Note 11 - Leases - Lease Liabil

Note 11 - Leases - Lease Liability Maturities (Details) $ in Thousands	Dec. 31, 2019USD ($)
2020	$ 1,540
2021	813
2022
2023
Thereafter
Total lease payments	2,353
Less imputed interest	139
Furniture, Fixtures and Equipment and Other Capital Assets Accrued Liabilities and Other Noncurrent Liabilities [Member]
Present value of lease liabilities	$ 2,214

Note 12 - Dispositions and Ac_2

Note 12 - Dispositions and Acquisitions (Details Textual) - USD ($) $ in Thousands	Mar. 01, 2019	May 21, 2018	Feb. 28, 2018	Dec. 31, 2019	Dec. 31, 2018
Proceeds from Sale of Productive Assets, Total	$ 1,300	$ 3,300	$ 23,000	$ 1,334	$ 26,839
Other Miscellaneous Acreage [Member]
Proceeds from Sale of Productive Assets, Total					$ 700

Note 13 - Oil and Natural Gas_3

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) (Details Textual) Mcfe in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2019USD ($)Mcfe$ / MMBTU$ / bbl	Dec. 31, 2018USD ($)Mcfe$ / MMBTU$ / bbl	Dec. 31, 2017$ / MMBTU$ / bbl
Costs Incurred, Asset Retirement Obligation Incurred		$ 0.1	$ 0.1
Proved Developed and Undeveloped Reserves, Sale of Mineral in Place (Energy) | Mcfe		54,571	2,500
Oil and Gas Reclamation Liability, Noncurrent		$ 7.4	$ 7.3
Crude Oil and Natural Gas Liquids (NGL) [Member]
Oil and Gas, Average Sale Price | $ / bbl	[1]	55.69	65.56	51.34
Natural Gas and Natural Gas Liquids [Member]
Oil and Gas, Average Sale Price | $ / MMBTU	[1]	2.58	3.1	2.98
[1]	These index prices, used to estimate our reserves at these dates, are before deducting or adding applicable transportation and quality differentials on a well-by-well basis.

Note 13 - Oil and Natural Gas_4

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) - Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Proved properties	$ 302,859	$ 206,097
Unproved properties	123	180
	302,982	206,277
Less: accumulated depreciation, depletion and amortization	(91,958)	(41,886)
Net oil and natural gas properties	$ 211,024	$ 164,391

Note 13 - Oil and Natural Gas_5

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) - Costs Incurred (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018
Unproved		$ 269	$ 178
Proved
Exploration
Development (1)	[1]	98,141	106,583
Total (2)	[2]	$ 98,410	$ 106,761
[1]	Includes asset retirement costs of $0.1 million in 2019 and less than $0.1 million in 2018.
[2]	Substantially all the costs incurred related to the Haynesville Shale Trend.

Note 13 - Oil and Natural Gas_6

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) - Net Proved Oil and Natural Gas Reserves (Details)		12 Months Ended
		Dec. 31, 2019MMBblsMMcf	Dec. 31, 2018MMBblsMMcf	Dec. 31, 2017MMBblsMMcf
Natural Gas and Natural Gas Liquids [Member]
Net proved reserves at beginning of period (Millions Cubic Feet)		470,937	415,224	286,038
Revisions of previous estimates (1) (Millions Cubic Feet)	[1]	37,136	(16,993)	106,639
Extensions, discoveries and improved recovery (2) (Millions Cubic Feet)	[2]	218,015	100,499	32,871
Purchases of minerals in place (Millions Cubic Feet)
Sales of minerals in place (Millions Cubic Feet)		(169,310)	(3,349)
Production (Millions Cubic Feet)		(46,712)	(24,444)	(10,324)
Net proved reserves at end of period (Millions Cubic Feet)		510,066	470,937	415,224
Beginning of period (Millions Cubic Feet)		92,118	52,861	21,872
End of period (Millions Cubic Feet)		138,607	92,118	52,861
Beginning of period (Millions Cubic Feet)		378,819	362,363	264,166
End of period (Millions Cubic Feet)		371,459	378,819	362,363
Crude Oil and Natural Gas Liquids (NGL) [Member]
Net proved reserves at beginning of period (Millions Cubic Feet) | MMBbls		1,441	2,130	2,815
Revisions of previous estimates (1) (Millions Cubic Feet) | MMBbls	[1]	(166)	(388)	(381)
Extensions, discoveries and improved recovery (2) (Millions Cubic Feet) | MMBbls	[2]
Purchases of minerals in place (Millions Cubic Feet) | MMBbls
Sales of minerals in place (Millions Cubic Feet) | MMBbls			(84)
Production (Millions Cubic Feet) | MMBbls		(171)	(217)	(304)
Net proved reserves at end of period (Millions Cubic Feet) | MMBbls		1,104	1,441	2,130
Beginning of period (Millions Cubic Feet) | MMBbls		1,441	2,130	2,815
End of period (Millions Cubic Feet) | MMBbls		1,104	1,441	2,130
Beginning of period (Millions Cubic Feet) | MMBbls
End of period (Millions Cubic Feet) | MMBbls
Natural Gas Equivalents [Member]
Net proved reserves at beginning of period (Millions Cubic Feet)		479,583	428,002	302,927
Revisions of previous estimates (1) (Millions Cubic Feet)	[1]	36,141	(19,320)	104,354
Extensions, discoveries and improved recovery (2) (Millions Cubic Feet)	[2]	218,015	100,499	32,871
Purchases of minerals in place (Millions Cubic Feet)
Sales of minerals in place (Millions Cubic Feet)	[3]	(169,310)	(3,852)
Production (Millions Cubic Feet)		(47,738)	(25,746)	(12,150)
Net proved reserves at end of period (Millions Cubic Feet)		516,691	479,583	428,002
Beginning of period (Millions Cubic Feet)		100,764	65,639	44,432
End of period (Millions Cubic Feet)		145,232	100,764	65,639
Beginning of period (Millions Cubic Feet)		378,819	362,363	258,495
End of period (Millions Cubic Feet)		371,459	378,819	362,363
[1]	Revisions of previous estimates in 2019 were positive, primarily due to improved well performance. Revisions of previous estimates in 2018 were negative, primarily due to increases in our operating expenditures and other tax rates. Revisions of previous estimates in 2017 were positive, primarily due to the application of both experience and ever improving technology in drilling and completing Haynesville Shale natural gas wells. Well production performance has improved by drilling longer laterals, increasing both the number of frac stages and the amount of sand used in each frac stage.
[2]	Extensions and discoveries were positive on an overall basis in all three periods presented, primarily reflecting our successful drilling results on our Haynesville Shale Trend properties.
[3]	In 2019, we sold approximately 54,571 Mmcfe and in 2018, we sold approximately 2,500 Mmcfe, attributed to the sale of producing properties in the TMS and Haynesville Shale.

Note 13 - Oil and Natural Gas_7

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) - Standardized Measures (Details) $ in Thousands		12 Months Ended
		Dec. 31, 2019USD ($)$ / MMBTU$ / bbl	Dec. 31, 2018USD ($)$ / MMBTU$ / bbl	Dec. 31, 2017USD ($)$ / MMBTU$ / bbl	Dec. 31, 2016USD ($)
Future revenues		$ 1,272,504	$ 1,494,557	$ 1,260,490
Future lease operating expenses and production taxes		(377,851)	(410,957)	(430,048)
Future development costs (1)	[1]	(338,116)	(349,552)	(329,938)
Future income tax expense		(13,552)	(56,784)	(17,113)
Future net cash flows		542,985	677,264	483,391
10% annual discount for estimated timing of cash flows		(246,031)	(279,679)	(223,081)
Standardized measure of discounted future net cash flows		$ 296,954	$ 397,585	$ 260,310	$ 56,922
Natural Gas and Natural Gas Liquids [Member]
Index price used to calculate reserves (in USD per Millions of British Thermal Unit) | $ / MMBTU	[2]	2.58	3.1	2.98
Crude Oil and Natural Gas Liquids (NGL) [Member]
Index price used to calculate reserves (in USD per Millions of British Thermal Unit) | $ / bbl	[2]	55.69	65.56	51.34
[1]	Includes cumulative asset retirement obligations of $7.4 million and $7.3 million in 2019 and 2018, respectively.
[2]	These index prices, used to estimate our reserves at these dates, are before deducting or adding applicable transportation and quality differentials on a well-by-well basis.

Note 13 - Oil and Natural Gas_8

Note 13 - Oil and Natural Gas Producing Activities (Unaudited) - Changes in the Standardized Measure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Balance, beginning of year	$ 397,585	$ 260,310	$ 56,922
Net changes in prices and production costs related to future production	(337,911)	95,927	113,319
Sales and transfers of oil and natural gas produced, net of production costs	(82,706)	(63,846)	(32,012)
Net change due to revisions in quantity estimates	33,181	(25,595)	107,499
Net change due to extensions, discoveries and improved recovery	101,012	129,207	8,970
Net change due to purchases and sales of minerals in place	(2,009)	(3,382)
Changes in future development costs	125,179	(4,608)	(59,560)
Previously estimated development cost incurred in period	31,340	7,923	8,114
Net change in income taxes	20,185	(16,336)	(3,686)
Accretion of discount	41,777	26,416	5,709
Change in production rates (timing) and other	(30,679)	(8,431)	55,035
Net increase (decrease) in standardized measures	(100,631)	137,275	203,388
Balance, end of year	$ 296,954	$ 397,585	$ 260,310