Abraxas Petroleum (AXAS) 10-K 7 May 21 2020 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2020	Apr. 30, 2021	Jun. 30, 2020
Document Information [Line Items]
Entity Central Index Key	0000867665
Entity Registrant Name	ABRAXAS PETROLEUM CORP
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2020
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2020
Document Transition Report	false
Entity File Number	001-16071
Entity Incorporation, State or Country Code	NV
Entity Tax Identification Number	74-2584033
Entity Address, Address Line One	18803 Meisner Drive
Entity Address, City or Town	San Antonio
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	78258
City Area Code	210
Local Phone Number	490-4788
Title of 12(b) Security	Common Stock, par value $.01 per share
Trading Symbol	AXAS
Security Exchange Name	NASDAQ
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 31,865,614
Entity Common Stock, Shares Outstanding		8,421,910

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 2,775	$ 0
Accounts receivable:
Joint owners, net	1,255	2,397
Oil and gas production sales	8,794	16,985
Other	0	263
Total accounts receivable	10,049	19,645
Derivative asset - short-term	9,639	83
Other current assets	1,588	1,193
Total current assets	24,051	20,921
Proved oil and gas properties, full cost method	1,167,333	1,162,094
Other property and equipment	39,456	39,295
Total	1,206,789	1,201,389
Less accumulated depreciation, depletion, amortization and impairment	(1,083,843)	(872,431)
Total property and equipment - net	122,946	328,958
Operating lease right-of-use assets	228	327
Derivative asset, long-term	10,281	4,170
Other assets	255	255
Total assets	157,761	354,631
Current liabilities:
Accounts payable	6,074	19,280
Joint interest oil and gas production payable	8,795	18,050
Accrued interest	86	133
Other accrued liabilities	230	361
Derivative liabilities - short-term	480	10,688
Right of use liability	53	98
Current maturities of long-term debt	202,751	280
Other current liabilities	850	582
Total current liabilities	219,319	49,472
Derivative liabilities long-term	0	999
Right of use liability	150	203
Future site restoration	7,360	7,420
Total liabilities	230,728	250,812
Commitments and contingencies (Note 8)
Stockholders' Equity
Preferred stock, par value $0.01 per share - authorized 1,000,000 shares; - 0- shares issued and outstanding	0	0
Common stock, par value $0.01 per share, authorized 20,000,000 shares; 8,436,498 and 8,421,910 issued and outstanding at December 31, 2019 and 2020, respectively	85	84
Additional paid-in capital	429,475	421,740
Accumulated deficit	(502,527)	(318,005)
Total stockholders' equity	(72,967)	103,819
Total liabilities and stockholders' equity	157,761	354,631
Debt Instruments Excluding PPP Loan [Member]
Current liabilities:
Long-term debt - less current maturities	2,515	192,718
Paycheck Protection Program, CARES Act [Member]
Current liabilities:
Long-term debt - less current maturities	$ 1,384	$ 0

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - $ / shares	Dec. 31, 2020	Dec. 31, 2019
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, authorized (in shares)	1,000,000	1,000,000
Preferred stock, issued (in shares)	0	0
Preferred stock, outstanding (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	20,000,000	20,000,000
Common stock, issued (in shares)	8,421,910	8,436,498
Common stock, outstanding (in shares)	8,421,910	8,436,498

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Revenues:
Other	$ 59	$ 154
Total Revenue	43,043	129,146
Operating costs and expenses
Lease operating	16,458	27,619
Production and ad valorem taxes	4,632	10,610
Rig expense	762	1,333
Depreciation, depletion, amortization and accretion	24,846	52,703
Proved property impairment	186,980	51,293
General and administrative (including stock-based compensation of $1,911 and $1,312, respectively)	8,783	11,304
Total operating costs and expenses	242,461	154,862
Operating (loss) income	(199,418)	(25,716)
Other (income) expense:
Interest income	(39)	(65)
Interest expense	21,281	12,335
Amortization of deferred financing fees	2,565	543
Loss on debt extinguishment	4,108	0
Loss (gain) on derivative contracts	(42,880)	26,831
Loss on sale of non-oil and gas assets	0	33
Other	69	(389)
Total other expense (income)	(14,896)	39,288
(Loss) income before income tax	(184,522)	(65,004)
Income tax (expense) benefit	0	0
Net (loss) income	$ (184,522)	$ (65,004)
Net (loss) income per common share - basic (in dollars per share)	$ (22.01)	$ (7.82)
Net (loss) income per common share - diluted (in dollars per share)	$ (22.01)	$ (7.82)
Weighted average shares outstanding
Basic (in shares)	8,382	8,312
Diluted (in shares)	8,382	8,315
Oil Revenues [Member]
Revenues:
Revenues	$ 41,969	$ 124,503
Gas Revenues [Member]
Revenues:
Revenues	586	2,579
Natural Gas Liquids Revenues [Member]
Revenues:
Revenues	$ 429	$ 1,910

Consolidated Statements of Op_2

Consolidated Statements of Operations (Parentheticals) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Stock-based compensation	$ 1,312	$ 1,911

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Total
Balance (in shares) at Dec. 31, 2018	8,354,133
Balance at Dec. 31, 2018	$ 83	$ 419,428	$ (253,001)	$ 166,510
Net loss	0	0	(65,004)	(65,004)
Stock-based compensation	0	1,911	0	1,911
Stock options exercised	$ 0	402	0	402
Restricted stock issued, net of forfeitures (in shares)	61,196
Restricted stock issued, net of forfeitures	$ 1	(1)	0	$ 0
Balance (in shares) at Dec. 31, 2019	8,436,498			8,436,498
Balance at Dec. 31, 2019	$ 84	421,740	(318,005)	$ 103,819
Net loss	0		(184,522)	(184,522)
Stock-based compensation	0	1,312	0	1,312
Stock options exercised	0	0	0	0
Warrant issued	$ 0	6,424		$ 6,424
Restricted stock forfeitures and cancellations (in shares)	(14,588)
Balance (in shares) at Dec. 31, 2020	8,421,910			8,421,910
Balance at Dec. 31, 2020	$ 84	$ 429,476	$ (502,527)	$ (72,967)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Operating Activities:
Net (loss)	$ (184,522)	$ (65,004)
Adjustments to reconcile net (loss) to net cash provided by operating activities:
Loss on sale of non-oil and gas assets	0	33
Net loss (gain) on derivative contracts	(42,880)	26,831
Net cash settlements (paid) received on derivative contracts	16,006	(4,317)
Depreciation, depletion and amortization	24,432	52,267
Proved property impairment	186,980	51,293
Amortization of deferred financing fees and issuance discount	3,926	738
Accretion expense and other	414	436
Loss on debt extinguishment	4,108	0
Plugging cost	(236)	(890)
Non-cash interest	12,695	0
Stock-based compensation	1,312	1,911
Changes in operating assets and liabilities:
Accounts receivable	9,596	19,991
Other assets	(394)	1,092
Accounts payable	(15,304)	(10,491)
Accrued expenses and other	(148)	(243)
Net cash provided by operating activities	15,985	73,647
Investing Activities
Capital expenditures, including purchase and development of properties	(12,557)	(108,673)
Proceeds from the sale of oil and gas properties	0	23,434
Proceeds from the sale of non-oil and gas assets	0	272
Net cash used in investing activities	(12,557)	(84,967)
Financing Activities
Proceeds from exercise of stock options and restricted stock	0	402
Payments of long-term borrowings	(9,059)	(124,692)
Deferred financing fees	(978)	(1,960)
Net cash provided by (used) in financing activities	(653)	10,453
(Decrease) increase in cash and cash equivalents	2,775	(867)
Cash and cash equivalents at beginning of period	0	867
Cash and cash equivalents at end of period	2,775	0
Supplemental disclosure of cash flow information:
Interest paid	7,174	12,340
Income tax paid	0	0
Non-cash investing and financing activities
Change in asset retirement obligation cost and liabilities	(22)	855
Asset retirement obligations associated with dispositions	(216)	(473)
Change in capital expenditures included in accounts payable	(7,157)	(16,489)
Paycheck Protection Program, CARES Act [Member]
Financing Activities
Proceeds from long-term borrowings	1,384	0
First Lien Credit Facility [Member]
Financing Activities
Proceeds from long-term borrowings	8,000	40,203
Second Lien Credit Facility [Member]
Financing Activities
Proceeds from long-term borrowings	$ 0	$ 96,500

Note 1 - Organization and Signi

Note 1 - Organization and Significant Accounting Policies	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Organization, Consolidation and Presentation of Financial Statements Disclosure and Significant Accounting Policies [Text Block]	1. Nature of Operations We are an independent energy company primarily engaged in the acquisition, exploitation, development and production of oil and gas in the United States. Our oil and gas assets are located primarily in two The terms “Abraxas,” “Abraxas Petroleum,” “we,” “us,” “our” or the “Company” refer to Abraxas Petroleum Corporation and all of its subsidiaries, including Raven Drilling LLC (“Raven Drilling”). Going Concern Our present level of indebtedness and the recent commodity price environment present challenges to our ability to comply with certain covenants in our credit facilities and under applicable auditing standards the independent accountants' opinion on our financial statements for the year ended December 31, 2020 December 31, 2020 April 30, 2021, Specifically, with regard to our credit agreements, we did not first December 31, 2020 not 4 first September 30, 2021, twelve December 31, 2020 not We are evaluating the available financial alternatives and are in discussion with our lenders seeking additional waivers or amendments to the covenants or other provisions of our credit facilities to address any current and future default relating to the covenants in question. The existing defaults at March 31, 2021 May 6, 2021. No may not Under applicable accounting principles these circumstances are deemed to create substantial doubt regarding the Company's ability to continue as a "going concern". The consolidated financial statements have been prepared on a "going concern" basis, which contemplates the realization of assets and the satisfaction of liabilities and other commitments in the normal course of business for the twelve not may In April 2021, April 15 April 30, 2021. may may 14 Rig Accounting In accordance with SEC Regulation S- X, no not 2019 2020 Use of Estimates The consolidated financial statements of the Company have been prepared by management in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The most significant estimates pertain to proved oil, gas and NGL reserves and related cash flow estimates used in impairment tests of oil and gas properties, the fair value of assets and liabilities acquired in business combinations, derivative contracts, the provision for income taxes including uncertain tax positions, stock based compensation, asset retirement obligations, accrued oil and gas revenues and expenses, as well as estimates of expenses related to depreciation, depletion, amortization and accretion. Actual results could differ from those estimates. The process of estimating oil and gas reserves in accordance with SEC requirements is complex and involves decisions and assumptions in evaluating the available geological, geophysical, engineering and economic data. Accordingly, these estimates are imprecise. Actual future production, oil and gas prices, differentials, revenues, taxes, capital expenditures, operating expenses and quantities of recoverable oil and gas reserves most likely will vary from those estimated. Any significant variance could materially affect the estimated quantities and present value of our reserves. In addition, we may Reclassifications Certain reclassifications have been made to the prior year financial statements to conform to the current period presentation. These reclassifications were to share and per share data related to the 1 October 19, 2020 no Concentration of Credit Risk Financial instruments which potentially expose the Company to credit risk consist principally of trade receivables and derivative contracts. Accounts receivable are generally from companies with significant oil and gas marketing or operating activities. The Company performs ongoing credit evaluations and, generally, requires no The Company maintains any cash and cash equivalents in excess of federally insured limits in prominent financial institutions considered by the Company to be of high credit quality. Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand deposits and short-term investments with original maturities of three Accounts Receivable Accounts receivable are reported net of an allowance for doubtful accounts of approximately $0.1 million at December 31, 2019 2020 Industry Segment and Geographic Information The Company operates in one no Oil and Gas Properties The Company follows the full cost method of accounting for oil and gas properties. Under this method, certain direct costs and indirect costs associated with acquisition of properties and successful as well as unsuccessful exploration and development activities are capitalized. Depreciation, depletion, and amortization of capitalized oil and gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method based on proved reserves. Net capitalized costs of oil and gas properties, less related deferred taxes, are limited by country, to the lower of unamortized cost or the cost ceiling, defined as the sum of the present value of estimated future net revenues from proved reserves based on unescalated prices discounted at 10%, plus the cost of properties not No not December 31, 2019 2020 Other Property and Equipment Other property and equipment are recorded at cost. Depreciation of other property and equipment is provided over the estimated useful lives using the straight-line method. Major renewals and improvements are recorded as additions to the property and equipment accounts. Repairs that do not Estimates of Proved Oil and Gas Reserves Estimates of our proved reserves included in this report are prepared in accordance with GAAP and SEC guidelines. The accuracy of a reserve estimate is a function of: • the quality and quantity of available data; • the interpretation of that data; • the accuracy of various mandated economic assumptions; and • the judgment of the persons preparing the estimate. Our proved reserve information included in this report was based on studies performed by our independent petroleum engineers assisted by the engineering and operations departments of Abraxas. Estimates prepared by other third may may may In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the average of oil and gas prices based on the unweighted average 12 first may The estimates of proved reserves materially impact depreciation, depletion and amortization, or DD&A expense. If the estimates of proved reserves decline, the rate at which we record DD&A expense will increase, reducing future net income. Such a decline may may Derivative Instruments and Hedging Activities The Company enters into agreements to hedge the risk of future oil and gas price fluctuations. Such agreements are typically in the form of fixed price commodity and basis swaps, which limit the impact of price fluctuations with respect to the Company’s sale of oil and gas. While it is never management’s intention to hold or issue derivative instruments for speculative trading purposes, conditions could arise where actual production is less than estimated which could result in over hedged volumes. All derivative instruments are recorded on the Consolidated Balance Sheets at fair value as either short-term or long-term assets or liabilities based on their anticipated settlement date. The derivative instruments the Company utilizes are based on index prices that may 815. not Fair Value of Financial Instruments The Company includes fair value information in the notes to consolidated financial statements when the fair value of its financial instruments is materially different from the carrying value. The carrying value of those financial instruments that are classified as current, except for derivative instruments, approximates fair value because of the short maturity of these instruments. For noncurrent financial instruments, the Company uses quoted market prices or, to the extent that there are no Share-Based Payments Options granted are valued at the date of grant and expense is recognized over the vesting period. The Company currently utilizes a standard option pricing model (Black-Scholes) to measure the fair value of stock options granted to employees and directors. Restricted stock awards are awards of common stock that are subject to restrictions on transfer and to a risk of forfeiture if the awardee terminates employment with the Company prior to the lapse of the restrictions. The value of such restricted stock is determined using the market price on the grant date and expense is recorded over the vesting period. For the years ended December 31, 2019 2020 Restoration, Removal and Environmental Liabilities The Company is subject to extensive federal, state and local environmental laws and regulations. These laws regulate the discharge of materials into the environment and may no Liabilities for expenditures of a noncapital nature are recorded when environmental assessments and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments for the liability or component are fixed or reliably determinable. The fair value of a liability for an asset's retirement obligation is recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period and the capitalized cost is depreciated over the estimated useful life of the related asset. For all periods presented, we have included estimated future costs of abandonment and dismantlement in our full cost amortization base and we amortize these costs as a component of our depletion expense in the accompanying consolidated financial statements. Each year, the Company reviews, and to the extent necessary, revises its asset retirement obligation estimates. The following table (in thousands) summarizes changes in the Company’s future site restoration obligations during the two December 31: 2019 2020 Beginning future site restoration obligation $ 7,492 $ 7,420 New wells placed on production and other 80 43 Deletions related to property disposals (473 ) (216 ) Deletions related to plugging costs (890 ) (235 ) Accretion expense and other 436 414 Revisions and other 775 (66 ) Ending future site restoration obligation $ 7,420 $ 7,360 Revenue Recognition and Major Purchasers The Company recognizes oil and gas revenue from its interest in producing wells as oil and gas is sold from those wells, net of royalties, control of the product has transferred to the purchaser and collectability is reasonably assured. The Company had no December 31, 2019 2020 During 2019 2020 Deferred Financing Fees Deferred financing fees are being amortized on the effective yield basis over the term of the related debt. Income Taxes Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to be in effect with respect to taxable income in the years in which those temporary differences are expected to be recovered or settled. Uncertainties exist as to the future utilization of the operating loss carryforwards. Therefore, we have established a valuation allowance of $117.27 million for deferred tax assets at December 31, 2020 Accounting for Uncertainty in Income Taxes Evaluation of a tax position is a two first not second not 50% Tax positions that previously failed to meet the more-likely-than- not first no not first no no December 31, 2020 Adoption of New Accounting Standards Effective January 1, 2020, 2016 13 30 not In November 2019, 2019 12 740” 2019 12 740 2019 12 December 15, 2020. not In March 2020, No. 2020 04, 840 2020 04” 2020 04 470 December 31, 2022. In May 2020, not not January 1, 2021,

Note 2 - Revenue From Contracts

Note 2 - Revenue From Contracts With Customers	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Revenue from Contract with Customer [Text Block]	2. Revenue Recognition Sales of oil, gas and NGL are recognized at the point in time when control of the product is transferred to the customer and collectability is reasonably assured. The Company's contracts’ pricing provisions are tied to a market index, with certain adjustments based on, among other factors, physical location, quality of the oil or gas, and prevailing supply and demand conditions. As a result, the price of the oil, gas and NGL fluctuates to remain competitive with other available oil, gas and NGL supplies in the market. The Company believes that the pricing provisions of our oil, gas and NGL contracts are customary in the industry. Oil sales The Company's oil sales contracts are generally structured such that it sells its oil production to a purchaser at a contractually specified delivery point at or near the wellhead. The crude oil production is priced on the delivery date based upon prevailing index prices less certain deductions related to oil quality, physical location and transportation costs incurred by the purchaser subsequent to delivery. The Company recognizes revenue when control transfers to the purchaser upon delivery at or near the wellhead at the net price received from the purchaser. Payment terms as customarily and normally paid on the twentieth Gas and NGL Sales Under the Company's gas processing contracts, it delivers wet gas to a midstream processing entity at the wellhead or the inlet of the midstream processing entity’s system. There are no third In these scenarios, the Company evaluates whether it is the principal or the agent in the transaction. With respect to the Company's gas purchase contracts, the Company has concluded that it is the agent, and thus, the midstream processing entity is its customer. Accordingly, the Company recognizes revenue upon delivery to the midstream processing entity based on the net amount of the proceeds received from the midstream processing entity. Imbalances The Company had no December 31, 2019 2020. Disaggregation of Revenue The Company is focused on the development of oil and natural gas properties primarily located in the following three Years Ended December 31, 2019 2020 Oil Gas NGL Oil Gas NGL Operating Region Permian/Delaware Basin $ 52,789 $ 494 $ 602 $ 22,891 $ 335 $ 163 Rocky Mountain $ 68,555 $ 1,480 $ 1,305 $ 19,078 $ 251 $ 266 South Texas $ 3,159 $ 605 $ 3 $ - $ - $ - Significant Judgments Principal versus agent The Company engages in various types of transactions in which midstream entities process the Company's gas and subsequently market resulting NGL and residue gas to third Transaction price allocated to remaining performance obligations A significant number of the Company's product sales are short-term in nature with a contract term of one 606 10 50 14 one For product sales that have a contract term greater than one 606 10 50 14 not not Contract balances Under the Company's product sales contracts, the Company is entitled to payment from purchasers once its performance obligations have been satisfied upon delivery of the product, at which point payment is unconditional. The Company records invoiced amounts as “Accounts receivable - Oil and gas production sales” in the accompanying condensed consolidated balance sheet. To the extent actual volumes and prices of oil and natural gas are unavailable for a given reporting period because of timing or information not third not 2014 09. December 31, 2019 December 31, 2020 Prior-period performance obligations The Company records revenue in the month production is delivered to the purchaser. However, settlement statements for certain gas and NGL sales may not 30 60 not third The Company records the differences between its estimates and the actual amounts received for product sales in the month that payment is received from the purchaser. Any identified differences between its revenue estimates and actual revenue received historically have not December 31, 2020 not

Note 3 - Reverse Stock Split

Note 3 - Reverse Stock Split	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Reverse Stock Split [Text Block]	3. On October 19, 2020 1 September 29, 2020. no not September 30, 2020 December 31, 2019. Additionally on the effective date of the Reverse Stock Split, all options, warrants and other convertible securities of the Company outstanding immediately prior to the Reverse Stock Split were adjusted by dividing the number of shares of common stock into which the options, warrants and other convertible securities are exercisable or convertible by 20, 20,

Note 4 - Long-term Debt

Note 4 - Long-term Debt	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Long-term Debt [Text Block]	4. The following sections regarding the First Lien Credit Facility and Second Lien Credit Facility are qualified in their entirety by the disclosure contained in Note 1. December 31, 2020, The following is a description of the Company’s debt as of December 31, 2019 2020 Years Ended December 31, 2019 2020 (In thousands) First Lien Credit Facility $ 95,778 $ 95,000 Second Lien Credit Facility 100,000 112,695 Exit fee - Second Lien Credit Facility - 10,000 Real estate lien note 3,091 2,810 198,869 220,505 Less current maturities (280 ) (202,751 ) 198,589 17,754 Deferred financing fees and debt issuance cost - net (5,871 ) (15,239 ) Total long-term debt, net of deferred financing fees and debt issuance costs $ 192,718 $ 2,515 Maturities of long-term debt are as follows: Years ending December 31, (In thousands) 2021 $ 217,990 2022 310 2023 2,205 2024 - 2025 - Thereafter - Total $ 220,505 First Lien Credit Facility The Company has a senior secured First Lien Credit Facility with Société Générale, as administrative agent and issuing lender, and certain other lenders. As of December 31, 2020 Outstanding amounts under the First Lien Credit Facility accrue interest at a rate per annum equal to (a)(i) for borrowings that we elect to accrue interest at the reference rate at the greater of ( x one December 31, 2020, Subject to earlier termination rights and events of default, the stated maturity date of the First Lien Credit Facility is May 16, 2022. not Each of the Company's subsidiaries has guaranteed our obligations under the First Lien Credit Facility on a senior secured basis. Obligations under the First Lien Credit Facility are secured by a first December 30, 2020, 9 9 Under the amended First Lien Credit Facility, the Company is subject to customary covenants, including financial covenants and reporting covenants. The amendment to the First Lien Credit Facility dated June 25, 2020 ( "1L six no six first not 1.00 first 15 9 15 20% 1.00 December 31, 2020, 1.00 four four June 30, 2020 1, 2 3 June 30, 2020, September 30, 2020 December 31, 2020, 1 first 1.00, 2 first 3 4 no 5 60 90 may four four June 30, 2020, four September 30, 2020, four December 31, 2020, March 31, 2021 December 31, 2021 1L Table of Contents The First Lien Credit Facility contains a number of covenants that, among other things, restrict our ability to: • incur or guarantee additional indebtedness; • transfer or sell assets; • pay dividends or make other distributions on capital stock or make other restricted payments; • engage in transactions with affiliates other than on an "arm's length" basis; • make any change in the principal nature of our business; and • permit a change in control The First Lien Credit Facility also contains customary events of default, including nonpayment of principal or interest, violations of covenants, cross default and cross acceleration to certain other indebtedness, bankruptcy and material judgments and liabilities. As of December 31, 2020 not Second Lien Credit Facility On November 13, 2019, June 25, 2020. November 13, 2019, December 31, 2020, The stated maturity date of the Second Lien Credit Facility is November 13, 2022. three Each of our subsidiaries has guaranteed our obligations under the Second Lien Credit Facility. Obligations under the Second Lien Credit Facility are secured by a first December 31, 2020, 9 9 Table of Contents Under the amended Second Lien Credit Facility, the Company is subject to customary covenants, including financial covenants and reporting covenants. The amendment to the Second Lien Credit Facility dated June 25, 2020 ( "2L 200bps 500bps 15 9 15 20% not 1.00 September 30, 2021 December 31, 2021, 1.00 first September 30, 2021; ( 60 90 may four four June 30, 2020, four September 30, 2020, March 31, 2021 December 31, 2021 The Second Lien Credit Facility contains a number of covenants that, among other things, restrict our ability to: ● incur or guarantee additional indebtedness; ● transfer or sell assets; ● create liens on assets; ● pay dividends or make other distributions on capital stock or make other restricted payments; ● engage in transactions with affiliates other than on an “arm’s length” basis; ● make any change in the principal nature of our business; and ● permit a change of control The Second Lien Credit Facility also contains customary events of default, including nonpayment of principal or interest, violation of covenants, cross default and cross acceleration to certain other indebtedness, bankruptcy and material judgments and liabilities. Events of default have occurred, or are reasonably likely to occur, under the Second Lien Credit Facility as a result of (i) our failure to timely deliver audited financial statements without a “going concern” or like qualification for the fiscal year ended December 31, 2020, ( may On April 16, 2021, The Notice of Default describes certain events of default that occurred under the Second Lien Credit Facility as a result of (i) our failure to file timely our Form 10 December 31, 2020, ( December 31, 2020, The Notice of Default declares that our obligations under the Second Lien Credit Facility are immediately due and payable, in each case without presentment, demand, protest or other requirements of any kind, and have begun to bear interest at the rate applicable to such amount under the Second Lien Credit Facility, plus an additional 3%. Additionally, the administrative agent and the lenders have reserved their right to exercise further rights, powers and remedies under the Second Lien Credit Facility, at any time or from time to time, with respect to any of the events of default described above. Angelo Gordon has agreed to forbear from exercising remedies available to it until May 6, 2021. In connection with the amendment to the Second Lien Credit Facility on June 25, 2020, August 11, 2020 October 19, 2020, 1 may five 2L August 11, 2020, 2L ASC 470: Real Estate Lien Note We have a real estate lien note secured by a first July 20, 2023. December 31, 2019 2020

Note 5 - Property and Equipment

Note 5 - Property and Equipment	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Property, Plant and Equipment Disclosure [Text Block]	5. The major components of property and equipment, at cost, are as follows: Estimated December 31, Useful life 2019 2020 Years (In thousands) Oil and gas properties (1) - $ 1,162,094 $ 1,167,333 Equipment and other 3-39 15,187 15,348 Drilling rig 15 24,108 24,108 1,201,389 1,206,789 Accumulated depreciation, depletion, amortization and impairment (872,431 ) (1,083,843 ) Net Property and Equipment $ 328,958 $ 122,946 ( 1

Note 6 - Stock-based Compensati

Note 6 - Stock-based Compensation and Option Plans	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Share-based Payment Arrangement [Text Block]	6. The Company’s Amended and Restated 2005 may not may 1 one 2 3 4 Stock Options The Company grants options to its officers, directors, and other employees under various stock option and incentive plans. There were no 2019 2020 The following table is a summary of the Company’s stock option activity for the three December 31: Options Weighted average Weighted average Intrinsic value (000s) exercise price remaining life per share Options outstanding December 31, 2018 378 $ 47.35 Granted - - Exercised (23 ) 19.63 Forfeited/Expired (58 ) 48.02 Options outstanding December 31, 2019 297 $ 49.41 Granted - - Exercised - - Forfeited/Expired (101 ) 48.96 Options outstanding December 31, 2020 196 49.69 3.8 $ 0.00 Exercisable at end of year 192 49.64 3.9 $ 0.00 Other information pertaining to the Company’s stock option activity for the three December 31: 2019 2020 Weighted average grant date fair value of stock options granted (per share) $ - $ - Total fair value of options vested (000's) $ 732 $ 275 Total intrinsic value of options exercised (000's) $ 141 $ - As of December 31, 2020 not 2021 2022. December 31, 2019 2020 The following table represents the range of stock option prices and the weighted average remaining life of outstanding options as of December 31, 2020 Outstanding Options Exercisable Weighted Weighted Weighted Weighted average average average average Number remaining exercise Number remaining exercise Range of stock option prices Outstanding life price Outstanding life price 19.40-29.99 66,025 4.9 $ 20.02 66,025 4.9 $ 20.02 30.00-39.99 5,350 6.4 $ 37.47 5,263 6.4 $ 34.46 40.00-49.99 19,459 2.2 $ 47.73 19,447 2.2 $ 47.73 50.00-59.99 13,900 6.0 $ 55.81 11,400 5.7 $ 56.33 60.00-69.99 52,646 3.8 $ 63.14 52,646 3.8 $ 63.14 70.00-79.99 19,075 1.8 $ 73.22 19,075 1.8 $ 73.22 80.00-89.99 3,650 2.9 $ 84.15 3,650 2.9 $ 84.14 90.00-99.99 12,625 1.8 $ 93.38 12,625 1.8 $ 93.38 100.00-125.60 2,450 3.3 $ 107.97 2,450 3.3 $ 17.97 195,180 3.9 $ 49.69 192,581 3.8 $ 49.64 Restricted Stock Awards Restricted stock awards are awards of common stock that are subject to restrictions on transfer and to a risk of forfeiture if the awardee terminates employment with the Company prior to the lapse of the restrictions. The value of such stock is determined using the market price on the grant date. Compensation expense is recorded over the applicable restricted stock vesting periods. As of December 31, 2020 not 2020 2022. December 31, 2019 2020 The following table is a summary of the Company’s restricted stock activity for the three December 31, 2020 Number of Shares Weighted average grant date fair value Unvested December 31, 2018 42 $ 43.07 Granted 66 26.75 Vested/Released (14 ) 42.98 Forfeited/Expired (5 ) 30.71 Unvested December 31, 2019 89 $ 31.67 Granted - - Vested/Released (33 ) 32.11 Forfeited/Expired (15 ) 31.52 Unvested December 31, 2020 41 $ 31.37 Performance Based Restricted Stock Awards Effective on April 1, 2018, 2005 2021 three The table below provides a summary of Performance Based Restricted Stock as of the date indicated (shares in thousands): Number of Shares Weighted average grant date fair value Unvested December 31, 2018 20 47.40 Granted 40 26.80 Vested/Released - - Forfeited (3 ) 30.38 Unvested December 31, 2019 57 $ 33.86 Granted - - Vested/Released - - Forfeited (13 ) 34.29 Unvested December 31, 2020 44 $ 33.73 Compensation expense associated with the performance based restricted stock is based on the grant date fair value of a single share as determined using a Monte Carlo Simulation model which utilizes a stochastic process to create a range of potential future outcomes given a variety of inputs. As the Compensation Committee intends to settle the performance based restricted stock awards with shares of the Company's common stock, the awards are accounted for as equity awards and the expense is calculated on the grant date assuming a 100% target payout and amortized over the life of the awards. As of December 31, 2020 not 2020 2022. December 31, 2019 2020, Director Stock Awards The 2005 2005 first not 2020. The maximum annual award for any one no Warrants for Common Stock As of December 31, 2020, Issuance Date Exercisable for Expiration Date Exercise Price Number of Shares August 11, 2020 Common Stock August 11, 2025 $ 0.20 1,672,290 In connection with the amended Second Lien Credit Agreement, on August 11, 2020, October 19, 2020 1 may five At December 31, 2020

Note 7 - Income Taxes

Note 7 - Income Taxes	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Income Tax Disclosure [Text Block]	7. The Company has determined that a revision was required to correct the December 31, 2019 no 2019 Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Significant components of the Company’s deferred tax liabilities and assets are as follows: As of December 31, 2019 2020 (In thousands) Deferred tax liabilities: Hedge contracts $ - $ 4,299 Other 3,158 2,137 Total deferred tax liabilities 3,158 6,436 Deferred tax assets: US full cost pool $ 9,595 35,500 Depletion carryforward 3,722 461 U.S. net operating loss carryforward 68,250 84,927 Alternative minimum tax credit 6 - Hedge contracts 1,661 - Interest disallowed - 2,818 Total deferred tax assets 83,234 123,706 Valuation allowance for deferred tax assets (80,076 ) (117,270 ) Net deferred tax assets 3,158 6,436 Net deferred tax $ - $ - Significant components of the provision (benefit) for income taxes are as follows: Years Ended December 31, 2019 2020 (In thousands) Current: Federal $ - $ - State - - $ - $ - Deferred: Federal $ - $ - $ - $ - At December 31, 2020 $245.20 2018 2017 2018 2022 2037, not 100% 2018, 2019 2020 five 100% January 1, 2021 80% December 31, 2020. January 1, 2021, 80% no January 1, 2018). The use of our NOLs will be limited if there is an "ownership change" in our common stock, generally a cumulative ownership change exceeding 50% three 382 December 31, 2020 not 382. December 31, 2019 December 31, 2020 The reconciliation of income tax computed at the U.S. federal statutory tax rates to income tax expense is: Years Ended December 31, 2019 2020 (in thousands) Tax benefit at U.S. Statutory rates $ 13,651 $ 38,749 Change in deferred tax asset valuation allowance (12,767 ) (37,193 ) Alternative minimum tax expense (745 ) - Expired capital loss carryover (3,966 ) - Permanent differences (403 ) (276 ) Return to provision estimated revision 341 (3,069 ) State income taxes, net of federal effect 3,892 1,789 Other (3 ) - $ - $ - As of December 31, 2019 2020 not 2014 2020 New tax legislation, commonly referred to as the Tax Cuts and Jobs Act (H.R. 1 December 22, 2017. not may 30% 2019 2020, 50% 2017 80% 2017, 100% not may

Note 8 - Commitments and Contin

Note 8 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	8. Litigation and Contingencies From time to time, the Company is involved in litigation relating to claims arising out of its operations in the normal course of business. At December 31, 2020 not

Note 9 - Earnings Per Share

Note 9 - Earnings Per Share	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Earnings Per Share [Text Block]	9. The following table sets forth the computation of basic and diluted earnings per share: Years Ended December 31, 2019 2020 Numerator: Net (loss) $ (65,004 ) $ (184,522 ) Denominator for basic earnings per share - weighted-average common shares outstanding 8,312 8,382 Effect of dilutive securities: Stock options, restricted shares and performance based shares 3 - Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and performance based shares 8,315 8,382 Net (loss) per common share - basic $ (7.82 ) $ (22.01 ) Net (loss) per common share - diluted $ (7.82 ) $ (22.01 ) Basic earnings per share, excluding any dilutive effects of stock options and unvested restricted stock, is computed by dividing net income (loss) available to common stockholders by the weighted average number of common shares outstanding for the period. Diluted income (loss) per share is computed similar to basic; however diluted income (loss) per share reflects the assumed conversion of all potentially dilutive securities. For the year ended December 31, 2019, four thousand

Note 10 - Benefit Plans

Note 10 - Benefit Plans	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Compensation and Employee Benefit Plans [Text Block]	10. The Company has a defined contribution plan ( 401 2019 2020 first may 2019 50 50 2020 50 50

Note 11 - Hedging Program and D

Note 11 - Hedging Program and Derivatives	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Derivative Instruments and Hedging Activities Disclosure [Text Block]	11. Hedging Program and Derivatives The derivative instruments we utilize are based on index prices that may not 815; no no The following table sets forth the summary position of our derivative contracts as of December 31, 2020 Oil - WTI Contract Periods Daily Volume (Bbl) Swap Price (per Bbl) Fixed Swaps January - December 2021 2,889 $ 57.62 January - December 2022 2,412 $ 50.60 January - December 2023 1,498 $ 50.60 January - December 2024 1,585 $ 50.60 The following table illustrates the impact of derivative contracts on the Company’s balance sheet: Fair Value Derivative Contracts as of December 31, 2019 Asset Derivatives Liability Derivatives Derivatives not designated as hedging instruments Balance Sheet Location Fair Value Balance Sheet Location Fair Value Commodity price derivatives Derivatives - current $ 83 Derivatives - current $ 10,688 Commodity price derivatives Derivatives - long-term 4,170 Derivatives - long-term 999 $ 4,253 $ 11,687 Fair Value Derivative Contracts as of December 31, 2020 Asset Derivatives Liability Derivatives Derivatives not designated as hedging instruments Balance Sheet Location Fair Value Balance Sheet Location Fair Value Commodity price derivatives Derivatives - current $ 9,639 Derivatives - current $ 480 Commodity price derivatives Derivatives - long-term 10,281 Derivatives - long-term - $ 19,920 $ 480 Gains and losses from derivative activities are reflected as “Loss (gain) on derivative contracts” in the accompanying Consolidated Statements of Operations. The net estimated value of our commodity derivative contracts was an asset of approximately $19.4 million as of December 31, 2020 December 31, 2020 December 31, 2019

Note 12 - Financial Instruments

Note 12 - Financial Instruments	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Fair Value Disclosures [Text Block]	12. There is a three one three three • Level 1 • Level 2 • Level 3 A financial instrument’s categorization within the valuation hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. The Company is further required to assess the creditworthiness of the counter-party to the derivative contract. The results of the assessment of non-performance risk, based on the counter-party’s credit risk, could result in an adjustment of the carrying value of the derivative instrument. The following tables sets forth information about the Company’s assets and liabilities measured at fair value on a recurring basis as of December 31, 2019 2020 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Balance as of December 31, 2019 Assets: NYMEX fixed price derivative contracts $ - $ 4,253 $ - $ 4,253 NYMEX basis differential swap - - - - Total Assets $ - $ 4,253 $ - $ 4,253 Liabilities: NYMEX fixed price derivative contracts $ - $ 5,583 $ - $ 5,583 NYMEX basis differential swap - - 6,104 6,104 Total Liabilities $ - $ 5,583 $ 6,104 $ 11,687 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Balance as of December 31, 2020 Assets: NYMEX fixed price derivative contracts $ - $ 19,920 $ - $ 19,920 Total Assets $ - $ 19,920 $ - $ 19,920 Liabilities: NYMEX fixed price derivative contracts $ - $ 480 $ - $ 480 Total Liabilities $ - $ 480 $ - $ 480 The Company’s derivative contracts at December 31, 2020 December 31, 2019 2. third third not 3. Additional information for the Company's recurring fair value measurements using significant unobservable inputs (Level 3 December 31, 2020 (In thousands) Fair value at January 1, 2020 $ (6,104 ) Changes in market value 4,577 Settlements during the period 1,527 Fair value at December 31, 2020 $ - There were no 3 2020 Nonrecurring Fair Value Measurements Non-financial assets and liabilities measured at fair value on a nonrecurring basis included certain non-financial assets and liabilities as may The asset retirement obligation estimates are derived from historical costs as well as management’s expectation of future cost environments. As there is no 3. 1. Other Financial Instruments The carrying amounts of our cash, cash equivalents, restricted cash, accounts receivable and accounts payable approximate fair value because of the short-term maturities and/or liquid nature of these assets and liabilities. The carrying value of our debt approximates fair value as the interest rates are market rates and this debt is considered Level 2.

Note 13 - Lease Accounting Stan

Note 13 - Lease Accounting Standard	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Lessee, Operating Leases [Text Block]	13. Nature of Leases We lease certain real estate, field equipment and other equipment under cancelable and non-cancelable leases to support our operations. A more detailed description of our significant lease types is included below. Real Estate Leases We rent a residence in North Dakota from a third five August 31, 2024. not Field Equipment We rent compressors and coolers from third one thirty not twelve not third thirty not Discount Rate Our leases typically do not Practical Expedients and Accounting Policy Elections Certain of our lease agreements include lease and non-lease components. For all existing asset classes with multiple component types, we have utilized the practical expedient that exempts us from separating lease components from non-lease components. Accordingly, we account for the lease and non-lease components in an arrangement as a single lease component. In addition, for all of our existing asset classes, we have made an accounting policy election not 12 not not None The components of our total lease expense for the years ended December 31,2019 December 31, 2020 For the Year Ended December 31, 2019 2020 (in thousands) Operating lease cost $ 478 $ 114 Short-term lease expense (1) 1,992 2,183 Total lease expense $ 2,470 $ 2,297 Short-term lease costs (2) $ 4,900 $ 973 ( 1 Short-term lease expense represents expense related to leases with a contract term of 12 ( 2 These short-term lease costs are related to leases with a contract term of 12 Supplemental balance sheet information related to our operating leases is included in the table below: For the Year Ended December 31, 2019 2020 (in thousands) Operating lease Right of Use asset $ 327 $ 228 Operating lease liability - current $ 98 $ 53 Operating lease liabilities - long-term $ 203 $ 150 Our weighted average remaining lease term and weighted average discount rate for our operating leases are as follows: For the Year Ended December 31, 2019 2020 (in thousands) Weighted Average Remaining Lease Term (in years) 8.66 10.68 Weighted Average Discount Rate 6 % 6 % Our lease liabilities with enforceable contract terms that are greater than one Operating Leases (in thousands) 2021 $ 63 2022 48 2023 41 2024 28 2025 4 Thereafter 98 Total lease payments 282 Less imputed interest (79 ) Total lease liability $ 203 Supplemental cash flow information related to our operating leases is included in the table below: For the Year Ended December 31, 2019 2020 (in thousands) Cash paid for amounts included in the measurement of lease liabilities $ 478 $ 114 Right of Use assets added in exchange for lease obligations (since adoption) $ 770 $ 125

Note 14 - Subsequent Events

Note 14 - Subsequent Events	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Subsequent Events [Text Block]	14. Paycheck Protection Program Loan On May 4, 2020, 1.0% two seventeen first seven eight 75% 19 not January 2021. first 2021. In connection with the completion of our financial statements for the year ended December 31, 2020, December 31, 2020 not first December 31, 2020. First Lien Credit Facility Events of default have occurred, or are reasonably likely to occur, under the First Lien Credit Facility as a result of (i) the Company's failure to timely deliver audited financial statements without a “going concern” or like qualification for the fiscal year ended December 31, 2020, ( first December 31, 2020, ( may Second Lien Credit Facility Events of default have occurred, or are reasonably likely to occur, under the Second Lien Credit Facility as a result of (i) the Company's failure to timely deliver audited financial statements without a “going concern” or like qualification for the fiscal year ended December 31, 2020, ( may On April 16, 2021, The Notice of Default describes certain events of default that occurred under the Second Lien Credit Facility as a result of (i) our failure to file timely our Form 10 December 31, 2020, ( December 31, 2020, The Notice of Default declares that our obligations under the Second Lien Credit Facility are immediately due and payable, in each case without presentment, demand, protest or other requirements of any kind, and have begun to bear interest at the rate applicable to such amount under the Second Lien Credit Facility, plus an additional 3%. Additionally, the administrative agent and the lenders have reserved their right to exercise further rights, powers and remedies under the Second Lien Credit Facility, at any time or from time to time, with respect to any of the events of default described above. Angelo Gordon has agreed to forbear from exercising remedies available to it until May 6, 2021. Hedging Contracts Effective April 12, 2021, April 15 April 30, 2021. 6.7% may may may Forbearance Discussions The existing events of default under the credit facilities are subject to forbearance agreements with our lenders that currently expire on May 6, 2021, no No

Note 15 - Quarterly Results of

Note 15 - Quarterly Results of Operations (Unaudited)	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Quarterly Financial Information [Text Block]	15. Selected results of operations for each of the fiscal quarters during the years ended December 31, 2019 2020 1st 2nd 3rd 4th Quarter Quarter Quarter Quarter (In thousands, except per share data) Year Ended December 31, 2019 Net revenue $ 34,514 $ 34,820 $ 31,536 $ 28,276 Operating income (loss) $ 6,708 $ 8,935 $ 8,053 $ (49,412 ) Net income (loss) $ (25,455 ) $ 11,678 $ 17,041 $ (68,268 ) Net income (loss) per common share - basic $ (3.00 ) $ 1.40 $ 2.00 $ (8.20 ) Net income (loss) per common share - diluted $ (3.00 ) $ 1.40 $ 2.00 $ (8.20 ) Year Ended December 31, 2020 Net revenue $ 15,726 $ 1,993 $ 12,595 $ 12,729 Operating income (loss) $ (29,781 ) $ (61,474 ) $ (56,661 ) $ (51,502 ) Net income (loss) $ 41,443 $ (83,256 ) $ (73,615 ) $ (69,094 ) Net income (loss) per common share - basic $ 4.80 $ (10.00 ) $ (8.80 ) $ (8.21 ) Net income (loss) per common share - diluted $ 4.80 $ (10.00 ) $ (8.80 ) $ (8.21 )

Note 16 - Supplemental Oil and

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	16. The accompanying tables present information concerning the Company’s oil and gas producing activities “Disclosures about Oil and Gas Producing Activities.” Capitalized costs relating to oil and gas producing activities are as follows as of December 31: Years Ended December 31, (in thousands) 2019 2020 Proved oil and gas properties $ 1,162,094 $ 1,167,333 Unproved properties - - Total 1,162,094 1,167,333 Accumulated depreciation, depletion, amortization and impairment (851,107 ) (1,060,649 ) Net capitalized costs $ 310,987 $ 106,684 Cost incurred in oil and gas property acquisition and development activities were as follows for the years ended December 31 ( 2019 2020 Development costs $ 92,884 $ 5,238 Exploration costs - - Property acquisition costs - - $ 92,884 $ 5,238 Results of operations from oil and gas producing activities were as follows for the years ended December 31: 2019 2020 Revenues $ 128,992 $ 42,984 Production costs (38,229 ) (21,090 ) Depreciation, depletion and amortization (51,041 ) (22,679 ) Accretion of future site restoration (436 ) (414 ) Proved property impairment (51,293 ) (186,980 ) Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs) $ (12,007 ) $ (188,179 ) Depletion rate per barrel of oil equivalent $ 14.12 $ 12.59 Estimated Quantities of Proved Oil and Gas Reserves Reserve estimates are inherently imprecise and estimates of new discoveries are more imprecise than those of producing oil and gas properties. Accordingly, the estimates are expected to change as future information becomes available. The estimates have been predominately prepared by independent petroleum reserve engineers. Proved oil and gas reserves are the estimated quantities of oil and gas that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed oil and gas reserves are those expected to be recovered through existing wells with existing equipment and operating methods. All of the Company’s proved reserves are located in the continental United States. Proved reserves were estimated in accordance with guidelines established by the SEC and the FASB, which require that reserve estimates be prepared under existing economic and operating conditions with no 12 first The following set forth changes in estimated net proved reserves for the years ended December 31, 2019 2020 Oil Oil NGL Gas Equivalents (MBbl) (MBbl) (MMcf) (Mboe) Change in Proved Reserves Balance at December 31, 2018 42,237 10,034 89,744 67,228 Revisions of previous estimates (15,616 ) (2,713 ) (23,178 ) (22,192 ) Extensions and discoveries 13,477 2,285 14,073 18,109 Purchases of minerals in place - - - - Sales of minerals in place (1,431 ) (86 ) (9,898 ) (3,167 ) Production (2,388 ) (548 ) (4,076 ) (3,616 ) Balance at December 31, 2019 36,279 8,972 66,665 56,362 Revisions of previous estimates (16,922 ) (3,549 ) (27,921 ) (25,125 ) Extensions and discoveries - - - - Removal of PUDs (8,687 ) (1,922 ) (12,291 ) (12,658 ) Production (1,132 ) (313 ) (2,135 ) (1,801 ) Balance at December 31, 2020 9,538 3,188 24,318 16,778 The following is a summary of the changes to the Company’s proved reserves that occurred during 2020: Revisions to prior estimates There was a decrease of 56 MBoe of net reserves attributable to changes in projections for the Company’s producing wells based on actual performance during 2020. The Company converted 29 A1 25 3rd 2020 five nine 2020 two 2020 no five Extensions, discoveries and other additions The Company did not 2020 Purchases: The Company did not 2020. Sales: The Company did not 2020. Production: The Company produced 1,801 MBoe of net proved reserves during 2020. The following is a summary of the changes to the Company’s proved reserves that occurred during 2019: Revisions to prior estimates There was a decrease of 8,790 MBoe of net reserves attributable to changes in projections for the Company’s producing wells based on actual performance during 2019. eight A1 twenty-four A2 one 3rd two 2019 no five Extensions, discoveries and other additions The Company added two new proved undeveloped Wolfcamp A locations, and nine 3rd eighteen A1 twenty-four 3rd one 2019 Purchases: The Company did not 2019. Sales: The Company sold all its holdings in the Gulf Coast Area accounting for 1,839 MBoe of net proved reserves. The Company sold fourteen producing non-operated Permian locations in Marion, Pecos, and Reeves Counties, Texas, accounting for 42 MBoe of net reserves. The Company sold substantially all its holdings in the non-operated Bakken Area accounting for 1,268 MBoe of net proved reserves. Other miscellaneous asset sales during the year accounted for 18 MBoe of net reserves. Production: The Company produced 3,616 MBoe of net reserves during 2019. The following table presents the Company's estimate of its net proved developed and undeveloped oil and gas reserves as of December 31, 2019 2020 Total Oil Oil NGL Gas Equivalents (MBbl) (MBbl) (MMcf) (Mboe) Proved Developed Reserves: December 31, 2019 10,964 2,699 21,439 17,237 December 31, 2020 9,538 3,187 24,318 16,778 Proved Undeveloped Reserves: December 31, 2019 25,315 6,273 45,226 39,125 December 31, 2020 - - - - Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The Company’s proved oil and gas reserves have been estimated by the independent petroleum engineering firm, DeGolyer & MacNaughton, assisted by the engineering and operations departments of the Company as of December 31, 2019 December 31, 2020 12 first No. 2010 03, 932 not 2019 2020 The technical personnel responsible for preparing the reserve estimates at DeGolyer & MacNaughton meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. DeGolyer & MacNaughton is an independent firm of petroleum engineers, geologists, geophysicists, and petrophysicists; they do not not February 12, 2021, 99.1 Estimates of proved reserves at December 31, 2019 2020 42 The projections should not not Future net cash inflows after income taxes were discounted using a 10% December 31, 2019 2020 Years Ended December 31, (in thousands) 2019 2020 Future cash inflows $ 1,890,579 $ 345,869 Future production costs (598,714 ) (166,781 ) Future development costs (544,111 ) (6,291 ) Future income tax expense - - Future net cash flows 747,754 172,797 Discount $ (440,142 ) $ (66,113 ) Standardized Measure of discounted future net cash relating to proved reserves $ 307,612 $ 106,684 Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The following is an analysis of the changes in the Standardized Measure for the periods indicated (in thousands): Years Ended December 31, (in thousands) 2019 2020 Standardized Measure, beginning of year $ 651,884 $ 307,612 Sales and transfers of oil and gas produced, net of production costs (90,763 ) (21,894 ) Net change in prices and development and production costs from prior year (218,092 ) (96,688 ) Extensions, discoveries, and improved recovery, less related costs 98,780 - Sales of minerals in place (17,276 ) - Removal of PUDs - (80,416 ) Revisions of previous estimates (227,477 ) (159,613 ) Change in timing and other (13,744 ) 126,922 Change in future income tax expense 59,112 - Accretion of discount 65,188 30,761 Standardized Measure, end of year $ 307,612 $ 106,684 The standardized measure is based on the following oil and gas prices over the life of the properties as of the following dates: Years Ended December 31, 2019 2020 Oil (per Bbl) (1) $ 55.73 $ 39.54 Gas (per Mmbtu) (2) $ 2.54 $ 2.03 Oil (per Bbl) (3) $ 52.14 $ 37.05 Gas (per Mmbtu) (4) $ 0.63 $ 0.27 NGL's (per Bbl) (5) $ 3.48 $ 1.37 _____________________ ( 1 The quoted oil price for the year ended December 31 2019 2020 12 first 2019 2020 ( 2 The quoted gas price for the year ended December 31, 2019 2020 12 first 2019 2020 ( 3 The oil price is the realized price at the wellhead as of December 31 ( 4 The gas price is the realized price at the wellhead as of December 31 ( 5 The NGL price is the realized price as of December 31

Significant Accounting Policies

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Consolidation, Policy [Policy Text Block]	Nature of Operations We are an independent energy company primarily engaged in the acquisition, exploitation, development and production of oil and gas in the United States. Our oil and gas assets are located primarily in two The terms “Abraxas,” “Abraxas Petroleum,” “we,” “us,” “our” or the “Company” refer to Abraxas Petroleum Corporation and all of its subsidiaries, including Raven Drilling LLC (“Raven Drilling”).
Going Concern Qualification, Policy [Policy Text Block]	Going Concern Our present level of indebtedness and the recent commodity price environment present challenges to our ability to comply with certain covenants in our credit facilities and under applicable auditing standards the independent accountants' opinion on our financial statements for the year ended December 31, 2020 December 31, 2020 April 30, 2021, Specifically, with regard to our credit agreements, we did not first December 31, 2020 not 4 first September 30, 2021, twelve December 31, 2020 not We are evaluating the available financial alternatives and are in discussion with our lenders seeking additional waivers or amendments to the covenants or other provisions of our credit facilities to address any current and future default relating to the covenants in question. The existing defaults at March 31, 2021 May 6, 2021. No may not Under applicable accounting principles these circumstances are deemed to create substantial doubt regarding the Company's ability to continue as a "going concern". The consolidated financial statements have been prepared on a "going concern" basis, which contemplates the realization of assets and the satisfaction of liabilities and other commitments in the normal course of business for the twelve not may In April 2021, April 15 April 30, 2021. may may 14
Rig Accounting [Policy Text Block]	Rig Accounting In accordance with SEC Regulation S- X, no not 2019 2020
Use of Estimates, Policy [Policy Text Block]	Use of Estimates The consolidated financial statements of the Company have been prepared by management in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The most significant estimates pertain to proved oil, gas and NGL reserves and related cash flow estimates used in impairment tests of oil and gas properties, the fair value of assets and liabilities acquired in business combinations, derivative contracts, the provision for income taxes including uncertain tax positions, stock based compensation, asset retirement obligations, accrued oil and gas revenues and expenses, as well as estimates of expenses related to depreciation, depletion, amortization and accretion. Actual results could differ from those estimates. The process of estimating oil and gas reserves in accordance with SEC requirements is complex and involves decisions and assumptions in evaluating the available geological, geophysical, engineering and economic data. Accordingly, these estimates are imprecise. Actual future production, oil and gas prices, differentials, revenues, taxes, capital expenditures, operating expenses and quantities of recoverable oil and gas reserves most likely will vary from those estimated. Any significant variance could materially affect the estimated quantities and present value of our reserves. In addition, we may
Reclassification, Comparability Adjustment [Policy Text Block]	Reclassifications Certain reclassifications have been made to the prior year financial statements to conform to the current period presentation. These reclassifications were to share and per share data related to the 1 October 19, 2020 no
Concentration Risk, Credit Risk, Policy [Policy Text Block]	Concentration of Credit Risk Financial instruments which potentially expose the Company to credit risk consist principally of trade receivables and derivative contracts. Accounts receivable are generally from companies with significant oil and gas marketing or operating activities. The Company performs ongoing credit evaluations and, generally, requires no The Company maintains any cash and cash equivalents in excess of federally insured limits in prominent financial institutions considered by the Company to be of high credit quality.
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand deposits and short-term investments with original maturities of three
Accounts Receivable [Policy Text Block]	Accounts Receivable Accounts receivable are reported net of an allowance for doubtful accounts of approximately $0.1 million at December 31, 2019 2020
Segment Reporting, Policy [Policy Text Block]	Industry Segment and Geographic Information The Company operates in one no
Full Cost Method Using Gross Revenue Method, Policy [Policy Text Block]	Oil and Gas Properties The Company follows the full cost method of accounting for oil and gas properties. Under this method, certain direct costs and indirect costs associated with acquisition of properties and successful as well as unsuccessful exploration and development activities are capitalized. Depreciation, depletion, and amortization of capitalized oil and gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method based on proved reserves. Net capitalized costs of oil and gas properties, less related deferred taxes, are limited by country, to the lower of unamortized cost or the cost ceiling, defined as the sum of the present value of estimated future net revenues from proved reserves based on unescalated prices discounted at 10%, plus the cost of properties not No not December 31, 2019 2020
Property, Plant and Equipment, Policy [Policy Text Block]	Other Property and Equipment Other property and equipment are recorded at cost. Depreciation of other property and equipment is provided over the estimated useful lives using the straight-line method. Major renewals and improvements are recorded as additions to the property and equipment accounts. Repairs that do not
Estimate of Proved Oil and Gas Reserves Policy [Policy Text Block]	Estimates of Proved Oil and Gas Reserves Estimates of our proved reserves included in this report are prepared in accordance with GAAP and SEC guidelines. The accuracy of a reserve estimate is a function of: • the quality and quantity of available data; • the interpretation of that data; • the accuracy of various mandated economic assumptions; and • the judgment of the persons preparing the estimate. Our proved reserve information included in this report was based on studies performed by our independent petroleum engineers assisted by the engineering and operations departments of Abraxas. Estimates prepared by other third may may may In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the average of oil and gas prices based on the unweighted average 12 first may The estimates of proved reserves materially impact depreciation, depletion and amortization, or DD&A expense. If the estimates of proved reserves decline, the rate at which we record DD&A expense will increase, reducing future net income. Such a decline may may
Derivatives, Policy [Policy Text Block]	Derivative Instruments and Hedging Activities The Company enters into agreements to hedge the risk of future oil and gas price fluctuations. Such agreements are typically in the form of fixed price commodity and basis swaps, which limit the impact of price fluctuations with respect to the Company’s sale of oil and gas. While it is never management’s intention to hold or issue derivative instruments for speculative trading purposes, conditions could arise where actual production is less than estimated which could result in over hedged volumes. All derivative instruments are recorded on the Consolidated Balance Sheets at fair value as either short-term or long-term assets or liabilities based on their anticipated settlement date. The derivative instruments the Company utilizes are based on index prices that may 815. not
Fair Value of Financial Instruments, Policy [Policy Text Block]	Fair Value of Financial Instruments The Company includes fair value information in the notes to consolidated financial statements when the fair value of its financial instruments is materially different from the carrying value. The carrying value of those financial instruments that are classified as current, except for derivative instruments, approximates fair value because of the short maturity of these instruments. For noncurrent financial instruments, the Company uses quoted market prices or, to the extent that there are no
Share-based Payment Arrangement [Policy Text Block]	Share-Based Payments Options granted are valued at the date of grant and expense is recognized over the vesting period. The Company currently utilizes a standard option pricing model (Black-Scholes) to measure the fair value of stock options granted to employees and directors. Restricted stock awards are awards of common stock that are subject to restrictions on transfer and to a risk of forfeiture if the awardee terminates employment with the Company prior to the lapse of the restrictions. The value of such restricted stock is determined using the market price on the grant date and expense is recorded over the vesting period. For the years ended December 31, 2019 2020
Asset Retirement Obligation and Environmental Cost [Policy Text Block]	Restoration, Removal and Environmental Liabilities The Company is subject to extensive federal, state and local environmental laws and regulations. These laws regulate the discharge of materials into the environment and may no Liabilities for expenditures of a noncapital nature are recorded when environmental assessments and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments for the liability or component are fixed or reliably determinable. The fair value of a liability for an asset's retirement obligation is recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period and the capitalized cost is depreciated over the estimated useful life of the related asset. For all periods presented, we have included estimated future costs of abandonment and dismantlement in our full cost amortization base and we amortize these costs as a component of our depletion expense in the accompanying consolidated financial statements. Each year, the Company reviews, and to the extent necessary, revises its asset retirement obligation estimates. The following table (in thousands) summarizes changes in the Company’s future site restoration obligations during the two December 31: 2019 2020 Beginning future site restoration obligation $ 7,492 $ 7,420 New wells placed on production and other 80 43 Deletions related to property disposals (473 ) (216 ) Deletions related to plugging costs (890 ) (235 ) Accretion expense and other 436 414 Revisions and other 775 (66 ) Ending future site restoration obligation $ 7,420 $ 7,360
Revenue [Policy Text Block]	Revenue Recognition and Major Purchasers The Company recognizes oil and gas revenue from its interest in producing wells as oil and gas is sold from those wells, net of royalties, control of the product has transferred to the purchaser and collectability is reasonably assured. The Company had no December 31, 2019 2020 During 2019 2020
Deferred Charges, Policy [Policy Text Block]	Deferred Financing Fees Deferred financing fees are being amortized on the effective yield basis over the term of the related debt.
Income Tax, Policy [Policy Text Block]	Income Taxes Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to be in effect with respect to taxable income in the years in which those temporary differences are expected to be recovered or settled. Uncertainties exist as to the future utilization of the operating loss carryforwards. Therefore, we have established a valuation allowance of $117.27 million for deferred tax assets at December 31, 2020
Income Tax Uncertainties, Policy [Policy Text Block]	Accounting for Uncertainty in Income Taxes Evaluation of a tax position is a two first not second not 50% Tax positions that previously failed to meet the more-likely-than- not first no not first no no December 31, 2020
New Accounting Pronouncements, Policy [Policy Text Block]	Adoption of New Accounting Standards Effective January 1, 2020, 2016 13 30 not In November 2019, 2019 12 740” 2019 12 740 2019 12 December 15, 2020. not In March 2020, No. 2020 04, 840 2020 04” 2020 04 470 December 31, 2022. In May 2020, not not January 1, 2021,

Note 1 - Organization and Sig_2

Note 1 - Organization and Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Change in Asset Retirement Obligation [Table Text Block]	2019 2020 Beginning future site restoration obligation $ 7,492 $ 7,420 New wells placed on production and other 80 43 Deletions related to property disposals (473 ) (216 ) Deletions related to plugging costs (890 ) (235 ) Accretion expense and other 436 414 Revisions and other 775 (66 ) Ending future site restoration obligation $ 7,420 $ 7,360

Note 2 - Revenue From Contrac_2

Note 2 - Revenue From Contracts With Customers (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Disaggregation of Revenue [Table Text Block]	Years Ended December 31, 2019 2020 Oil Gas NGL Oil Gas NGL Operating Region Permian/Delaware Basin $ 52,789 $ 494 $ 602 $ 22,891 $ 335 $ 163 Rocky Mountain $ 68,555 $ 1,480 $ 1,305 $ 19,078 $ 251 $ 266 South Texas $ 3,159 $ 605 $ 3 $ - $ - $ -

Note 4 - Long-term Debt (Tables

Note 4 - Long-term Debt (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Long-term Debt Instruments [Table Text Block]	Years Ended December 31, 2019 2020 (In thousands) First Lien Credit Facility $ 95,778 $ 95,000 Second Lien Credit Facility 100,000 112,695 Exit fee - Second Lien Credit Facility - 10,000 Real estate lien note 3,091 2,810 198,869 220,505 Less current maturities (280 ) (202,751 ) 198,589 17,754 Deferred financing fees and debt issuance cost - net (5,871 ) (15,239 ) Total long-term debt, net of deferred financing fees and debt issuance costs $ 192,718 $ 2,515
Contractual Obligation, Fiscal Year Maturity [Table Text Block]	Years ending December 31, (In thousands) 2021 $ 217,990 2022 310 2023 2,205 2024 - 2025 - Thereafter - Total $ 220,505

Note 5 - Property and Equipme_2

Note 5 - Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Property, Plant and Equipment [Table Text Block]	Estimated December 31, Useful life 2019 2020 Years (In thousands) Oil and gas properties (1) - $ 1,162,094 $ 1,167,333 Equipment and other 3-39 15,187 15,348 Drilling rig 15 24,108 24,108 1,201,389 1,206,789 Accumulated depreciation, depletion, amortization and impairment (872,431 ) (1,083,843 ) Net Property and Equipment $ 328,958 $ 122,946

Note 6 - Stock-based Compensa_2

Note 6 - Stock-based Compensation and Option Plans (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Share-based Payment Arrangement, Option, Activity [Table Text Block]	Options Weighted average Weighted average Intrinsic value (000s) exercise price remaining life per share Options outstanding December 31, 2018 378 $ 47.35 Granted - - Exercised (23 ) 19.63 Forfeited/Expired (58 ) 48.02 Options outstanding December 31, 2019 297 $ 49.41 Granted - - Exercised - - Forfeited/Expired (101 ) 48.96 Options outstanding December 31, 2020 196 49.69 3.8 $ 0.00 Exercisable at end of year 192 49.64 3.9 $ 0.00 2019 2020 Weighted average grant date fair value of stock options granted (per share) $ - $ - Total fair value of options vested (000's) $ 732 $ 275 Total intrinsic value of options exercised (000's) $ 141 $ -
Share-based Payment Arrangement, Option, Exercise Price Range [Table Text Block]	Outstanding Options Exercisable Weighted Weighted Weighted Weighted average average average average Number remaining exercise Number remaining exercise Range of stock option prices Outstanding life price Outstanding life price 19.40-29.99 66,025 4.9 $ 20.02 66,025 4.9 $ 20.02 30.00-39.99 5,350 6.4 $ 37.47 5,263 6.4 $ 34.46 40.00-49.99 19,459 2.2 $ 47.73 19,447 2.2 $ 47.73 50.00-59.99 13,900 6.0 $ 55.81 11,400 5.7 $ 56.33 60.00-69.99 52,646 3.8 $ 63.14 52,646 3.8 $ 63.14 70.00-79.99 19,075 1.8 $ 73.22 19,075 1.8 $ 73.22 80.00-89.99 3,650 2.9 $ 84.15 3,650 2.9 $ 84.14 90.00-99.99 12,625 1.8 $ 93.38 12,625 1.8 $ 93.38 100.00-125.60 2,450 3.3 $ 107.97 2,450 3.3 $ 17.97 195,180 3.9 $ 49.69 192,581 3.8 $ 49.64
Schedule of Nonvested Restricted Stock Units Activity [Table Text Block]	Number of Shares Weighted average grant date fair value Unvested December 31, 2018 42 $ 43.07 Granted 66 26.75 Vested/Released (14 ) 42.98 Forfeited/Expired (5 ) 30.71 Unvested December 31, 2019 89 $ 31.67 Granted - - Vested/Released (33 ) 32.11 Forfeited/Expired (15 ) 31.52 Unvested December 31, 2020 41 $ 31.37
Schedule of Nonvested Performance-based Units Activity [Table Text Block]	Number of Shares Weighted average grant date fair value Unvested December 31, 2018 20 47.40 Granted 40 26.80 Vested/Released - - Forfeited (3 ) 30.38 Unvested December 31, 2019 57 $ 33.86 Granted - - Vested/Released - - Forfeited (13 ) 34.29 Unvested December 31, 2020 44 $ 33.73
Schedule of Stockholders' Equity Note, Warrants or Rights [Table Text Block]	Issuance Date Exercisable for Expiration Date Exercise Price Number of Shares August 11, 2020 Common Stock August 11, 2025 $ 0.20 1,672,290

Note 7 - Income Taxes (Tables)

Note 7 - Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	As of December 31, 2019 2020 (In thousands) Deferred tax liabilities: Hedge contracts $ - $ 4,299 Other 3,158 2,137 Total deferred tax liabilities 3,158 6,436 Deferred tax assets: US full cost pool $ 9,595 35,500 Depletion carryforward 3,722 461 U.S. net operating loss carryforward 68,250 84,927 Alternative minimum tax credit 6 - Hedge contracts 1,661 - Interest disallowed - 2,818 Total deferred tax assets 83,234 123,706 Valuation allowance for deferred tax assets (80,076 ) (117,270 ) Net deferred tax assets 3,158 6,436 Net deferred tax $ - $ -
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Years Ended December 31, 2019 2020 (In thousands) Current: Federal $ - $ - State - - $ - $ - Deferred: Federal $ - $ - $ - $ -
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Years Ended December 31, 2019 2020 (in thousands) Tax benefit at U.S. Statutory rates $ 13,651 $ 38,749 Change in deferred tax asset valuation allowance (12,767 ) (37,193 ) Alternative minimum tax expense (745 ) - Expired capital loss carryover (3,966 ) - Permanent differences (403 ) (276 ) Return to provision estimated revision 341 (3,069 ) State income taxes, net of federal effect 3,892 1,789 Other (3 ) - $ - $ -

Note 9 - Earnings Per Share (Ta

Note 9 - Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	Years Ended December 31, 2019 2020 Numerator: Net (loss) $ (65,004 ) $ (184,522 ) Denominator for basic earnings per share - weighted-average common shares outstanding 8,312 8,382 Effect of dilutive securities: Stock options, restricted shares and performance based shares 3 - Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and performance based shares 8,315 8,382 Net (loss) per common share - basic $ (7.82 ) $ (22.01 ) Net (loss) per common share - diluted $ (7.82 ) $ (22.01 )

Note 11 - Hedging Program and_2

Note 11 - Hedging Program and Derivatives (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Fixed Price Derivatives [Table Text Block]	Oil - WTI Contract Periods Daily Volume (Bbl) Swap Price (per Bbl) Fixed Swaps January - December 2021 2,889 $ 57.62 January - December 2022 2,412 $ 50.60 January - December 2023 1,498 $ 50.60 January - December 2024 1,585 $ 50.60
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	Fair Value Derivative Contracts as of December 31, 2019 Asset Derivatives Liability Derivatives Derivatives not designated as hedging instruments Balance Sheet Location Fair Value Balance Sheet Location Fair Value Commodity price derivatives Derivatives - current $ 83 Derivatives - current $ 10,688 Commodity price derivatives Derivatives - long-term 4,170 Derivatives - long-term 999 $ 4,253 $ 11,687 Fair Value Derivative Contracts as of December 31, 2020 Asset Derivatives Liability Derivatives Derivatives not designated as hedging instruments Balance Sheet Location Fair Value Balance Sheet Location Fair Value Commodity price derivatives Derivatives - current $ 9,639 Derivatives - current $ 480 Commodity price derivatives Derivatives - long-term 10,281 Derivatives - long-term - $ 19,920 $ 480

Note 12 - Financial Instrumen_2

Note 12 - Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Balance as of December 31, 2019 Assets: NYMEX fixed price derivative contracts $ - $ 4,253 $ - $ 4,253 NYMEX basis differential swap - - - - Total Assets $ - $ 4,253 $ - $ 4,253 Liabilities: NYMEX fixed price derivative contracts $ - $ 5,583 $ - $ 5,583 NYMEX basis differential swap - - 6,104 6,104 Total Liabilities $ - $ 5,583 $ 6,104 $ 11,687 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Balance as of December 31, 2020 Assets: NYMEX fixed price derivative contracts $ - $ 19,920 $ - $ 19,920 Total Assets $ - $ 19,920 $ - $ 19,920 Liabilities: NYMEX fixed price derivative contracts $ - $ 480 $ - $ 480 Total Liabilities $ - $ 480 $ - $ 480
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	(In thousands) Fair value at January 1, 2020 $ (6,104 ) Changes in market value 4,577 Settlements during the period 1,527 Fair value at December 31, 2020 $ -

Note 13 - Lease Accounting St_2

Note 13 - Lease Accounting Standard (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Lease, Cost [Table Text Block]	For the Year Ended December 31, 2019 2020 (in thousands) Operating lease cost $ 478 $ 114 Short-term lease expense (1) 1,992 2,183 Total lease expense $ 2,470 $ 2,297 Short-term lease costs (2) $ 4,900 $ 973 For the Year Ended December 31, 2019 2020 (in thousands) Weighted Average Remaining Lease Term (in years) 8.66 10.68 Weighted Average Discount Rate 6 % 6 % For the Year Ended December 31, 2019 2020 (in thousands) Cash paid for amounts included in the measurement of lease liabilities $ 478 $ 114 Right of Use assets added in exchange for lease obligations (since adoption) $ 770 $ 125
Schedule of Operating Leased Assets [Table Text Block]	For the Year Ended December 31, 2019 2020 (in thousands) Operating lease Right of Use asset $ 327 $ 228 Operating lease liability - current $ 98 $ 53 Operating lease liabilities - long-term $ 203 $ 150
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Operating Leases (in thousands) 2021 $ 63 2022 48 2023 41 2024 28 2025 4 Thereafter 98 Total lease payments 282 Less imputed interest (79 ) Total lease liability $ 203

Note 15 - Quarterly Results o_2

Note 15 - Quarterly Results of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Quarterly Financial Information [Table Text Block]	1st 2nd 3rd 4th Quarter Quarter Quarter Quarter (In thousands, except per share data) Year Ended December 31, 2019 Net revenue $ 34,514 $ 34,820 $ 31,536 $ 28,276 Operating income (loss) $ 6,708 $ 8,935 $ 8,053 $ (49,412 ) Net income (loss) $ (25,455 ) $ 11,678 $ 17,041 $ (68,268 ) Net income (loss) per common share - basic $ (3.00 ) $ 1.40 $ 2.00 $ (8.20 ) Net income (loss) per common share - diluted $ (3.00 ) $ 1.40 $ 2.00 $ (8.20 ) Year Ended December 31, 2020 Net revenue $ 15,726 $ 1,993 $ 12,595 $ 12,729 Operating income (loss) $ (29,781 ) $ (61,474 ) $ (56,661 ) $ (51,502 ) Net income (loss) $ 41,443 $ (83,256 ) $ (73,615 ) $ (69,094 ) Net income (loss) per common share - basic $ 4.80 $ (10.00 ) $ (8.80 ) $ (8.21 ) Net income (loss) per common share - diluted $ 4.80 $ (10.00 ) $ (8.80 ) $ (8.21 )

Note 16 - Supplemental Oil an_2

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Years Ended December 31, (in thousands) 2019 2020 Proved oil and gas properties $ 1,162,094 $ 1,167,333 Unproved properties - - Total 1,162,094 1,167,333 Accumulated depreciation, depletion, amortization and impairment (851,107 ) (1,060,649 ) Net capitalized costs $ 310,987 $ 106,684
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	2019 2020 Development costs $ 92,884 $ 5,238 Exploration costs - - Property acquisition costs - - $ 92,884 $ 5,238
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]	2019 2020 Revenues $ 128,992 $ 42,984 Production costs (38,229 ) (21,090 ) Depreciation, depletion and amortization (51,041 ) (22,679 ) Accretion of future site restoration (436 ) (414 ) Proved property impairment (51,293 ) (186,980 ) Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs) $ (12,007 ) $ (188,179 ) Depletion rate per barrel of oil equivalent $ 14.12 $ 12.59
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	Oil Oil NGL Gas Equivalents (MBbl) (MBbl) (MMcf) (Mboe) Change in Proved Reserves Balance at December 31, 2018 42,237 10,034 89,744 67,228 Revisions of previous estimates (15,616 ) (2,713 ) (23,178 ) (22,192 ) Extensions and discoveries 13,477 2,285 14,073 18,109 Purchases of minerals in place - - - - Sales of minerals in place (1,431 ) (86 ) (9,898 ) (3,167 ) Production (2,388 ) (548 ) (4,076 ) (3,616 ) Balance at December 31, 2019 36,279 8,972 66,665 56,362 Revisions of previous estimates (16,922 ) (3,549 ) (27,921 ) (25,125 ) Extensions and discoveries - - - - Removal of PUDs (8,687 ) (1,922 ) (12,291 ) (12,658 ) Production (1,132 ) (313 ) (2,135 ) (1,801 ) Balance at December 31, 2020 9,538 3,188 24,318 16,778 Total Oil Oil NGL Gas Equivalents (MBbl) (MBbl) (MMcf) (Mboe) Proved Developed Reserves: December 31, 2019 10,964 2,699 21,439 17,237 December 31, 2020 9,538 3,187 24,318 16,778 Proved Undeveloped Reserves: December 31, 2019 25,315 6,273 45,226 39,125 December 31, 2020 - - - -
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	Years Ended December 31, (in thousands) 2019 2020 Future cash inflows $ 1,890,579 $ 345,869 Future production costs (598,714 ) (166,781 ) Future development costs (544,111 ) (6,291 ) Future income tax expense - - Future net cash flows 747,754 172,797 Discount $ (440,142 ) $ (66,113 ) Standardized Measure of discounted future net cash relating to proved reserves $ 307,612 $ 106,684
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	Years Ended December 31, (in thousands) 2019 2020 Standardized Measure, beginning of year $ 651,884 $ 307,612 Sales and transfers of oil and gas produced, net of production costs (90,763 ) (21,894 ) Net change in prices and development and production costs from prior year (218,092 ) (96,688 ) Extensions, discoveries, and improved recovery, less related costs 98,780 - Sales of minerals in place (17,276 ) - Removal of PUDs - (80,416 ) Revisions of previous estimates (227,477 ) (159,613 ) Change in timing and other (13,744 ) 126,922 Change in future income tax expense 59,112 - Accretion of discount 65,188 30,761 Standardized Measure, end of year $ 307,612 $ 106,684
Oil and Gas Prices Considered in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	Years Ended December 31, 2019 2020 Oil (per Bbl) (1) $ 55.73 $ 39.54 Gas (per Mmbtu) (2) $ 2.54 $ 2.03 Oil (per Bbl) (3) $ 52.14 $ 37.05 Gas (per Mmbtu) (4) $ 0.63 $ 0.27 NGL's (per Bbl) (5) $ 3.48 $ 1.37

Note 1 - Organization and Sig_3

Note 1 - Organization and Significant Accounting Policies (Details Textual) $ in Thousands	Oct. 19, 2020	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Apr. 30, 2021USD ($)	Apr. 14, 2021USD ($)
Long-term Debt, Gross		$ 220,505	$ 198,869
Line of Credit, Exit Fee		10,000
Accounts Receivable, Allowance for Credit Loss, Ending Balance		$ 100	100
Discount Rate Used in Future Net Cash Flows Relating to Proved Oil and Gas Reserves		10.00%
Impairment of Oil and Gas Properties		$ 186,980	51,293
Share-based Payment Arrangement, Noncash Expense, Total		1,312	1,911
Deferred Tax Assets, Valuation Allowance, Total		$ 117,270	$ 80,076
Revenue Benchmark [Member] | Customer Concentration Risk [Member]
Entity Wide Revenue Number of Major Purchasers of Oil and Gas		4	2
Revenue Benchmark [Member] | Customer Concentration Risk [Member] | Two Purchasers [Member]
Concentration Risk, Percentage			71.00%
Revenue Benchmark [Member] | Customer Concentration Risk [Member] | Four Purchasers [Member]
Concentration Risk, Percentage		73.00%
Reverse Stock Split [Member]
Stockholders' Equity Note, Stock Split, Conversion Ratio	20
Subsequent Event [Member]
Long-term Debt, Gross					$ 219,400
First Lien Credit Facility [Member]
Long-term Debt, Gross		$ 95,000
First Lien Credit Facility [Member] | Subsequent Event [Member]
Long-term Debt, Gross					89,500
First Lien Credit Facility [Member] | Subsequent Event [Member] | Obligations from Terminated Hedging Arrangements [Member]
Termination Value of Hedge Contracts				$ 9,900
Debt Instrument, Interest Rate, Stated Percentage				6.70%
Second Lien Credit Facility [Member]
Long-term Debt, Gross		$ 112,700
Second Lien Credit Facility [Member] | Subsequent Event [Member]
Long-term Debt, Gross					127,200
Line of Credit, Exit Fee					$ 10,000

Note 1 - Organization and Sig_4

Note 1 - Organization and Significant Accounting Policies - Future Site Restoration Obligation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Beginning future site restoration obligation	$ 7,420	$ 7,492
New wells placed on production and other	43	80
Deletions related to property disposals	(216)	(473)
Deletions related to plugging costs	(235)	(890)
Accretion expense and other	414	436
Revisions and other	(66)	775
Ending future site restoration obligation	$ 7,360	$ 7,420

Note 2 - Revenue From Contrac_3

Note 2 - Revenue From Contracts With Customers (Details Textual) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Asset, after Allowance for Credit Loss, Total	$ 8.8	$ 17

Note 2 - Revenue From Contrac_4

Note 2 - Revenue From Contracts With Customers - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Oil Revenues [Member]
Revenue	$ 41,969	$ 124,503
Gas Revenues [Member]
Revenue	586	2,579
Natural Gas Liquids Revenues [Member]
Revenue	429	1,910
Permian / Delaware Basin [Member] | Oil Revenues [Member]
Revenue	22,891	52,789
Permian / Delaware Basin [Member] | Gas Revenues [Member]
Revenue	335	494
Permian / Delaware Basin [Member] | Natural Gas Liquids Revenues [Member]
Revenue	163	602
Rocky Mountain [Member] | Oil Revenues [Member]
Revenue	19,078	68,555
Rocky Mountain [Member] | Gas Revenues [Member]
Revenue	251	1,480
Rocky Mountain [Member] | Natural Gas Liquids Revenues [Member]
Revenue	266	1,305
South Texas [Member] | Oil Revenues [Member]
Revenue	0	3,159
South Texas [Member] | Gas Revenues [Member]
Revenue	0	605
South Texas [Member] | Natural Gas Liquids Revenues [Member]
Revenue	$ 0	$ 3

Note 3 - Reverse Stock Split (D

Note 3 - Reverse Stock Split (Details Textual) $ / shares in Units, $ in Millions	Oct. 19, 2020$ / sharesshares	Sep. 30, 2020USD ($)	Dec. 31, 2019USD ($)$ / sharesshares	Dec. 31, 2020$ / sharesshares	Oct. 18, 2020shares
Common Stock, Par or Stated Value Per Share (in dollars per share) | $ / shares			$ 0.01	$ 0.01
Common Stock, Shares Authorized (in shares)			20,000,000	20,000,000
Common Stock, Shares, Outstanding, Ending Balance (in shares)			8,436,498	8,421,910
Reverse Stock Split [Member]
Stockholders' Equity Note, Stock Split, Conversion Ratio	20
Common Stock, Par or Stated Value Per Share (in dollars per share) | $ / shares	$ 0.01
Common Stock, Shares Authorized (in shares)	20,000,000				400,000,000
Common Stock, Shares, Outstanding, Ending Balance (in shares)	8,453,466				168,069,305
Adjustments to Additional Paid in Capital, Stock Split | $		$ 1.6	$ 1.6

Note 4 - Long-term Debt (Detail

Note 4 - Long-term Debt (Details Textual)	Oct. 19, 2020USD ($)$ / sharesshares	Jun. 25, 2020USD ($)	Nov. 13, 2019USD ($)	Jun. 20, 2018USD ($)	Dec. 31, 2020USD ($)$ / sharesshares	Dec. 31, 2019USD ($)	Aug. 11, 2020$ / sharesshares
Line of Credit, Exit Fee					$ 10,000,000
Gain (Loss) on Extinguishment of Debt, Total					(4,108,000)	$ 0
Long-term Debt, Total					$ 2,515,000	192,718,000
Reverse Stock Split [Member]
Stockholders' Equity Note, Stock Split, Conversion Ratio	20
Warrant Issued to Lender [Member]
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in shares) | shares	1,672,290				1,672,290		33,445,792
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) | $ / shares	$ 0.20				$ 0.20		$ 0.01
Warrants and Rights Outstanding, Term (Year)	5 years
Line of Credit [Member] | First Lien Credit Facility [Member]
Long-term Line of Credit, Total					$ 95,000,000
Debt Instrument, Spread on Elected Variable Rate					0.50%
Debt Instrument, Debt Default, Basis Spread on Variable Rate					3.00%
Line of Credit Facility, Interest Rate at Period End					3.60%
Debt Instrument, Collateral Eligible, Minimum Percent of PV-9 of Proven Reserves Required					90.00%
Debt Instrument, Collateral Eligible, Minimum Percent of PV-9 of PDP Reserves Required					95.00%
Debt Instrument, Covenant, Working Capital Reserve		$ 3,000,000
Debt Instrument, Covenant, Maximum Capital Expenditures		$ 3,000,000
Debt Instrument, Covenant, Minimum Asset Coverage Ratio for Capital Expenditures		1.60
Debt Instrument, Covenant, Maximum Line of Credit Outstanding for Capital Expenditures		$ 50,000,000
Debt Instrument, Covenant, Maximum Outstanding and Undisputed Accounts Payable		7,500,000
Debt Instrument, Covenant, Maximum Undisputed Accounts Payable Outstanding with 60 to 90 Days		2,000,000
Debt Instrument, Covenant, Maximum Undisputed Accounts Payable Outstanding with Over 90 Days		1,000,000
Debt Instrument, Covenant, Maximum Legal and Professional Fees Excluded from General and Administrative Expense Limitations		1,000,000
Debt Instrument, Covenant, Maximum Additional Subordinated Debt Allowed to Finance Capital Expenditures		25,000,000
Line of Credit Facility, Current Borrowing Capacity		102,000,000
Line of Credit [Member] | First Lien Credit Facility [Member] | General and Administrative Expenses for Quarter Ending June 30, 2020 [Member]
Debt Instrument, Covenant, Maximum Quarterly General and Administrative Expenses		9,000,000
Line of Credit [Member] | First Lien Credit Facility [Member] | General and Administrative Expenses for Quarter Ending September 30, 2020 [Member]
Debt Instrument, Covenant, Maximum Quarterly General and Administrative Expenses		8,250,000
Line of Credit [Member] | First Lien Credit Facility [Member] | General and Administrative Expenses for Quarter Ending December 31, 2020 [Member]
Debt Instrument, Covenant, Maximum Quarterly General and Administrative Expenses		6,900,000
Line of Credit [Member] | First Lien Credit Facility [Member] | General and Administrative Expenses for Year End December 31, 2021 [Member]
Debt Instrument, Covenant, Maximum Yearly General and Administrative Expenses		6,500,000
Line of Credit [Member] | First Lien Credit Facility [Member] | General and Administrative Expenses After Year End December 31, 2021 [Member]
Debt Instrument, Covenant, Maximum Yearly General and Administrative Expenses		$ 5,000,000
Line of Credit [Member] | First Lien Credit Facility [Member] | Minimum [Member]
Debt Instrument, Spread on Elected Variable Rate					2.50%
Debt Instrument, Basis Spread on Variable Rate					1.50%
Line of Credit [Member] | First Lien Credit Facility [Member] | Maximum [Member]
Debt Instrument, Spread on Elected Variable Rate					3.50%
Debt Instrument, Basis Spread on Variable Rate					2.50%
Debt Instrument, Covenant, Total Debt to EBITDAX Ratio		2.75
Debt Instrument, Covenant, Asset Coverage Ratio, Current		1.15
Debt Instrument, Covenant, Asset Coverage Ratio, Noncurrent		1.25
Line of Credit [Member] | Second Lien Credit Facility [Member]
Long-term Line of Credit, Total					$ 122,700,000
Debt Instrument, Covenant, Maximum Outstanding and Undisputed Accounts Payable		$ 7,500,000
Debt Instrument, Covenant, Maximum Undisputed Accounts Payable Outstanding with 60 to 90 Days		2,000,000
Debt Instrument, Covenant, Maximum Undisputed Accounts Payable Outstanding with Over 90 Days		1,000,000
Line of Credit Facility, Maximum Borrowing Capacity			$ 100,000,000
Proceeds from Lines of Credit, Total			$ 95,000,000
Line of Credit, Exit Fee					10,000,000	0
Debt Instrument, Collateral Eligible, Minimum Percent of PV-9 Proven Reserves			90.00%
Debt Instrument, Collateral Eligible, Minimum Percent of PV-9 Required PDP Reserves			95.00%
Gain (Loss) on Extinguishment of Debt, Total	$ (4,100,000)
Line of Credit [Member] | Second Lien Credit Facility [Member] | General and Administrative Expenses for Quarter Ending June 30, 2020 [Member]
Debt Instrument, Covenant, Maximum Quarterly General and Administrative Expenses		9,000,000
Line of Credit [Member] | Second Lien Credit Facility [Member] | General and Administrative Expenses for Quarter Ending September 30, 2020 [Member]
Debt Instrument, Covenant, Maximum Quarterly General and Administrative Expenses		8,250,000
Line of Credit [Member] | Second Lien Credit Facility [Member] | General and Administrative Expenses for Year End December 31, 2021 [Member]
Debt Instrument, Covenant, Maximum Yearly General and Administrative Expenses		6,500,000
Line of Credit [Member] | Second Lien Credit Facility [Member] | General and Administrative Expenses After Year End December 31, 2021 [Member]
Debt Instrument, Covenant, Maximum Yearly General and Administrative Expenses		$ 5,000,000
Line of Credit [Member] | Second Lien Credit Facility [Member] | Maximum [Member]
Debt Instrument, Covenant, Asset Coverage Ratio, Noncurrent, Year Two		1.45
Debt Instrument, Covenant, Asset Coverage Ratio, Noncurrent, after Year Two		1.55
Construction Loans [Member]
Debt Instrument, Interest Rate, Stated Percentage				4.90%
Debt Instrument, Periodic Payment, Total				$ 35,672
Long-term Debt, Total					$ 2,800,000	$ 3,100,000

Note 4 - Long-term Debt - Debt

Note 4 - Long-term Debt - Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Long-term debt	$ 220,505	$ 198,869
Exit fee - Second Lien Credit Facility	10,000
Less current maturities	(202,751)	(280)
Long-term Debt, Noncurrent, Gross	17,754	198,589
Deferred financing fees and debt issuance cost - net	(15,239)	(5,871)
Total long-term debt, net of deferred financing fees and debt issuance costs	2,515	192,718
First Lien Credit Facility [Member]
Long-term debt	95,000
Second Lien Credit Facility [Member]
Long-term debt	112,700
Line of Credit [Member] | First Lien Credit Facility [Member]
Long-term debt	95,000	95,778
Line of Credit [Member] | Second Lien Credit Facility [Member]
Long-term debt	112,695	100,000
Exit fee - Second Lien Credit Facility	10,000	0
Mortgages [Member]
Long-term debt	$ 2,810	$ 3,091

Note 4 - Long-term Debt - Matur

Note 4 - Long-term Debt - Maturities of Long-term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
2021	$ 217,990
2022	310
2023	2,205
2024	0
2025	0
Thereafter	0
Total	$ 220,505	$ 198,869

Note 5 - Property and Equipme_3

Note 5 - Property and Equipment - Property and Equipment (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019
Oil and gas properties (1)		$ 1,206,789	$ 1,201,389
Accumulated depreciation, depletion, amortization and impairment		(1,083,843)	(872,431)
Net Property and Equipment		122,946	328,958
Oil and Gas Properties [Member]
Oil and gas properties (1)	[1]	1,167,333	1,162,094
Equipment and Other [Member]
Oil and gas properties (1)		$ 15,348	15,187
Equipment and Other [Member] | Minimum [Member]
Estimated Useful Life (Year)		3 years
Equipment and Other [Member] | Maximum [Member]
Estimated Useful Life (Year)		39 years
Drilling Rig [Member]
Oil and gas properties (1)		$ 24,108	$ 24,108
Estimated Useful Life (Year)		15 years
[1]	Oil and gas properties are amortized utilizing the units of production method.

Note 6 - Stock-based Compensa_3

Note 6 - Stock-based Compensation and Option Plans (Details Textual)	Oct. 19, 2020$ / sharesshares	Apr. 01, 2018	Dec. 31, 2020USD ($)$ / sharesshares	Dec. 31, 2019USD ($)shares	Aug. 11, 2020$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in shares) | shares			0	0
Share-based Payment Arrangement, Noncash Expense, Total			$ 1,312,000	$ 1,911,000
Common Stock, Capital Shares Reserved for Future Issuance (in shares) | shares			450,000
Reverse Stock Split [Member]
Stockholders' Equity Note, Stock Split, Conversion Ratio	20
Warrant Issued to Lender [Member]
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in shares) | shares	1,672,290		1,672,290		33,445,792
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) | $ / shares	$ 0.20		$ 0.20		$ 0.01
Warrants and Rights Outstanding, Term (Year)	5 years
Directors Plan 2005 [Member]
Common Stock, Capital Shares Reserved for Future Issuance (in shares) | shares			70,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Maximum Number of Shares Per Employee (in shares) | shares			1,250
Percentage of Exercise Price Awarded			100.00%
Share-based Payment Arrangement, Option [Member]
Deferred Compensation Arrangement with Individual, Common Stock Reserved for Future Issuance (in shares) | shares			600,000
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period (Year)			10 years
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount, Total			$ 60,000
Share-based Payment Arrangement, Noncash Expense, Total			100,000	400,000
Restricted Stock [Member]
Share-based Payment Arrangement, Noncash Expense, Total			900,000	1,000,000
Share-based Payment Arrangement, Nonvested Award, Excluding Option, Cost Not yet Recognized, Amount			1,400,000
Restricted Stock [Member] | Directors Plan 2005 [Member] | Share-based Payment Arrangement, Nonemployee [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Amount Approved for Issuance Per Participant			12,000
Performance Shares [Member]
Share-based Payment Arrangement, Noncash Expense, Total			300,000	$ 500,000
Share-based Payment Arrangement, Nonvested Award, Excluding Option, Cost Not yet Recognized, Amount			$ 400,000
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period (Year)		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Target Payout Rate		100.00%
Performance Shares [Member] | Minimum [Member]
Share-based Compensation Awards, Vesting, Requirement, TSR, Percentage		0.00%
Performance Shares [Member] | Maximum [Member]
Share-based Compensation Awards, Vesting, Requirement, TSR, Percentage		200.00%

Note 6 - Stock-based Compensa_4

Note 6 - Stock-based Compensation and Option Plans - Stock Option Activity (Details) - Share-based Payment Arrangement, Option [Member] - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Balance (in shares)	297	378
Balance, weighted average exercise price (in dollars per share)	$ 49.69	$ 49.41	$ 47.35
Granted (in shares)	0	0
Granted, weighted average exercise price (in dollars per share)		$ 0	0
Exercised (in shares)	0	(23)
Exercised, weighted average exercise price (in dollars per share)		$ 0	19.63
Forfeited/Expired (in shares)	(101)	(58)
Forfeited/Expired, weighted average exercise price (in dollars per share)		$ 48.96	$ 48.02
Balance (in shares)	196	297	378
Balance, weighted average exercise price (in dollars per share)		$ 49.69	$ 49.41
Options outstanding, weighted average remaining life (Year)	3 years 9 months 18 days
Options outstanding, intrinsic value per share (in dollars per share)	$ 0
Exercisable at end of year (in shares)	192
Exercisable, weighted average exercise price (in dollars per share)	$ 49.64
Exercisable, weighted average remaining life (Year)	3 years 10 months 24 days
Exercisable, intrinsic value per share (in dollars per share)	$ 0
Weighted average grant date fair value of stock options granted (per share) (in dollars per share)	$ 0	$ 0
Total fair value of options vested (000's)	$ 275	$ 732
Total intrinsic value of options exercised (000's)	$ 0	$ 141

Note 6 - Stock-based Compensa_5

Note 6 - Stock-based Compensation and Option Plans - Stock Options Outstanding (Details)	12 Months Ended
	Dec. 31, 2020$ / sharesshares
Outstanding options, number outstanding (in shares) | shares	195,180
Outstanding options, weighted average remaining life (Year)	3 years 10 months 24 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 49.69
Exercisable, number outstanding (in shares) | shares	192,581
Exercisable, weighted average remaining life (Year)	3 years 9 months 18 days
Exercisable, weighted average exercise price (in dollars per share)	$ 49.64
Range One [Member]
Exercise price range, lower limit (in dollars per share)	19.40
Exercise price range, upper limit (in dollars per share)	$ 29.99
Outstanding options, number outstanding (in shares) | shares	66,025
Outstanding options, weighted average remaining life (Year)	4 years 10 months 24 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 20.02
Exercisable, number outstanding (in shares) | shares	66,025
Exercisable, weighted average remaining life (Year)	4 years 10 months 24 days
Exercisable, weighted average exercise price (in dollars per share)	$ 20.02
Range Two [Member]
Exercise price range, lower limit (in dollars per share)	30
Exercise price range, upper limit (in dollars per share)	$ 39.99
Outstanding options, number outstanding (in shares) | shares	5,350
Outstanding options, weighted average remaining life (Year)	6 years 4 months 24 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 37.47
Exercisable, number outstanding (in shares) | shares	5,263
Exercisable, weighted average remaining life (Year)	6 years 4 months 24 days
Exercisable, weighted average exercise price (in dollars per share)	$ 34.46
Range Three [Member]
Exercise price range, lower limit (in dollars per share)	40
Exercise price range, upper limit (in dollars per share)	$ 49.99
Outstanding options, number outstanding (in shares) | shares	19,459
Outstanding options, weighted average remaining life (Year)	2 years 2 months 12 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 47.73
Exercisable, number outstanding (in shares) | shares	19,447
Exercisable, weighted average remaining life (Year)	2 years 2 months 12 days
Exercisable, weighted average exercise price (in dollars per share)	$ 47.73
Range Four [Member]
Exercise price range, lower limit (in dollars per share)	50
Exercise price range, upper limit (in dollars per share)	$ 59.99
Outstanding options, number outstanding (in shares) | shares	13,900
Outstanding options, weighted average remaining life (Year)	6 years
Outstanding options, weighted average exercise price (in dollars per share)	$ 55.81
Exercisable, number outstanding (in shares) | shares	11,400
Exercisable, weighted average remaining life (Year)	5 years 8 months 12 days
Exercisable, weighted average exercise price (in dollars per share)	$ 56.33
Range Five [Member]
Exercise price range, lower limit (in dollars per share)	60
Exercise price range, upper limit (in dollars per share)	$ 69.99
Outstanding options, number outstanding (in shares) | shares	52,646
Outstanding options, weighted average remaining life (Year)	3 years 9 months 18 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 63.14
Exercisable, number outstanding (in shares) | shares	52,646
Exercisable, weighted average remaining life (Year)	3 years 9 months 18 days
Exercisable, weighted average exercise price (in dollars per share)	$ 63.14
Range Six [Member]
Exercise price range, lower limit (in dollars per share)	70
Exercise price range, upper limit (in dollars per share)	$ 79.99
Outstanding options, number outstanding (in shares) | shares	19,075
Outstanding options, weighted average remaining life (Year)	1 year 9 months 18 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 73.22
Exercisable, number outstanding (in shares) | shares	19,075
Exercisable, weighted average remaining life (Year)	1 year 9 months 18 days
Exercisable, weighted average exercise price (in dollars per share)	$ 73.22
Range Seven [Member]
Exercise price range, lower limit (in dollars per share)	80
Exercise price range, upper limit (in dollars per share)	$ 89.99
Outstanding options, number outstanding (in shares) | shares	3,650
Outstanding options, weighted average remaining life (Year)	2 years 10 months 24 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 84.15
Exercisable, number outstanding (in shares) | shares	3,650
Exercisable, weighted average remaining life (Year)	2 years 10 months 24 days
Exercisable, weighted average exercise price (in dollars per share)	$ 84.14
Range Eight [Member]
Exercise price range, lower limit (in dollars per share)	90
Exercise price range, upper limit (in dollars per share)	$ 99.99
Outstanding options, number outstanding (in shares) | shares	12,625
Outstanding options, weighted average remaining life (Year)	1 year 9 months 18 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 93.38
Exercisable, number outstanding (in shares) | shares	12,625
Exercisable, weighted average remaining life (Year)	1 year 9 months 18 days
Exercisable, weighted average exercise price (in dollars per share)	$ 93.38
Range Nine [Member]
Exercise price range, lower limit (in dollars per share)	100
Exercise price range, upper limit (in dollars per share)	$ 125.60
Outstanding options, number outstanding (in shares) | shares	2,450
Outstanding options, weighted average remaining life (Year)	3 years 3 months 18 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 107.97
Exercisable, number outstanding (in shares) | shares	2,450
Exercisable, weighted average remaining life (Year)	3 years 3 months 18 days
Exercisable, weighted average exercise price (in dollars per share)	$ 17.97

Note 6 - Stock-based Compensa_6

Note 6 - Stock-based Compensation and Option Plans - Restricted Stock Activity (Details) - Restricted Stock [Member] - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Unvested (in shares)	89	42
Unvested, weighted average grant date fair value (in dollars per share)	$ 31.67	$ 43.07
Granted (in shares)	0	66
Granted, weighted average grant date fair value (in dollars per share)	$ 0	$ 26.75
Vested/Released (in shares)	(33)	(14)
Vested/Released, weighted average grant date fair value (in dollars per share)	$ 32.11	$ 42.98
Forfeited/Expired (in shares)	(15)	(5)
Forfeited/Expired, weighted average grant date fair value (in dollars per share)	$ 31.52	$ 30.71
Unvested (in shares)	41	89
Unvested, weighted average grant date fair value (in dollars per share)	$ 31.37	$ 31.67

Note 6 - Stock-based Compensa_7

Note 6 - Stock-based Compensation and Option Plans - Performance Based Restricted Stock Awards (Details) - Performance Shares [Member] - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Unvested (in shares)	57	20
Unvested, weighted average grant date fair value (in dollars per share)	$ 33.86	$ 47.40
Granted (in shares)	0	40
Granted, weighted average grant date fair value (in dollars per share)	$ 0	$ 26.80
Vested/Released (in shares)	0	0
Vested/Released, weighted average grant date fair value (in dollars per share)	$ 0	$ 0
Forfeited/Expired (in shares)	(13)	(3)
Forfeited/Expired, weighted average grant date fair value (in dollars per share)	$ 34.29	$ 30.38
Unvested (in shares)	44	57
Unvested, weighted average grant date fair value (in dollars per share)	$ 33.73	$ 33.86

Note 6 - Stock-based Compensa_8

Note 6 - Stock-based Compensation and Option Plans - Warrants (Details) - Warrant Issued to Lender [Member] - $ / shares	Dec. 31, 2020	Oct. 19, 2020	Aug. 11, 2020
Exercise Price (in dollars per share)	$ 0.20	$ 0.20	$ 0.01
Number of Shares (in shares)	1,672,290	1,672,290	33,445,792

Note 7 - Income Taxes (Details

Note 7 - Income Taxes (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Deferred Tax Assets, Valuation Allowance, Total	$ 117,270	$ 80,076
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued, Total	$ 0	$ 0
Open Tax Year	2014 2015 2016 2017 2018 2019 2020
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%
Post 2018 [Member] | Domestic Tax Authority [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards, Total	$ 140,000
Earliest Tax Year [Member]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2022
Latest Tax Year [Member]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
Pre 2018 [Member] | Domestic Tax Authority [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards, Total	$ 245,200

Note 7 - Income Taxes - Deferre

Note 7 - Income Taxes - Deferred Tax Liabilities and Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Hedge contracts	$ 4,299	$ 0
Other	2,137	3,158
Total deferred tax liabilities	6,436	3,158
US full cost pool	35,500	9,595
Depletion carryforward	461	3,722
U.S. net operating loss carryforward	84,927	68,250
Alternative minimum tax credit	0	6
Hedge contracts	0	1,661
Interest disallowed	2,818	0
Total deferred tax assets	123,706	83,234
Valuation allowance for deferred tax assets	(117,270)	(80,076)
Net deferred tax assets	6,436	3,158
Net deferred tax	$ 0	$ 0

Note 7 - Income Taxes - Provisi

Note 7 - Income Taxes - Provision (Benefit) for Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Federal	$ 0	$ 0
State	0	0
Federal	$ 0	$ 0

Note 7 - Income Taxes - Reconci

Note 7 - Income Taxes - Reconciliation of Income Tax (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Tax benefit at U.S. Statutory rates	$ 38,749	$ 13,651
Change in deferred tax asset valuation allowance	(37,193)	(12,767)
Alternative minimum tax expense	0	(745)
Expired capital loss carryover	0	(3,966)
Permanent differences	(276)	(403)
Return to provision estimated revision	(3,069)	341
State income taxes, net of federal effect	1,789	3,892
Other	$ 0	$ (3)

Note 9 - Earnings Per Share (De

Note 9 - Earnings Per Share (Details Textual) shares in Millions	12 Months Ended
	Dec. 31, 2020shares
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount (in shares)	4

Note 9 - Earnings Per Share - C

Note 9 - Earnings Per Share - Computation of Basic and Diluted Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019
Net loss	$ (69,094)	$ (73,615)	$ (83,256)	$ 41,443	$ (68,268)	$ 17,041	$ 11,678	$ (25,455)	$ (184,522)	$ (65,004)
Basic (in shares)									8,382	8,312
Effect of dilutive securities: Stock options, restricted shares and performance based shares (in shares)									0	3
Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and performance based shares (in shares)									8,382	8,315
Net (loss) income per common share - basic (in dollars per share)	$ (8.21)	$ (8.80)	$ (10)	$ 4.80	$ (8.20)	$ 2	$ 1.40	$ (3)	$ (22.01)	$ (7.82)
Net (loss) income per common share - diluted (in dollars per share)	$ (8.21)	$ (8.80)	$ (10)	$ 4.80	$ (8.20)	$ 2	$ 1.40	$ (3)	$ (22.01)	$ (7.82)

Note 10 - Benefit Plans (Detail

Note 10 - Benefit Plans (Details Textual)	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Deferred Compensation Arrangement with Individual, Contributions by Employer	$ 142,820	$ 284,905
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay		1.00%
Defined Contribution Plan, Employer Matching Contribution, Amount of Cents Per Dollar Increase for Each Additional Percentage Point	50
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	5.00%
Defined Contribution Plan Employee Contribution Limit Below 50 Years of Age	$ 19,500	$ 19,000
Defined Contribution Plan Employee Contribution Limit 50 Years of Age or Older	$ 26,000	$ 25,000

Note 11 - Hedging Program and_3

Note 11 - Hedging Program and Derivatives (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Derivative Asset, Total	$ 19,920	$ 4,253
Commodity Contract [Member]
Derivative Asset, Total	19,400
Commodity Contract [Member] | (Gain) Loss on Derivative Contracts [Member]
Gain (Loss) on Sale of Derivatives	42,900	(26,800)
Commodity Closed Contracts [Member] | (Gain) Loss on Derivative Contracts [Member]
Gain (Loss) on Sale of Derivatives	17,500	(6,000)
Commodity Open Contracts [Member] | (Gain) Loss on Derivative Contracts [Member]
Gain (Loss) on Sale of Derivatives	$ 25,400	$ (20,800)

Note 11 - Hedging Program and_4

Note 11 - Hedging Program and Derivatives - Derivative Contracts (Details)	12 Months Ended
	Dec. 31, 2020$ / bbl
Fixed Swap 2021 [Member]
Daily volume	2,889
Swap price (in USD per Barrel of Oil)	57.62
Fixed Swap 2022 [Member]
Daily volume	2,412
Swap price (in USD per Barrel of Oil)	50.60
Fixed Swap 2023 [Member]
Daily volume	1,498
Swap price (in USD per Barrel of Oil)	50.60
Fixed Swap 2024 [Member]
Daily volume	1,585
Swap price (in USD per Barrel of Oil)	50.60

Note 11 - Hedging Program and_5

Note 11 - Hedging Program and Derivatives - Impact of Derivative Contracts on Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Derivative asset, current	$ 9,639	$ 83
Derivative liability, current	480	10,688
Derivative asset, long-term	10,281	4,170
Derivative liability, long-term	0	999
Derivative Asset, Total	19,920	4,253
Derivative liability	480	11,687
Commodity Contract [Member]
Derivative Asset, Total	19,400
Commodity Contract [Member] | Derivative Assets Current [Member]
Derivative asset, current	9,639	83
Commodity Contract [Member] | Derivative Liabilities Current [Member]
Derivative liability, current	480	10,688
Commodity Contract [Member] | Derivative Assets Noncurrent [Member]
Derivative asset, long-term	10,281	4,170
Commodity Contract [Member] | Derivative Liabilities Noncurrent [Member]
Derivative liability, long-term	$ 0	$ 999

Note 12 - Financial Instrumen_3

Note 12 - Financial Instruments - Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Derivative assets	$ 19,920	$ 4,253
Derivative liabilities	480	11,687
Fair Value, Recurring [Member]
Derivative assets	19,920	4,253
Derivative liabilities	480	11,687
Fair Value, Recurring [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets	19,920	4,253
Derivative liabilities	480	5,583
Fair Value, Recurring [Member] | Basis Swap [Member]
Derivative assets		0
Derivative liabilities		6,104
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets	0	0
Derivative liabilities	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets	0	0
Derivative liabilities	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Basis Swap [Member]
Derivative assets		0
Derivative liabilities		0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets	19,920	4,253
Derivative liabilities	480	5,583
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets	19,920	4,253
Derivative liabilities	480	5,583
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Basis Swap [Member]
Derivative assets		0
Derivative liabilities		0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets	0	0
Derivative liabilities	0	6,104
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets	0	0
Derivative liabilities	$ 0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Basis Swap [Member]
Derivative assets		0
Derivative liabilities		$ 6,104

Note 12 - Financial Instrumen_4

Note 12 - Financial Instruments - Recurring Fair Value Measurements Using Significant Unobservable Inputs (Details) - Fair Value, Inputs, Level 3 [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2020USD ($)
Fair value	$ (6,104)
Changes in market value	4,577
Settlements during the period	1,527
Fair value	$ 0

Note 13 - Lease Accounting St_3

Note 13 - Lease Accounting Standard (Details Textual)	Dec. 31, 2020
Lease for Residence in North Dakota [Member]
Lessee, Operating Lease, Term of Contract (Year)	5 years

Note 13 - Lease Accounting St_4

Note 13 - Lease Accounting Standard - Total Lease Expense (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019
Operating lease cost		$ 114	$ 478
Short-term lease expense	[1]	2,183	1,992
Total lease expense		$ 2,297	$ 2,470
Weighted Average Remaining Lease Term (in years) (Year)		10 years 8 months 4 days	8 years 7 months 28 days
Weighted Average Discount Rate		6.00%	6.00%
Cash paid for amounts included in the measurement of lease liabilities		$ 114	$ 478
Right of Use assets added in exchange for lease obligations (since adoption)		125	770
Drilling Rig [Member]
Short-term lease expense	[2]	$ 973	$ 4,900
[1]	Short-term lease expense represents expense related to leases with a contract term of 12 months or less.
[2]	These short-term lease costs are related to leases with a contract term of 12 months or less which are related to drilling rigs and are capitalized as part of natural gas and oil properties on our balance sheet.

Note 13 - Lease Accounting St_5

Note 13 - Lease Accounting Standard - Balance Sheet Information (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Operating lease Right of Use asset	$ 228	$ 327
Operating lease liability - current	53	98
Operating lease liabilities - long-term	$ 150	$ 203

Note 13 - Lease Accounting St_6

Note 13 - Lease Accounting Standard - Lease Liabilities Maturity (Details) $ in Thousands	Dec. 31, 2020USD ($)
2021	$ 63
2022	48
2023	41
2024	28
2025	4
Thereafter	98
Total lease payments	282
Less imputed interest	(79)
Total lease liability	$ 203

Note 14 - Subsequent Events (De

Note 14 - Subsequent Events (Details Textual) - USD ($) $ in Thousands	May 04, 2020	Mar. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Apr. 30, 2021	Apr. 16, 2021	Apr. 12, 2021
Gain (Loss) on Extinguishment of Debt, Total			$ (4,108)	$ 0
Subsequent Event [Member] | Morgan Stanley [Member]
Termination Value of Hedge Contracts							$ 9,100
Paycheck Protection Program, CARES Act [Member]
Proceeds from Issuance of Long-term Debt, Total	$ 1,400		$ 1,384	$ 0
Paycheck Protection Program, CARES Act [Member] | Subsequent Event [Member]
Gain (Loss) on Extinguishment of Debt, Total		$ 1,400
Second Lien Credit Facility [Member] | Subsequent Event [Member]
Debt Instrument, Interest Rate, Additional Default Interest						3.00%
First Lien Credit Facility [Member] | Subsequent Event [Member] | Obligations from Terminated Hedging Arrangements [Member]
Termination Value of Hedge Contracts					$ 9,900
Debt Instrument, Interest Rate, Stated Percentage					6.70%
First Lien Credit Facility [Member] | Subsequent Event [Member] | Morgan Stanley [Member]
Percentage of Outstanding Obligations							3.70%
First Lien Credit Facility [Member] | Subsequent Event [Member] | Morgan Stanley [Member] | Obligations from Terminated Hedging Arrangements [Member]
Termination Value of Hedge Contracts					$ 9,100

Note 15 - Quarterly Results o_3

Note 15 - Quarterly Results of Operations (Unaudited) - Results of Operations for Fiscal Quarters (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019
Net revenue	$ 12,729	$ 12,595	$ 1,993	$ 15,726	$ 28,276	$ 31,536	$ 34,820	$ 34,514	$ 43,043	$ 129,146
Operating income (loss)	(51,502)	(56,661)	(61,474)	(29,781)	(49,412)	8,053	8,935	6,708	(199,418)	(25,716)
Net (loss)	$ (69,094)	$ (73,615)	$ (83,256)	$ 41,443	$ (68,268)	$ 17,041	$ 11,678	$ (25,455)	$ (184,522)	$ (65,004)
Net income (loss) per common share - basic (in dollars per share)	$ (8.21)	$ (8.80)	$ (10)	$ 4.80	$ (8.20)	$ 2	$ 1.40	$ (3)	$ (22.01)	$ (7.82)
Net income (loss) per common share - diluted (in dollars per share)	$ (8.21)	$ (8.80)	$ (10)	$ 4.80	$ (8.20)	$ 2	$ 1.40	$ (3)	$ (22.01)	$ (7.82)

Note 16 - Supplemental Oil an_3

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) (Details Textual) bbl in Thousands, Boe in Thousands	12 Months Ended
	Dec. 31, 2020Boebbl	Dec. 31, 2019Boebbl
Proved Developed and Undeveloped Reserves Production, Energy (Barrel of Oil Equivalent)	1,801	3,616
Other Miscellaneous Asset [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy (Barrel of Oil Equivalent)		18
Change in Projections [Member]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates (Barrel of Oil) | bbl	(56)	(8,790)
Conversion of Proved Undeveloped Locations to Probable Undeveloped Reserves [Member] | Wolfcamp A1 and Bone Spring Locations in Ward County, Texas [Member]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates (Barrel of Oil) | bbl	(17,616)
Conversion of Proved Undeveloped Locations to Probable Undeveloped Reserves [Member] | McKenzie County, ND [Member]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates (Barrel of Oil) | bbl	(5,153)
Conversion of Proved Undeveloped Locations to Probable Undeveloped Reserves [Member] | Delaware Locations in Ward County, TX [Member]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates (Barrel of Oil) | bbl	(2,300)
Conversion of Proved Undeveloped Locations to Probable Undeveloped Reserves [Member] | Ward County, Texas [Member]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates (Barrel of Oil) | bbl		(13,402)
Addition of Proved Undeveloped Non-operated Locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		2
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy (Barrel of Oil Equivalent)		3,776
Three Forks Location in McKenzie County, North Dakota [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy (Barrel of Oil Equivalent)		14,333
Gulf Coast Area Holdings [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy (Barrel of Oil Equivalent)		1,839
Permian Locations in Marion, Pecos, and Reeves Counties, Texas [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy (Barrel of Oil Equivalent)		42
Number of Non-operated Holdings Sold		14
Bakken Area Holdings [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy (Barrel of Oil Equivalent)		1,268

Note 16 - Supplemental Oil an_4

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Proved oil and gas properties	$ 1,167,333	$ 1,162,094
Unproved properties	0	0
Total	1,167,333	1,162,094
Accumulated depreciation, depletion, amortization and impairment	(1,060,649)	(851,107)
Net capitalized costs	$ 106,684	$ 310,987

Note 16 - Supplemental Oil an_5

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Cost Incurred (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Development costs	$ 5,238	$ 92,884
Exploration costs	0	0
Property acquisition costs	0	0
Costs Incurred, Acquisition of Oil and Gas Properties, Total	$ 5,238	$ 92,884

Note 16 - Supplemental Oil an_6

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Results of Operations (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2020USD ($)$ / bbl	Dec. 31, 2019USD ($)$ / bbl
Revenues	$ 42,984	$ 128,992
Production costs	(21,090)	(38,229)
Depreciation, depletion and amortization	(22,679)	(51,041)
Accretion of future site restoration	(414)	(436)
Proved property impairment	(186,980)	(51,293)
Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs)	$ (188,179)	$ (12,007)
Depletion rate per barrel of oil equivalent (in USD per Barrel of Oil) | $ / bbl	12.59	14.12

Note 16 - Supplemental Oil an_7

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Proved Developed and Undeveloped Reserves (Details) - bbl bbl in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Oil [Member]
Balance (Barrel of Oil)	36,279	42,237
Revisions of previous estimates (Barrel of Oil)	(16,922)	(15,616)
Extensions and discoveries (Barrel of Oil)	0	13,477
Purchases of minerals in place (Barrel of Oil)		0
Sales of minerals in place (Barrel of Oil)		(1,431)
Production (Barrel of Oil)	(1,132)	(2,388)
Removal of PUDs (Barrel of Oil)	(8,687)
Balance (Barrel of Oil)	9,538	36,279
Proved developed reserves (Barrel of Oil)	9,538	10,964
Proved undeveloped reserves (Barrel of Oil)	0	25,315
Natural Gas Liquids [Member]
Balance (Barrel of Oil)	8,972	10,034
Revisions of previous estimates (Barrel of Oil)	(3,549)	(2,713)
Extensions and discoveries (Barrel of Oil)	0	2,285
Purchases of minerals in place (Barrel of Oil)		0
Sales of minerals in place (Barrel of Oil)		(86)
Production (Barrel of Oil)	(313)	(548)
Removal of PUDs (Barrel of Oil)	(1,922)
Balance (Barrel of Oil)	3,188	8,972
Proved developed reserves (Barrel of Oil)	3,187	2,699
Proved undeveloped reserves (Barrel of Oil)	0	6,273
Natural Gas [Member]
Balance (Barrel of Oil)	66,665	89,744
Revisions of previous estimates (Barrel of Oil)	(27,921)	(23,178)
Extensions and discoveries (Barrel of Oil)	0	14,073
Purchases of minerals in place (Barrel of Oil)		0
Sales of minerals in place (Barrel of Oil)		(9,898)
Production (Barrel of Oil)	(2,135)	(4,076)
Removal of PUDs (Barrel of Oil)	(12,291)
Balance (Barrel of Oil)	24,318	66,665
Proved developed reserves (Barrel of Oil)	24,318	21,439
Proved undeveloped reserves (Barrel of Oil)	0	45,226
Oil Equivalents [Member]
Balance (Barrel of Oil)	56,362	67,228
Revisions of previous estimates (Barrel of Oil)	(25,125)	(22,192)
Extensions and discoveries (Barrel of Oil)	0	18,109
Purchases of minerals in place (Barrel of Oil)		0
Sales of minerals in place (Barrel of Oil)		(3,167)
Production (Barrel of Oil)	(1,801)	(3,616)
Removal of PUDs (Barrel of Oil)	(12,658)
Balance (Barrel of Oil)	16,778	56,362
Proved developed reserves (Barrel of Oil)	16,778	17,237
Proved undeveloped reserves (Barrel of Oil)	0	39,125

Note 16 - Supplemental Oil an_8

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Future Net Cash Inflows (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Future cash inflows	$ 345,869	$ 1,890,579
Future production costs	(166,781)	(598,714)
Future development costs	(6,291)	(544,111)
Future income tax expense	0	0
Future net cash flows	172,797	747,754
Discount	(66,113)	(440,142)
Standardized Measure of discounted future net cash relating to proved reserves	$ 106,684	$ 307,612	$ 651,884

Note 16 - Supplemental Oil an_9

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Changes in the Standardized Measure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Standardized Measure, beginning of year	$ 307,612	$ 651,884
Sales and transfers of oil and gas produced, net of production costs	(21,894)	(90,763)
Net change in prices and development and production costs from prior year	(96,688)	(218,092)
Extensions, discoveries, and improved recovery, less related costs	0	98,780
Sales of minerals in place	0	(17,276)
Removal of PUDs	(80,416)	0
Revisions of previous estimates	(159,613)	(227,477)
Change in timing and other	126,922	(13,744)
Change in future income tax expense	0	59,112
Accretion of discount	30,761	65,188
Standardized Measure, end of year	$ 106,684	$ 307,612

Note 16 - Supplemental Oil a_10

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Oil and Gas Prices (Details)		12 Months Ended
		Dec. 31, 2020$ / bbl$ / BTU	Dec. 31, 2019$ / bbl$ / BTU
Oil (per Bbl) (1) (in USD per Barrel of Oil)	[1]	39.54	55.73
Gas (per Mmbtu) (2) (in USD per British Thermal Unit) | $ / BTU	[2]	2.03	2.54
Oil (per Bbl) (3) (in USD per Barrel of Oil)	[3]	37.05	52.14
Gas (per Mmbtu) (4) (in USD per British Thermal Unit) | $ / BTU	[4]	0.27	0.63
NGL's (per Bbl) (5) (in USD per Barrel of Oil)	[5]	1.37	3.48
[1]	The quoted oil price for the year ended December 31 of each year, 2019 and 2020 is the 12-month unweighted average first-day-of-the-month West Texas Intermediate spot price for each month of 2019 and 2020.
[2]	The quoted gas price for the year ended December 31, 2019 and 2020 is the 12-month unweighted average first-day-of-the-month Henry Hub spot price for each month of 2019 and 2020.
[3]	The oil price is the realized price at the wellhead as of December 31 of each year after the appropriate differentials have been applied.
[4]	The gas price is the realized price at the wellhead as of December 31 of each year after the appropriate differentials have been applied.
[5]	The NGL price is the realized price as of December 31 of each year after the appropriate differentials have been applied.