Abraxas Petroleum (AXAS) 10-K 15 Mar 19 2018 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Mar. 08, 2019	Jun. 30, 2018
Document Information [Line Items]
Entity Registrant Name	ABRAXAS PETROLEUM CORP
Entity Central Index Key	0000867665
Trading Symbol	axas
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding (in shares)		166,934,860
Entity Public Float			$ 470,774,656
Entity Shell Company	false
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	FY
Amendment Flag	false

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 867	$ 1,618
Accounts receivable:
Joint owners, net	17,110	14,218
Oil and gas production sales	21,991	17,789
Other	535	86
Total accounts receivable	39,636	32,093
Derivative asset - short-term	9,602
Other current assets	626	778
Total current assets	50,731	34,489
Proved oil and gas properties	1,091,905	923,237
Other property and equipment	39,453	39,136
Total	1,131,358	962,373
Less accumulated depreciation, depletion, amortization and impairment	(768,140)	(724,606)
Total property and equipment - net	363,218	237,767
Derivative asset, long-term	10,527
Deferred financing fees - net	1,149	1,285
Other assets	265	265
Total assets	425,890	273,806
Current liabilities:
Accounts payable	39,571	45,570
Joint interest oil and gas production payable	23,063	11,502
Accrued interest	335	140
Other accrued liabilities	511	539
Derivative liability, current	616	10,837
Current maturities of long-term debt	267	262
Total current liabilities	64,363	68,850
Long-term debt - less current maturities	183,091	87,354
Other liabilities		132
Derivative liability, long-term	4,434	2,387
Future site restoration	7,492	8,775
Total liabilities	259,380	167,498
Commitments and contingencies (Note 9)
Stockholders' Equity
Preferred stock, par value $0.01 per share - authorized 1,000,000 shares; - 0- shares issued and outstanding
Common stock, par value $0.01 per share, authorized 400,000,000 shares; 165,889,901 and 166,713,784 issued and outstanding at December 31, 2017 and 2018, respectively	1,667	1,659
Additional paid-in capital	417,844	415,471
Accumulated deficit	(253,001)	(310,822)
Total stockholders' equity	166,510	106,308
Total liabilities and stockholders' equity	$ 425,890	$ 273,806

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - $ / shares	Dec. 31, 2018	Dec. 31, 2017
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)	400,000,000	400,000,000
Common stock, issued (in shares)	166,713,784	165,889,901
Common stock, outstanding (in shares)	166,713,784	165,889,901

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues:
Other	$ 137	$ 75	$ 62
Total Revenue	149,167	86,264	56,555
Operating costs and expenses
Lease operating	24,300	15,197	18,205
Production and ad valorem taxes	12,023	7,228	5,454
Rig expense			664
Depreciation, depletion, amortization and accretion	43,275	26,677	24,922
Proved property impairment			67,626
General and administrative (including stock-based compensation of $3,194, $3,238 and $2,366, respectively)	12,041	16,276	13,562
Total operating costs and expenses	91,639	65,378	130,433
Operating (loss) income	57,528	20,886	(73,878)
Other (income) expense:
Interest income	(1)	(1)	(1)
Interest expense	7,053	2,497	3,828
Amortization of deferred financing fees	440	423	1,019
Loss (gain) on derivative contracts	(8,060)	1,849	18,028
Loss (gain) on sale of non-oil and gas assets	181	(102)	(374)
Other	94	214
Total other (income) expense	(293)	4,880	22,500
Income (loss) before income tax	57,821	16,006	(96,378)
Income tax (expense) benefit
Net income (loss)	$ 57,821	$ 16,006	$ (96,378)
Net income (loss) per common share - basic (in dollars per share)	$ 0.35	$ 0.10	$ (0.79)
Net income (loss) per common share - diluted (in dollars per share)	$ 0.34	$ 0.10	$ (0.79)
Weighted average shares outstanding
Basic (in shares)	165,635	161,141	122,132
Diluted (in shares)	167,689	162,844	122,132
Oil Revenues [Member]
Revenues:
Revenues	$ 132,904	$ 73,584	$ 50,965
Gas Revenues [Member]
Revenues:
Revenues	7,854	6,898	3,978
Natural Gas Liquids Revenues [Member]
Revenues:
Revenues	$ 8,272	$ 5,707	$ 1,550

Consolidated Statements of Op_2

Consolidated Statements of Operations (Parentheticals) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Stock-based Compensation	$ 2,366	$ 3,238	$ 3,194

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, 2015	106,346,001
Balance at Dec. 31, 2015	$ 1,063	$ 313,852	$ (230,450)	$ 84,465
Net (loss) income			(96,378)	(96,378)
Stock issuance (in shares)	28,750,000
Stock issuance	$ 287	26,848		27,135
Stock issued for compensation (in shares)	41,102
Stock issued for compensation		40		40
Stock-based compensation		3,194		3,194
Stock options exercised (in shares)	55,716
Stock options exercised	$ 1	48		49
Restricted stock issued, net of forfeitures (in shares)	(98,802)
Restricted stock issued, net of forfeitures
Balance (in shares) at Dec. 31, 2016	135,094,017
Balance at Dec. 31, 2016	$ 1,351	343,982	(326,828)	18,505
Net (loss) income			16,006	16,006
Stock issuance (in shares)	28,750,000
Stock issuance	$ 288	64,936		65,224
Stock-based compensation		3,238		3,238
Stock options exercised (in shares)	2,634
Stock options exercised
Restricted stock issued, net of forfeitures (in shares)	43,250
Restricted stock issued, net of forfeitures
Stock issued for acquisition of oil and gas properties (in shares)	2,000,000
Stock issued for acquisition of oil and gas properties	$ 20	3,315		$ 3,335
Balance (in shares) at Dec. 31, 2017	165,889,901			165,889,901
Balance at Dec. 31, 2017	$ 1,659	415,471	(310,822)	$ 106,308
Net (loss) income			57,821	57,821
Stock-based compensation		2,366		2,366
Stock options exercised (in shares)	150,327
Stock options exercised	$ 1	13		14
Restricted stock issued, net of forfeitures (in shares)	673,556
Restricted stock issued, net of forfeitures	$ 7	(6)		$ 1
Balance (in shares) at Dec. 31, 2018	166,713,784			166,713,784
Balance at Dec. 31, 2018	$ 1,667	$ 417,844	$ (253,001)	$ 166,510

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Activities:
Net (loss) income	$ 57,821	$ 16,006	$ (96,378)
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Loss (gain) on sale of non-oil and gas assets	181	(102)	(374)
Net loss (gain) on derivative contracts	(8,060)	1,849	18,028
Net cash settlements received (paid) on derivative contracts	(20,241)	2,450	1,790
Monetization of derivative contracts			14,370
Depreciation, depletion and amortization	42,759	26,226	24,431
Proved property impairment			67,626
Amortization of deferred financing fees	440	423	1,019
Accretion expense and other	516	451	491
Stock-based Compensation	2,366	3,238	3,194
Non-cash compensation			40
Changes in operating assets and liabilities:
Accounts receivable	(7,543)	(18,569)	(4,018)
Other assets	18	155	627
Accounts payable	11,576	6,231	(3,535)
Accrued expenses	167	(235)	(439)
Net cash provided by operating activities	80,000	38,123	26,872
Investing Activities
Capital expenditures, including purchase and development of properties	(179,509)	(108,236)	(31,663)
Proceeds from the sale of oil and gas properties	3,279	16,979	13,570
Proceeds from the sale of non-oil and gas assets	26	204	4,022
Net cash used in investing activities	(176,204)	(91,053)	(14,071)
Financing Activities
Proceeds from exercise of stock options and restricted stock	15		49
Proceeds from issuance of common stock, net of offering cost of $1.6 million and $3.8 million, respectively		65,224	27,135
Proceeds from long-term borrowings	127,000	82,000	22,000
Payments of long-term borrowings	(31,258)	(91,786)	(65,330)
Deferred financing fees	(304)	(890)	(195)
Net cash (used in) provided by financing activities	95,453	54,548	(16,341)
(Decrease) increase in cash and cash equivalents	(751)	1,618	(3,540)
Cash and cash equivalents at beginning of period	1,618		3,540
Cash and cash equivalents at end of period	867	1,618
Supplemental disclosure of cash flow information:
Interest paid	6,858	2,401	3,899
Income tax paid
Non-cash investing and financing activities
Change in asset retirement obligation cost and liabilities	1	1,252	285
Properties classified as held for sale			9,685
Asset retirement obligations associated with property acquisitions and dispositions, net	(1,799)	(1,551)	(1,832)
Issuance of stock for acquisition of oil and gas properties		3,335
Change in capital expenditures included in accounts payable	$ (6,014)	$ 23,507

Consolidated Statements of Ca_2

Consolidated Statements of Cash Flows (Parentheticals) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Offering costs		$ 3.8	$ 1.6

Note 1 - Organization and Signi

Note 1 - Organization and Significant Accounting Policies	12 Months Ended
	Dec. 31, 2018
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 in three 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”). Rig Accounting In accordance with SEC Regulation S- X, no not 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 prior year balances have been reclassified for consistency with current year classifications. Such reclassifications had 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 $0.4 $0.5 December 31, 2017 2018, 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%, not No not 2016 $67.6 December 31, 2017 2018, not Other Property and Equipment Other property and equipment are recorded on the basis of 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, 2016, 2017 2018, $3.2 $3.2 $2.4 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: 2017 2018 Beginning future site restoration obligation $ 8,623 $ 8,775 New wells placed on production and other 1,088 612 Deletions related to property disposals and plugging costs (1,551 ) (2,270 ) Accretion expense and other 451 516 Revisions and other 164 (141 ) Ending future site restoration obligation $ 8,775 $ 7,492 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. The Company recognizes oil and gas revenues from its interests in producing wells when control has transferred to the purchaser and to the extent the selling price is reasonably determinable. The Company had no December 31, 2017 2018. During 2016, two 71% 2017 three 69% 2018, two 57% 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 $67.3 December 31, 2018. On December 22, 2017, 115 97, 35% 21%, December 22, 2017. December 2017, No. 118 118” one 740, 740” three 740. not 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, 2018. New Accounting Standards and Disclosures In February 2016, 842, Leases 842" 840, Leases 840" 12 not January 2018, 842 not not 840. In July 2018, 842 840. 840 840. The amendments in these ASUs are effective for fiscal years beginning after December 15, 2018, 2016 02 first 2019 842 not The Company has a team, including third 842 twelve $2.0 The Company enters into certain lease agreements in support of its operations for assets such as compressors, a drilling rig, employee housing and office equipment. As of December 31, 2018, not 842 2019, not The Company has made certain accounting policy decisions including that it plans on adopting the short-term lease recognition exemption, account for certain asset classes and has established a balance sheet recognition capitalization threshold. The Company also expects for certain lessee asset classes to elect the practical expedient to not

Note 2 - Impact of ASC 606 Adop

Note 2 - Impact of ASC 606 Adoption	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	2. 606 On January 1, 2018, No. 2014 09, Revenue from Contracts with Customers 2014 09” 2014 09 January 1, 2018 not ASU 2014 09 five For the year ended December 31, 2018, no 2014 09, no January 1, 2018 2014 09.

Note 3 - Revenue From Contracts

Note 3 - Revenue From Contracts With Customers	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Revenue from Contract with Customer [Text Block]	3. 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, 2017 2018. 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, 2016 2017 2018 Oil Gas NGL Oil Gas NGL Oil Gas NGL (In thousands) Operating Region Permian/Delaware Basin $ 3,551 $ 1,672 $ 664 $ 17,722 $ 3,028 $ 1,840 $ 47,175 $ 2,698 $ 2,884 Rocky Mountain $ 40,048 $ 1,070 $ 793 $ 49,670 $ 2,694 $ 3,774 $ 77,664 $ 3,913 $ 5,253 South Texas $ 7,366 $ 1,236 $ 93 $ 6,192 $ 1,176 $ 93 $ 8,065 $ 1,243 $ 135 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, 2017 December 31, 2018, $17.8 $22.0 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, 2018, not

Note 4 - Acquisition and Divest

Note 4 - Acquisition and Divestitures of Properties	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	4. During the year ended December 31, 2018, 2,721 $40.4 $21,000 During 2018, $3.3

Note 5 - Long-term Debt

Note 5 - Long-term Debt	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Long-term Debt [Text Block]	5. The following is a description of the Company’s debt as of December 31, 2017 2018, 2017 2018 (In thousands) Senior secured credit facility $ 84,000 $ 180,000 Real estate lien note 3,616 3,358 87,616 183,358 Less current maturities (262 ) (267 ) Total $ 87,354 $ 183,091 Maturities of long-term debt are as follows: Years ending December 31, (In thousands) 2019 $ 267 2020 280 2021 180,295 2022 310 2023 2,206 Thereafter - Total $ 183,358 Credit Facility The Company has a senior secured credit facility with Société Générale, as administrative agent and issuing lender, and certain other lenders, which we refer to as the credit facility. As of December 31, 2018, $180.0 The credit facility has a maximum commitment of $300.0 December 31, 2018, $200.0 one one may one six one six not may not 5% 5% $300.0 3% x 0.5%, one 1.5% 2.5%, 2.5% 3.5% December 31, 2018, 6.0% Subject to earlier termination rights and events of default, the stated maturity date of the credit facility is May 16, 2021. not Each of the Company's subsidiaries has guaranteed the obligations under the credit facility on a senior secured basis. Obligations under the credit facility are secured by a first 90% 10 Under the credit facility, the Company is subject to customary covenants, including certain financial covenants and reporting requirements. The Company is required to maintain a current ratio, as defined in the credit facility, as of the last day of each quarter of not 1.00 1.00 not 2.50 1.00. not 3.50 1.00. 815 410 20 815 410 20. four 718, 815 410 20 $1.0 12 815 410 20. four . At December 31, 2018, December 31, 2018, 11.94 1.00, 2.14 1.00, 0.96 1.00. December 31, 2018. The credit facility contains a number of other covenants that, among other things, restrict our ability to: • incur or guarantee additional indebtedness; • transfer or sell assets; • create liens on assets; • 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 credit facility also contains certain additional covenants including: • 100% • If the sum of our cash on hand plus liquid investments exceeds $10.0 $10.0 The 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, 2018, Real Estate Lien Note The Company has a real estate lien note secured by a first June 20, 2018 4.9% $35,672. July 20, 2023. December 31, 2017 2018, $3.6 $3.4

Note 6 - Property and Equipment

Note 6 - Property and Equipment	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Property, Plant and Equipment Disclosure [Text Block]	6. The major components of property and equipment, at cost, are as follows: Estimated December 31, Useful life 2017 2018 Years (In thousands) Oil and gas properties (1) $ 923,237 $ 1,091,905 Equipment and other 3-39 15,648 15,369 Drilling rig 15 23,488 24,084 962,373 1,131,358 Accumulated depreciation, depletion, amortization and impairment (724,606 ) (768,140 ) Net Property and Equipment $ 237,767 $ 363,218 ( 1

Note 7 - Stock-based Compensati

Note 7 - Stock-based Compensation and Option Plans	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	7. The Company’s Amended and Restated 2005 12.6 may not 10 may 1 one 2 3 4 Stock Options The Company utilizes a standard option pricing model (Black-Scholes) to measure the fair value of stock options granted to employees and directors. The fair value for these options was estimated at the date of grant using the following weighted average assumptions for 2016, 2017 2018: 2016 2017 2018 Weighted average value per option granted during the period $ 0.68 $ 1.81 $ 1.87 Assumptions: Forfeiture rate (1) 4.2 % 2.0 % 1.7 % Expected dividend yield (2) 0.0 % 0.0 % 0.0 % Volatility (3) 71.1 % 67.6 % 66.5 % Risk free interest rate (4) 1.7 % 2.2 % 2.9 % Expected life (years) (5) 7.0 6.9 7.3 Fair value of options granted (in thousands) $ 2,307 $ 574 $ 841 ______________________ ( 1 The estimated future forfeiture rate is based on the Company’s historical forfeiture rate on similar grants of stock options. ( 2 The dividend yield is based on the fact the Company does not ( 3 The volatility is based on the historical volatility of our stock for a period approximating the expected life. ( 4 The risk-free interest rate is based on the observed U.S. Treasury yield curve in effect at the time the options were granted for a period approximating the expected life of the option. ( 5 The expected life was derived based on a weighting between (a) the Company’s historical exercise and forfeiture activity and (b) the average midpoint between vesting and the contractual term. The Company grants options to its officers, directors, and other employees under various stock option and incentive plans. 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, 2015 6,808 $ 2.89 Granted 2,265 1.02 Exercised (83 ) 1.40 Forfeited/Expired (836 ) 2.84 Options outstanding December 31, 2016 8,154 $ 2.39 Granted 317 1.81 Exercised (5 ) 0.97 Forfeited/Expired (149 ) 3.58 Options outstanding December 31, 2017 8,317 $ 2.35 Granted 300 2.80 Exercised (379 ) 1.71 Forfeited/Expired (689 ) 2.70 Options outstanding December 31, 2018 7,549 $ 2.37 4.9 $ 1.68 Exercisable at end of year 6,479 $ 2.50 4.5 $ 1.78 Other information pertaining to the Company’s stock option activity for the three December 31: 2016 2017 2018 Weighted average grant date fair value of stock options granted (per share) $ 0.68 $ 1.81 $ 1.87 Total fair value of options vested (000's) $ 2,776 $ 2,795 $ 2,054 Total intrinsic value of options exercised (000's) $ 39 $ 5 $ 395 As of December 31, 2018, not $0.5 2019 2021. December 31, 2016, 2017 2018, $2.0 $1.8 $1.4 The following table represents the range of stock option prices and the weighted average remaining life of outstanding options as of December 31, 2018: 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 0.97 - 1.99 3,270,117 4.9 $ 1.26 2,490,367 4.2 $ 1.32 2.00 - 2.99 1,422,975 4.4 $ 2.44 1,319,725 4.0 $ 2.43 3.00 - 3.99 2,212,606 5.4 $ 3.29 2,025,106 5.3 $ 3.30 4.00 - 4.99 544,750 4.2 $ 4.54 544,750 4.2 $ 4.54 5.00 - 5.99 98,000 5.4 $ 5.38 98,000 5.4 $ 5.38 6.00 - 6.28 1,000 5.5 $ 6.28 1,000 5.5 $ 6.28 7,549,448 4.9 $ 2.37 6,478,948 4.5 $ 2.50 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, 2018, not $1.3 2019 2021. December 31, 2016, 2017 2018, $1.2 $1.4 $0.7 The following table is a summary of the Company’s restricted stock activity for the three December 31, 2018: Number of Shares Weighted average grant date fair value Unvested December 31, 2015 1,643,284 $ 3.44 Granted - - Vested/Released (52,017 ) 2.40 Forfeited (98,802 ) 3.63 Unvested December 31, 2016 1,492,465 $ 3.47 Granted 44,000 1.75 Vested/Released (56,340 ) 3.14 Forfeited (750 ) 2.63 Unvested December 31, 2017 1,479,375 $ 3.43 Granted 861,113 2.17 Vested/Released (1,326,250 ) 3.43 Forfeited (187,557 ) 3.22 Unvested December 31, 2018 826,681 $ 2.15 Performance Based Restricted Stock Awards Effective on April 1, 2018, 2005 2021 three zero 200% 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, 2017 - $ - Granted 464 2.37 Vested/Released - - Forfeited (59 ) 2.37 Unvested December 31, 2018 405 $ 2.37 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% As of December 31, 2018, not $0.7 2019 2021. December 31, 2018, $0.2 Director Stock Awards The 2005 2.9 2005 first 25,000 one 100,000 no 100% At December 31, 2018, 10.3 Common Stock Issuance In May 2016, 28.8 $27.1 January 2017, 28.8 $65.2

Note 8 - Income Taxes

Note 8 - Income Taxes	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Income Tax Disclosure [Text Block]	8. 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, 2016 2017 2018 (In thousands) Deferred tax liabilities: Hedge contracts $ - $ - $ 3,167 Assets held for sale 3,390 - - Other 4,431 2,834 2,977 Total deferred tax liabilities 7,821 2,834 6,144 Deferred tax assets: Oil and gas properties 48,436 20,011 4,310 Capital loss carryforwards 7,361 3,015 3,980 Depletion carryforward 5,216 3,174 3,098 U.S. net operating loss carryforward 80,670 53,545 61,309 Alternative minimum tax credit 757 757 757 Hedge contracts 3,135 2,777 - Total deferred tax assets 145,575 83,279 73,454 Valuation allowance for deferred tax assets (137,754 ) (80,445 ) (67,310 ) Net deferred tax assets 7,821 2,834 6,144 Net deferred tax $ - $ - $ - Significant components of the provision (benefit) for income taxes are as follows: Years ended December 31, 2016 2017 2018 (In thousands) Current: Federal $ — $ — $ — State — — — $ — $ — $ — Deferred: Federal $ — $ — $ — $ — $ — $ — At December 31, 2018, $245.2 2018 $46.8 2018 2018 2023 2037, not 100% January 1, 2018, 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, 2018, not 382. $137.8 December 31, 2016, $80.4 December 31, 2017 $67.3 December 31, 2018. The reconciliation of income tax computed at the U.S. federal statutory tax rates to income tax expense is: Years Ended December 31, 2016 2017 2018 (In thousands) Tax (expense) benefit at U.S. Statutory rates $ 33,732 $ (5,602 ) $ (12,142 ) (Increase) decrease in deferred tax asset valuation allowance (34,072 ) 57,309 13,135 Permanent differences (1,133 ) (1,134 ) (500 ) Return to provision estimated revision 1,473 2,494 (470 ) Change in deferred tax rate - (53,125 ) - Other - 58 (23 ) $ - $ - $ - As of December 31, 2016, 2017 2018, n o 2013 2018 New tax legislation, commonly referred to as the Tax Cuts and Jobs Act (H.R. 1 December 22, 2017. ASC740, Accounting for Income Taxes December 31, 2017. 21% not 30% 2017 80% 2017, 100% not may

Note 9 - Commitments and Contin

Note 9 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	9. Operating Leases The Company leases office space in Dickinson, North Dakota, Lusk, Wyoming and Denver, Colorado. During 2016, 2017 2018, $27,165, $27,840, $23,200, October 31, 2018 not 2016 2017 $9,000 December 31, 2017 not 2016 2017 $15,601 $13,837, December 31, 2017 not 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, 2018, not

Note 10 - Earnings Per Share

Note 10 - Earnings Per Share	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Earnings Per Share [Text Block]	10. The following table sets forth the computation of basic and diluted earnings per share: Years ended December 31, 2016 2017 2018 (in thousands, except per share data) Numerator: Net income (loss) $ (96,378 ) $ 16,006 $ 57,821 Denominator for basic earnings per share - weighted-average common shares outstanding 122,132 161,141 165,635 Effect of dilutive securities: Stock options, restricted shares and performance based shares - 1,703 2,054 Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and performance based shares 122,132 162,844 167,689 Net (loss) income per common share - basic $ (0.79 ) $ 0.10 $ 0.35 Net (loss) income per common share - diluted $ (0.79 ) $ 0.10 $ 0.34 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, 2016, 1,635 December 31, 2017 2018, 5,018 4,007

Note 11 - Quarterly Results of

Note 11 - Quarterly Results of Operations (Unaudited)	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Quarterly Financial Information [Text Block]	11. Selected results of operations for each of the fiscal quarters during the years ended December 31, 2017 2018 1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter (In thousands, except per share data) Year Ended December 31, 2017 Net revenue $ 18,802 $ 13,152 $ 24,722 $ 29,588 Operating income $ 4,953 $ 1,260 $ 5,654 $ 9,470 Net income (loss) $ 13,690 $ 7,195 $ (770 ) $ (4,109 ) Net income (loss) per common share - basic $ 0.09 $ 0.04 $ - $ (0.02 ) Net income (loss) per common share - diluted $ 0.09 $ 0.04 $ - $ (0.02 ) Year Ended December 31, 2018 Net revenue $ 40,630 $ 30,916 $ 41,625 $ 35,996 Operating income $ 20,090 $ 10,931 $ 17,735 $ 8,722 Net income (loss) $ 10,779 $ (10,554 ) $ 1,777 $ 55,819 Net income (loss) per common share - basic $ 0.07 $ (0.06 ) $ 0.01 $ 0.34 Net income (loss) per common share - diluted $ 0.06 $ (0.06 ) $ 0.01 $ 0.33

Note 12 - Benefit Plans

Note 12 - Benefit Plans	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Compensation and Employee Benefit Plans [Text Block]	12. The Company has a defined contribution plan ( 401 2016, 2017 2018, $256,309, $330,415 $331,957, 401 first 1% 50 5%. may 2016 2017 $18,000 50 $24,000 50 2018 $18,500 50 $24,500 50

Note 13 - Hedging Program and D

Note 13 - Hedging Program and Derivatives	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Derivative Instruments and Hedging Activities Disclosure [Text Block]	13. 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, 2018 Oil - WTI Contract Periods Daily Volume (Bbl) Swap Price (per Bbl) Fixed Swaps January - December 2019 2,941 $ 56.20 January - December 2020 2,204 $ 54.35 January - December 2021 1,815 $ 60.32 Basis Swaps January - December 2019 4,000 $ 2.98 January - December 2020 4,000 $ 2.98 The following table illustrates the impact of derivative contracts on the Company’s balance sheet: Fair Value Derivative Contracts as of December 31, 2017 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 $ - Derivatives - current $ 10,837 Commodity price derivatives Derivatives - long-term - Derivatives - long-term 2,387 $ - $ 13,224 Fair Value Derivative Contracts as of December 31, 2018 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 $ 9,602 Derivatives - current $ 616 Commodity price derivatives Derivatives - long-term 10,527 Derivatives - long-term 4,434 $ 20,129 $ 5,050 Gains and losses from derivative activities are reflected as “(Gain) loss on derivative contracts” in the accompanying Consolidated Statements of Operations. The net estimated value of our commodity derivative contracts was an asset of approximately $15.1 December 31, 2018. December 31, 2018, $8.1 $19.0 $27.1 December 31, 2017, $1.8 $2.5 $4.3

Note 14 - Financial Instruments

Note 14 - Financial Instruments	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Fair Value Disclosures [Text Block]	14. 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, 2017 2018, 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, 2017 Assets: NYMEX fixed price derivative contracts $ - $ - $ - $ - Total Assets $ - $ - $ - $ - Liabilities: NYMEX fixed price derivative contracts $ - $ 13,208 $ - $ 13,208 NYMEX basis differential swap - - 16 16 Total Liabilities $ - $ 13,208 $ 16 $ 13,224 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, 2018 Assets: NYMEX fixed price derivative contracts $ - $ 18,172 $ - $ 18,172 NYMEX basis differential swap - - 1,957 1,957 Total Assets $ - $ 18,172 $ 1,957 $ 20,129 Liabilities: NYMEX fixed price derivative contracts $ - $ - $ - $ - NYMEX basis differential swap - - 5,050 5,050 Total Liabilities $ - $ - $ 5,050 $ 5,050 The Company’s derivative contracts at December 31, 2018 2. third third not 3. Additional information for the Company's recurring fair value measurements using significant unobservable inputs (Level 3 December 31, 2018. (In thousands) Unobservable inputs at January 1, 2018 $ (16 ) Changes in market value $ (3,093 ) Settlements during the period $ 16 Unobservable inputs at December 31, 2018 $ (3,093 ) There were no 3 2018. Nonrecurring Fair Value Measurements The Company follows the provisions of ASC 820 10 820 10 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 15 - Subsequent Events

Note 15 - Subsequent Events	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Subsequent Events [Text Block]	15. In March 2019, Oil - WTI Contract Periods Daily Volume (Bbl) Swap Price (per Bbl) Fixed Swaps July - December 2019 1,156 $ 58.50 January - December 2020 819 $ 57.65 January - December 2021 236 $ 55.70

Note 16 - Supplemental Oil and

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	16. The accompanying tables (in thousands) presents 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, 2017 2018 Proved oil and gas properties $ 923,237 $ 1,091,905 Unproved properties - - Total 923,237 1,091,905 Accumulated depreciation, depletion, amortization and impairment (706,537 ) (748,773 ) Net capitalized costs $ 216,700 $ 343,132 Cost incurred in oil and gas property acquisition and development activities were as follows for the years ended December 31 ( 2016 2017 2018 Development costs $ 18,262 $ 94,478 $ 131,271 Exploration costs 12,529 8,509 - Property acquisition costs - 31,409 41,465 $ 30,791 $ 134,396 $ 172,736 Results of operations from oil and gas producing activities were as follows for the years ended December 31: 2016 2017 2018 Revenues $ 56,493 $ 86,189 $ 149,030 Production costs (23,659 ) (22,425 ) (36,323 ) Depreciation, depletion and amortization (22,803 ) (25,676 ) (42,237 ) Proved property impairment (67,626 ) - - Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs) $ (57,595 ) $ 38,088 $ 72,488 Depletion rate per barrel of oil equivalent $ 10.08 $ 9.52 $ 11.80 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, 2016, 2017 2018. Oil Oil NGL Gas Equivalents (MBbl) (MBbl) (MMcf) (Mboe) Change in Proved Reserves Balance at December 31, 2015 24,131 6,556 75,027 43,190 Revisions of previous estimates 1,379 2,300 (1,537 ) 3,424 Extensions and discoveries 1,183 157 1,179 1,537 Sales of minerals in place (1,112 ) (6 ) (680 ) (1,232 ) Production (1,372 ) (363 ) (3,160 ) (2,262 ) Balance at December 31, 2016 24,209 8,644 70,829 44,657 Revisions of previous estimates 259 1,269 19,311 4,747 Extensions and discoveries 14,533 2,813 14,534 19,768 Purchases of minerals in place 8 14 1,001 189 Sales of minerals in place (364 ) (289 ) (3,958 ) (1,312 ) Production (1,574 ) (476 ) (3,889 ) (2,698 ) Balance at December 31, 2017 37,071 11,975 97,828 65,351 Revisions of previous estimates (4,206 ) (1,927 ) (2,618 ) (6,570 ) Extensions and discoveries 11,270 1,797 11,475 14,979 Purchases of minerals in place 688 - 1,137 877 Sales of minerals in place (278 ) (1,303 ) (13,491 ) (3,829 ) Production (2,308 ) (508 ) (4,587 ) (3,580 ) Balance at December 31, 2018 42,237 10,034 89,744 67,228 The following is a summary of the changes to the Company’s proved reserves that occurred during 2018: Revisions to prior estimates There was a decrease of 45 2018. thirteen 2 nd 2018, 6,525 no five Extensions, discoveries and other additions The Company added nineteen 8,130 two 838 two 1,523 five 2,670 2018 three 1,692 six 126 Purchases: In the Wolfcamp/3 rd 2018 four 877 Sales: The Company sold substantially all its holdings in the Ira Area accounting for 203 one two 3,558 68 Production: The Company produced 3,580 2018. The following is a summary of the changes to the Company’s proved reserves that occurred during 2017: Revisions to prior estimates There was an increase of 621 2017. 1,951 2,698 2017. seven no five 523 Extensions, discoveries and other additions The Company added three 1,229 three 2017 2,028 27 four two 11,928 ten 2017 4,343 240 Purchases The company purchased wells and acquired additional interest in existing wells which added 189 Sales: The Company sold substantially all of its holdings in the Powder River Basin of Wyoming during 2017. 1,312 Production The Company produced 2,698 2017. The following is a summary of the changes to the Company’s proved reserves that occurred during 2016: Revisions to prior estimates An increase of 5,005 1,360 16 2H two 670 16 2H. 2,271 Extensions, discoveries and other additions The Company added the Caprito 99 302H 449 five 805 265 eight 18 Sales The Company sold all its holdings in the Portilla Field in San Patricio County, Texas, and in the Brooks Draw Field in Converse County, Wyoming, during 2016. 1,232 Production The Company produced 2,262 2016. The following table presents the Company's estimate of its net proved developed and undeveloped oil and gas reserves as of December 31, 2016, 2017 2018: Total Oil OIl NGL Gas Equilavents (MBbl) (MBbl) (MMcf) (Mboe) Proved Developed Reserves: December 31, 2016 7,818 2,568 27,792 15,018 December 31, 2017 10,820 3,794 39,974 21,720 December 31, 2018 13,586 3,804 43,271 24,602 Proved Undeveloped Reserves: December 31, 2016 16,391 6,076 43,037 29,639 December 31, 2017 25,808 8,181 57,854 43,631 December 31, 2018 28,651 6,230 46,473 42,626 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 Company with the assistance of an independent petroleum engineering firm, DeGolyer & MacNaughton, as of December 31, 2016, 2017 December 31, 2018, The following information has been prepared in accordance with SEC rules and accounting standards based on the 12 first No. 2010 03, 932 not 2016, 2017, 2018, The technical personnel responsible for preparing the reserve estimates at LaRoche Petroleum Consultants 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. LaRoche Petroleum Consultants is an independent firm of petroleum engineers, geologists, geophysicists, and petrophysicists; they do not not February 12 2019, 99.1 Estimates of proved reserves at December 31, 2016, 2017 2018 40 The projections should not not Future net cash inflows after income taxes were discounted using a 10% three December 31, 2016, 2017 2018 Years Ended December 31, 2016 2017 2018 Future cash inflows $ 999,716 $ 2,035,619 $ 2,876,976 Future production costs (357,917 ) (609,921 ) (849,063 ) Future development costs (267,836 ) (461,619 ) (547,163 ) Future income tax expense (1) - (83,915 ) (181,224 ) Future net cash flows 373,963 880,164 1,299,526 Discount $ (213,363 ) $ (474,423 ) $ (647,642 ) Standardized Measure of discounted future net cash relating to proved reserves $ 160,600 $ 405,741 $ 651,884 ( 1 There was no December 31, 2016 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, 2016 2017 2018 Standardized Measure, beginning of year $ 197,251 $ 160,600 $ 405,741 Sales and transfers of oil and gas produced, net of production costs (32,834 ) (63,764 ) (112,707 ) Net change in prices and development and production costs from prior year (58,425 ) 159,661 268,942 Extensions, discoveries, and improved recovery, less related costs 5,531 129,277 153,544 Sales of minerals in place (4,433 ) (8,583 ) (39,253 ) Purchases of minerals in place - 1,238 8,990 Revisions of previous estimates 12,317 31,044 (67,345 ) Change in timing and other 21,468 1,908 30,811 Change in future income tax expense - (21,700 ) (37,413 ) Accretion of discount 19,725 16,060 40,574 Standardized Measure, end of year $ 160,600 $ 405,741 $ 651,884 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, 2016 2017 2018 Oil (per Bbl) (1) $ 42.74 $ 51.34 $ 65.56 Gas (per MMbtu) (2) $ 2.50 $ 2.99 $ 3.05 Oil (per Bbl) (3) $ 35.54 $ 46.83 $ 56.95 Gas (per MMbtu) (4) $ 1.41 $ 1.79 $ 1.76 NGL's (per Bbl) (5) $ 5.17 $ 13.19 $ 19.95 _____________________ ( 1 The quoted oil price for the year ended December 31 2016, 2017 2018 12 first 2016, 2017 2018. ( 2 The quoted gas price for the year ended December 31, 2016, 2017 2018 12 first 2016, 2017 2018. ( 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, 2018
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 in three 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”).
Rig Accounting [Policy Text Block]	Rig Accounting In accordance with SEC Regulation S- X, no not
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, Policy [Policy Text Block]	Reclassifications Certain prior year balances have been reclassified for consistency with current year classifications. Such reclassifications had 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
Trade and Other Accounts Receivable, Policy [Policy Text Block]	Accounts Receivable Accounts receivable are reported net of an allowance for doubtful accounts of approximately $0.4 $0.5 December 31, 2017 2018,
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%, not No not 2016 $67.6 December 31, 2017 2018, not
Property, Plant and Equipment, Policy [Policy Text Block]	Other Property and Equipment Other property and equipment are recorded on the basis of 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
Derivatives, 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
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 Compensation, Option and Incentive Plans Policy [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, 2016, 2017 2018, $3.2 $3.2 $2.4
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: 2017 2018 Beginning future site restoration obligation $ 8,623 $ 8,775 New wells placed on production and other 1,088 612 Deletions related to property disposals and plugging costs (1,551 ) (2,270 ) Accretion expense and other 451 516 Revisions and other 164 (141 ) Ending future site restoration obligation $ 8,775 $ 7,492
Revenue Recognition, Policy [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. The Company recognizes oil and gas revenues from its interests in producing wells when control has transferred to the purchaser and to the extent the selling price is reasonably determinable. The Company had no December 31, 2017 2018.
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 $67.3 December 31, 2018. On December 22, 2017, 115 97, 35% 21%, December 22, 2017. December 2017, No. 118 118” one 740, 740” three 740. not
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, 2018.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Standards and Disclosures In February 2016, 842, Leases 842" 840, Leases 840" 12 not January 2018, 842 not not 840. In July 2018, 842 840. 840 840. The amendments in these ASUs are effective for fiscal years beginning after December 15, 2018, 2016 02 first 2019 842 not The Company has a team, including third 842 twelve $2.0 The Company enters into certain lease agreements in support of its operations for assets such as compressors, a drilling rig, employee housing and office equipment. As of December 31, 2018, not 842 2019, not The Company has made certain accounting policy decisions including that it plans on adopting the short-term lease recognition exemption, account for certain asset classes and has established a balance sheet recognition capitalization threshold. The Company also expects for certain lessee asset classes to elect the practical expedient to not

Note 1 - Organization and Sig_2

Note 1 - Organization and Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Change in Asset Retirement Obligation [Table Text Block]	2017 2018 Beginning future site restoration obligation $ 8,623 $ 8,775 New wells placed on production and other 1,088 612 Deletions related to property disposals and plugging costs (1,551 ) (2,270 ) Accretion expense and other 451 516 Revisions and other 164 (141 ) Ending future site restoration obligation $ 8,775 $ 7,492

Note 3 - Revenue From Contrac_2

Note 3 - Revenue From Contracts With Customers (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Disaggregation of Revenue [Table Text Block]	Years Ended December 31, 2016 2017 2018 Oil Gas NGL Oil Gas NGL Oil Gas NGL (In thousands) Operating Region Permian/Delaware Basin $ 3,551 $ 1,672 $ 664 $ 17,722 $ 3,028 $ 1,840 $ 47,175 $ 2,698 $ 2,884 Rocky Mountain $ 40,048 $ 1,070 $ 793 $ 49,670 $ 2,694 $ 3,774 $ 77,664 $ 3,913 $ 5,253 South Texas $ 7,366 $ 1,236 $ 93 $ 6,192 $ 1,176 $ 93 $ 8,065 $ 1,243 $ 135

Note 5 - Long-term Debt (Tables

Note 5 - Long-term Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Long-term Debt Instruments [Table Text Block]	2017 2018 (In thousands) Senior secured credit facility $ 84,000 $ 180,000 Real estate lien note 3,616 3,358 87,616 183,358 Less current maturities (262 ) (267 ) Total $ 87,354 $ 183,091
Contractual Obligation, Fiscal Year Maturity Schedule [Table Text Block]	Years ending December 31, (In thousands) 2019 $ 267 2020 280 2021 180,295 2022 310 2023 2,206 Thereafter - Total $ 183,358

Note 6 - Property and Equipme_2

Note 6 - Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Property, Plant and Equipment [Table Text Block]	Estimated December 31, Useful life 2017 2018 Years (In thousands) Oil and gas properties (1) $ 923,237 $ 1,091,905 Equipment and other 3-39 15,648 15,369 Drilling rig 15 23,488 24,084 962,373 1,131,358 Accumulated depreciation, depletion, amortization and impairment (724,606 ) (768,140 ) Net Property and Equipment $ 237,767 $ 363,218

Note 7 - Stock-based Compensa_2

Note 7 - Stock-based Compensation and Option Plans (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	2016 2017 2018 Weighted average value per option granted during the period $ 0.68 $ 1.81 $ 1.87 Assumptions: Forfeiture rate (1) 4.2 % 2.0 % 1.7 % Expected dividend yield (2) 0.0 % 0.0 % 0.0 % Volatility (3) 71.1 % 67.6 % 66.5 % Risk free interest rate (4) 1.7 % 2.2 % 2.9 % Expected life (years) (5) 7.0 6.9 7.3 Fair value of options granted (in thousands) $ 2,307 $ 574 $ 841
Share-based Compensation, Stock Options, Activity [Table Text Block]	Options Weighted average Weighted average Intrinsic value (000s) exercise price remaining life per share Options outstanding December 31, 2015 6,808 $ 2.89 Granted 2,265 1.02 Exercised (83 ) 1.40 Forfeited/Expired (836 ) 2.84 Options outstanding December 31, 2016 8,154 $ 2.39 Granted 317 1.81 Exercised (5 ) 0.97 Forfeited/Expired (149 ) 3.58 Options outstanding December 31, 2017 8,317 $ 2.35 Granted 300 2.80 Exercised (379 ) 1.71 Forfeited/Expired (689 ) 2.70 Options outstanding December 31, 2018 7,549 $ 2.37 4.9 $ 1.68 Exercisable at end of year 6,479 $ 2.50 4.5 $ 1.78 2016 2017 2018 Weighted average grant date fair value of stock options granted (per share) $ 0.68 $ 1.81 $ 1.87 Total fair value of options vested (000's) $ 2,776 $ 2,795 $ 2,054 Total intrinsic value of options exercised (000's) $ 39 $ 5 $ 395
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, by 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 0.97 - 1.99 3,270,117 4.9 $ 1.26 2,490,367 4.2 $ 1.32 2.00 - 2.99 1,422,975 4.4 $ 2.44 1,319,725 4.0 $ 2.43 3.00 - 3.99 2,212,606 5.4 $ 3.29 2,025,106 5.3 $ 3.30 4.00 - 4.99 544,750 4.2 $ 4.54 544,750 4.2 $ 4.54 5.00 - 5.99 98,000 5.4 $ 5.38 98,000 5.4 $ 5.38 6.00 - 6.28 1,000 5.5 $ 6.28 1,000 5.5 $ 6.28 7,549,448 4.9 $ 2.37 6,478,948 4.5 $ 2.50
Schedule of Nonvested Restricted Stock Units Activity [Table Text Block]	Number of Shares Weighted average grant date fair value Unvested December 31, 2015 1,643,284 $ 3.44 Granted - - Vested/Released (52,017 ) 2.40 Forfeited (98,802 ) 3.63 Unvested December 31, 2016 1,492,465 $ 3.47 Granted 44,000 1.75 Vested/Released (56,340 ) 3.14 Forfeited (750 ) 2.63 Unvested December 31, 2017 1,479,375 $ 3.43 Granted 861,113 2.17 Vested/Released (1,326,250 ) 3.43 Forfeited (187,557 ) 3.22 Unvested December 31, 2018 826,681 $ 2.15
Schedule of Nonvested Performance-based Units Activity [Table Text Block]	Number of Shares Weighted average grant date fair value Unvested December 31, 2017 - $ - Granted 464 2.37 Vested/Released - - Forfeited (59 ) 2.37 Unvested December 31, 2018 405 $ 2.37

Note 8 - Income Taxes (Tables)

Note 8 - Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	As of December 31, 2016 2017 2018 (In thousands) Deferred tax liabilities: Hedge contracts $ - $ - $ 3,167 Assets held for sale 3,390 - - Other 4,431 2,834 2,977 Total deferred tax liabilities 7,821 2,834 6,144 Deferred tax assets: Oil and gas properties 48,436 20,011 4,310 Capital loss carryforwards 7,361 3,015 3,980 Depletion carryforward 5,216 3,174 3,098 U.S. net operating loss carryforward 80,670 53,545 61,309 Alternative minimum tax credit 757 757 757 Hedge contracts 3,135 2,777 - Total deferred tax assets 145,575 83,279 73,454 Valuation allowance for deferred tax assets (137,754 ) (80,445 ) (67,310 ) Net deferred tax assets 7,821 2,834 6,144 Net deferred tax $ - $ - $ -
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Years ended December 31, 2016 2017 2018 (In thousands) Current: Federal $ — $ — $ — State — — — $ — $ — $ — Deferred: Federal $ — $ — $ — $ — $ — $ —
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Years Ended December 31, 2016 2017 2018 (In thousands) Tax (expense) benefit at U.S. Statutory rates $ 33,732 $ (5,602 ) $ (12,142 ) (Increase) decrease in deferred tax asset valuation allowance (34,072 ) 57,309 13,135 Permanent differences (1,133 ) (1,134 ) (500 ) Return to provision estimated revision 1,473 2,494 (470 ) Change in deferred tax rate - (53,125 ) - Other - 58 (23 ) $ - $ - $ -

Note 10 - Earnings Per Share (T

Note 10 - Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	Years ended December 31, 2016 2017 2018 (in thousands, except per share data) Numerator: Net income (loss) $ (96,378 ) $ 16,006 $ 57,821 Denominator for basic earnings per share - weighted-average common shares outstanding 122,132 161,141 165,635 Effect of dilutive securities: Stock options, restricted shares and performance based shares - 1,703 2,054 Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and performance based shares 122,132 162,844 167,689 Net (loss) income per common share - basic $ (0.79 ) $ 0.10 $ 0.35 Net (loss) income per common share - diluted $ (0.79 ) $ 0.10 $ 0.34

Note 11 - Quarterly Results o_2

Note 11 - Quarterly Results of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Quarterly Financial Information [Table Text Block]	1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter (In thousands, except per share data) Year Ended December 31, 2017 Net revenue $ 18,802 $ 13,152 $ 24,722 $ 29,588 Operating income $ 4,953 $ 1,260 $ 5,654 $ 9,470 Net income (loss) $ 13,690 $ 7,195 $ (770 ) $ (4,109 ) Net income (loss) per common share - basic $ 0.09 $ 0.04 $ - $ (0.02 ) Net income (loss) per common share - diluted $ 0.09 $ 0.04 $ - $ (0.02 ) Year Ended December 31, 2018 Net revenue $ 40,630 $ 30,916 $ 41,625 $ 35,996 Operating income $ 20,090 $ 10,931 $ 17,735 $ 8,722 Net income (loss) $ 10,779 $ (10,554 ) $ 1,777 $ 55,819 Net income (loss) per common share - basic $ 0.07 $ (0.06 ) $ 0.01 $ 0.34 Net income (loss) per common share - diluted $ 0.06 $ (0.06 ) $ 0.01 $ 0.33

Note 13 - Hedging Program and_2

Note 13 - Hedging Program and Derivatives (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Derivative Instruments [Table Text Block]	Oil - WTI Contract Periods Daily Volume (Bbl) Swap Price (per Bbl) Fixed Swaps January - December 2019 2,941 $ 56.20 January - December 2020 2,204 $ 54.35 January - December 2021 1,815 $ 60.32 Basis Swaps January - December 2019 4,000 $ 2.98 January - December 2020 4,000 $ 2.98
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	Fair Value Derivative Contracts as of December 31, 2017 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 $ - Derivatives - current $ 10,837 Commodity price derivatives Derivatives - long-term - Derivatives - long-term 2,387 $ - $ 13,224 Fair Value Derivative Contracts as of December 31, 2018 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 $ 9,602 Derivatives - current $ 616 Commodity price derivatives Derivatives - long-term 10,527 Derivatives - long-term 4,434 $ 20,129 $ 5,050

Note 14 - Financial Instrumen_2

Note 14 - Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2018
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, 2017 Assets: NYMEX fixed price derivative contracts $ - $ - $ - $ - Total Assets $ - $ - $ - $ - Liabilities: NYMEX fixed price derivative contracts $ - $ 13,208 $ - $ 13,208 NYMEX basis differential swap - - 16 16 Total Liabilities $ - $ 13,208 $ 16 $ 13,224 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, 2018 Assets: NYMEX fixed price derivative contracts $ - $ 18,172 $ - $ 18,172 NYMEX basis differential swap - - 1,957 1,957 Total Assets $ - $ 18,172 $ 1,957 $ 20,129 Liabilities: NYMEX fixed price derivative contracts $ - $ - $ - $ - NYMEX basis differential swap - - 5,050 5,050 Total Liabilities $ - $ - $ 5,050 $ 5,050
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	(In thousands) Unobservable inputs at January 1, 2018 $ (16 ) Changes in market value $ (3,093 ) Settlements during the period $ 16 Unobservable inputs at December 31, 2018 $ (3,093 )

Note 15 - Subsequent Events (Ta

Note 15 - Subsequent Events (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Fixed Price Derivatives [Table Text Block]	Oil - WTI Contract Periods Daily Volume (Bbl) Swap Price (per Bbl) Fixed Swaps July - December 2019 1,156 $ 58.50 January - December 2020 819 $ 57.65 January - December 2021 236 $ 55.70

Note 16 - Supplemental Oil an_2

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Years Ended December 31, 2017 2018 Proved oil and gas properties $ 923,237 $ 1,091,905 Unproved properties - - Total 923,237 1,091,905 Accumulated depreciation, depletion, amortization and impairment (706,537 ) (748,773 ) Net capitalized costs $ 216,700 $ 343,132
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	2016 2017 2018 Development costs $ 18,262 $ 94,478 $ 131,271 Exploration costs 12,529 8,509 - Property acquisition costs - 31,409 41,465 $ 30,791 $ 134,396 $ 172,736
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]	2016 2017 2018 Revenues $ 56,493 $ 86,189 $ 149,030 Production costs (23,659 ) (22,425 ) (36,323 ) Depreciation, depletion and amortization (22,803 ) (25,676 ) (42,237 ) Proved property impairment (67,626 ) - - Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs) $ (57,595 ) $ 38,088 $ 72,488 Depletion rate per barrel of oil equivalent $ 10.08 $ 9.52 $ 11.80
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, 2015 24,131 6,556 75,027 43,190 Revisions of previous estimates 1,379 2,300 (1,537 ) 3,424 Extensions and discoveries 1,183 157 1,179 1,537 Sales of minerals in place (1,112 ) (6 ) (680 ) (1,232 ) Production (1,372 ) (363 ) (3,160 ) (2,262 ) Balance at December 31, 2016 24,209 8,644 70,829 44,657 Revisions of previous estimates 259 1,269 19,311 4,747 Extensions and discoveries 14,533 2,813 14,534 19,768 Purchases of minerals in place 8 14 1,001 189 Sales of minerals in place (364 ) (289 ) (3,958 ) (1,312 ) Production (1,574 ) (476 ) (3,889 ) (2,698 ) Balance at December 31, 2017 37,071 11,975 97,828 65,351 Revisions of previous estimates (4,206 ) (1,927 ) (2,618 ) (6,570 ) Extensions and discoveries 11,270 1,797 11,475 14,979 Purchases of minerals in place 688 - 1,137 877 Sales of minerals in place (278 ) (1,303 ) (13,491 ) (3,829 ) Production (2,308 ) (508 ) (4,587 ) (3,580 ) Balance at December 31, 2018 42,237 10,034 89,744 67,228 Total Oil OIl NGL Gas Equilavents (MBbl) (MBbl) (MMcf) (Mboe) Proved Developed Reserves: December 31, 2016 7,818 2,568 27,792 15,018 December 31, 2017 10,820 3,794 39,974 21,720 December 31, 2018 13,586 3,804 43,271 24,602 Proved Undeveloped Reserves: December 31, 2016 16,391 6,076 43,037 29,639 December 31, 2017 25,808 8,181 57,854 43,631 December 31, 2018 28,651 6,230 46,473 42,626
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	Years Ended December 31, 2016 2017 2018 Future cash inflows $ 999,716 $ 2,035,619 $ 2,876,976 Future production costs (357,917 ) (609,921 ) (849,063 ) Future development costs (267,836 ) (461,619 ) (547,163 ) Future income tax expense (1) - (83,915 ) (181,224 ) Future net cash flows 373,963 880,164 1,299,526 Discount $ (213,363 ) $ (474,423 ) $ (647,642 ) Standardized Measure of discounted future net cash relating to proved reserves $ 160,600 $ 405,741 $ 651,884
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	Years Ended December 31, 2016 2017 2018 Standardized Measure, beginning of year $ 197,251 $ 160,600 $ 405,741 Sales and transfers of oil and gas produced, net of production costs (32,834 ) (63,764 ) (112,707 ) Net change in prices and development and production costs from prior year (58,425 ) 159,661 268,942 Extensions, discoveries, and improved recovery, less related costs 5,531 129,277 153,544 Sales of minerals in place (4,433 ) (8,583 ) (39,253 ) Purchases of minerals in place - 1,238 8,990 Revisions of previous estimates 12,317 31,044 (67,345 ) Change in timing and other 21,468 1,908 30,811 Change in future income tax expense - (21,700 ) (37,413 ) Accretion of discount 19,725 16,060 40,574 Standardized Measure, end of year $ 160,600 $ 405,741 $ 651,884
Oil and Gas Prices Considered in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	Years Ended December 31, 2016 2017 2018 Oil (per Bbl) (1) $ 42.74 $ 51.34 $ 65.56 Gas (per MMbtu) (2) $ 2.50 $ 2.99 $ 3.05 Oil (per Bbl) (3) $ 35.54 $ 46.83 $ 56.95 Gas (per MMbtu) (4) $ 1.41 $ 1.79 $ 1.76 NGL's (per Bbl) (5) $ 5.17 $ 13.19 $ 19.95

Note 1 - Organization and Sig_3

Note 1 - Organization and Significant Accounting Policies (Details Textual)	12 Months Ended
	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Number of Operating Regions in Domicile Country		3
Allowance for Doubtful Accounts Receivable, Ending Balance		$ 0.50	$ 0.40
Impairment of Oil and Gas Properties				$ 67,626,000
Share-based Compensation, Total		$ 2,366,000	$ 3,238,000	$ 3,194,000
Entity Wide Revenue Number of Major Purchasers of Oil and Gas		2	3	2
Deferred Tax Assets, Valuation Allowance, Total		$ 67,310,000	$ 80,445,000	$ 137,754,000
Maximum [Member] | Scenario, Forecast [Member] | Accounting Standards Update 2016-01 [Member]
Impact of Adoption of Accounting Standards Update	$ 2,000,000
Sales Revenue, Net [Member] | Customer Concentration Risk [Member]
Concentration Risk, Percentage		57.00%	69.00%	71.00%

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Beginning future site restoration obligation	$ 8,775	$ 8,623
New wells placed on production and other	612	1,088
Deletions related to property disposals and plugging costs	(2,270)	(1,551)
Accretion expense and other	516	451	$ 491
Revisions and other	(141)	164
Ending future site restoration obligation	$ 7,492	$ 8,775	$ 8,623

Note 2 - Impact of ASC 606 Ad_2

Note 2 - Impact of ASC 606 Adoption (Details Textual) $ in Thousands	Jan. 01, 2018USD ($)
Accounting Standards Update 2014-09 [Member]
Cumulative Effect on Retained Earnings, Net of Tax, Total	$ 0

Note 3 - Revenue From Contrac_3

Note 3 - Revenue From Contracts With Customers (Details Textual) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Accounts Receivable, Gross, Current	$ 21,991	$ 17,789

Note 3 - Revenue From Contrac_4

Note 3 - Revenue From Contracts With Customers - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Oil Revenues [Member]
Revenues	$ 132,904	$ 73,584	$ 50,965
Gas Revenues [Member]
Revenues	7,854	6,898	3,978
Natural Gas Liquids Revenues [Member]
Revenues	8,272	5,707	1,550
Permian / Delaware Basin [Member] | Oil Revenues [Member]
Revenues	47,175	17,722	3,551
Permian / Delaware Basin [Member] | Gas Revenues [Member]
Revenues	2,698	3,028	1,672
Permian / Delaware Basin [Member] | Natural Gas Liquids Revenues [Member]
Revenues	2,884	1,840	664
Rocky Mountain [Member] | Oil Revenues [Member]
Revenues	77,664	49,670	40,048
Rocky Mountain [Member] | Gas Revenues [Member]
Revenues	3,913	2,694	1,070
Rocky Mountain [Member] | Natural Gas Liquids Revenues [Member]
Revenues	5,253	3,774	793
South Texas [Member] | Oil Revenues [Member]
Revenues	8,065	6,192	7,366
South Texas [Member] | Gas Revenues [Member]
Revenues	1,243	1,176	1,236
South Texas [Member] | Natural Gas Liquids Revenues [Member]
Revenues	$ 135	$ 93	$ 93

Note 4 - Acquisition and Dive_2

Note 4 - Acquisition and Divestitures of Properties (Details Textual)	12 Months Ended
	Dec. 31, 2018USD ($)a	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Proceeds from Sale of Property, Plant, and Equipment, Total	$ 26,000	$ 204,000	$ 4,022,000
Leasehold and Working Interests in Permian Basin Region [Member]
Mineral Area Acquired | a	2,721
Property, Plant and Equipment, Additions	$ 40,400,000
Capital Expenditures Incurred but Not yet Paid	21,000
Non-core Properties [Member]
Proceeds from Sale of Property, Plant, and Equipment, Total	$ 3,300,000

Note 5 - Long-term Debt (Detail

Note 5 - Long-term Debt (Details Textual)	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Line of Credit Facility, Interest Rate at Period End	6.00%
Financial Covenants, Minimum Current Ratio	1
Financial Covenants, Interest Coverage Ratio	2.5
Financial Covenants, Total Debt to EBITDAX Ratio	3.5
Debt Instrument Covenants, Extraordinary Expenses Included in Determining EBITDAX	$ 1,000,000
Interest Coverage Ratio	11.94
Total Debt to EBITDAX Ratio	2.14
Current Ratio	0.96
Line of Credit Covenant, Percentage of Net Proceeds to be Used for Repayment	100.00%
Line of Credit Covenant, Cash and Liquid Investments Triggering Credit Repayment	$ 10,000,000
Long-term Debt, Total	183,358,000	$ 87,616,000
Line of Credit [Member]
Long-term Line of Credit, Total	180,000,000
Line of Credit Facility, Maximum Borrowing Capacity	300,000,000
Line of Credit Facility, Current Borrowing Capacity	$ 200,000,000
Line of Credit, Market Value of Property, Minimum Percentage	5.00%
Line of Credit, Reduced Collateral Value, Minimum Percentage	5.00%
Line of Credit, Default, Minimum Interest Rate	3.00%
Debt Instrument, Spread on Elected Variable Rate	0.50%
Debt Instrument, Maturity Date	May 16, 2021
Debt Instrument, Collateral Eligible, Minimum Percent of PV-10 Required	90.00%
Long-term Debt, Total	$ 180,000,000	84,000,000
Line of Credit [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] | Maximum [Member]
Debt Instrument, Spread on Elected Variable Rate	3.50%
Debt Instrument, Basis Spread on Variable Rate	2.50%
Construction Loans [Member]
Long-term Debt, Percentage Bearing Fixed Interest, Percentage Rate	4.90%
Debt Instrument, Periodic Payment, Total	$ 35,672
Long-term Debt, Total	$ 3,400,000	$ 3,600,000

Note 5 - Long-term Debt - Debt

Note 5 - Long-term Debt - Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Long-term debt	$ 183,358	$ 87,616
Less current maturities	(267)	(262)
Total	183,091	87,354
Line of Credit [Member]
Long-term debt	180,000	84,000
Mortgages [Member]
Long-term debt	$ 3,358	$ 3,616

Note 5 - Long-term Debt - Matur

Note 5 - Long-term Debt - Maturities of Long-term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
2019	$ 267
2020	280
2021	180,295
2022	310
2023	2,206
Thereafter
Total	$ 183,358	$ 87,616

Note 6 - Property and Equipme_3

Note 6 - Property and Equipment - Property and Equipment (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Property and equipment		$ 1,131,358	$ 962,373
Accumulated depreciation, depletion, amortization and impairment		(768,140)	(724,606)
Net Property and Equipment		$ 363,218	237,767
Oil and Gas Properties [Member]
Estimated useful life (Year)	[1]	1 year
Property and equipment	[1]	$ 1,091,905	923,237
Equipment and Other [Member]
Property and equipment		$ 15,369	15,648
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]
Estimated useful life (Year)		15 years
Property and equipment		$ 24,084	$ 23,488
[1]	Oil and gas properties are amortized utilizing units of production method.

Note 7 - Stock-based Compensa_3

Note 7 - Stock-based Compensation and Option Plans (Details Textual) - USD ($) $ in Thousands	Apr. 01, 2018	Jan. 31, 2017	May 31, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation, Total				$ 2,366	$ 3,238	$ 3,194
Common Stock, Capital Shares Reserved for Future Issuance				10,300,000
Stock Issued During Period, Shares, New Issues		28,800,000	28,800,000
Proceeds from Issuance of Common Stock		$ 65,200	$ 27,100		65,224	27,135
Directors Plan 2005 [Member]
Common Stock, Capital Shares Reserved for Future Issuance				2,900,000
Share Based Compensation Arrangement By Share Based Payment Award, Number of Shares Granted to Attend Board and Committee Meetings				25,000
Share-based Compensation Arrangement by Share-based Payment Award, Maximum Number of Shares Per Employee				100,000
Percentage of Exercise Price Awarded				100.00%
Employee Stock Option [Member]
Deferred Compensation Arrangement with Individual, Common Stock Reserved for Future Issuance				12,600,000
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period				10 years
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Total				$ 500
Share-based Compensation, Total				1,400	1,800	2,000
Restricted Stock [Member]
Share-based Compensation, Total				700	$ 1,400	$ 1,200
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options				1,300
Performance Shares [Member]
Share-based Compensation, Total				200
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options				$ 700
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	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 7 - Stock-based Compensa_4

Note 7 - Stock-based Compensation and Option Plans - Stock Option Valuation Assumptions (Details) - USD ($) $ / shares in Units, $ in Thousands		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Weighted average value per option granted during the period (in dollars per share)		$ 1.87	$ 1.81	$ 0.68
Forfeiture rate (1)	[1]	1.70%	2.00%	4.20%
Expected dividend yield (2)	[2]	0.00%	0.00%	0.00%
Volatility (3)	[3]	66.50%	67.60%	71.10%
Risk free interest rate (4)	[4]	2.90%	2.20%	1.70%
Expected life (years) (5) (Year)	[5]	7 years 109 days	6 years 328 days	7 years
Fair value of options granted (in thousands)		$ 841	$ 574	$ 2,307
[1]	The estimated future forfeiture rate is based on the Company's historical forfeiture rate on similar grants of stock options.
[2]	The dividend yield is based on the fact the Company does not pay any dividends.
[3]	The volatility is based on the historical volatility of our stock for a period approximating the expected life.
[4]	The risk-free interest rate is based on the observed U.S. Treasury yield curve in effect at the time the options were granted for a period approximating the expected life of the option.
[5]	The expected life was derived based on a weighting between (a) the Company's historical exercise and forfeiture activity and (b) the average midpoint between vesting and the contractual term.

Note 7 - Stock-based Compensa_5

Note 7 - Stock-based Compensation and Option Plans - Stock Option Activity (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Weighted average value per option granted during the period (in dollars per share)	$ 1.87	$ 1.81	$ 0.68
Employee Stock Option [Member]
Balance (in shares)	8,317	8,154	6,808
Balance, weighted average exercise price (in dollars per share)	$ 2.35	$ 2.39	$ 2.89
Granted (in shares)	300	317	2,265
Granted, weighted average exercise price (in dollars per share)	$ 2.80	$ 1.81	$ 1.02
Exercised (in shares)	(379)	(5)	(83)
Exercised, weighted average exercise price (in dollars per share)	$ 1.71	$ 0.97	$ 1.40
Forfeited/Expired (in shares)	(689)	(149)	(836)
Forfeited/Expired, weighted average exercise price (in dollars per share)	$ 2.70	$ 3.58	$ 2.84
Balance (in shares)	7,549	8,317	8,154
Balance, weighted average exercise price (in dollars per share)	$ 2.37	$ 2.35	$ 2.39
Options outstanding, weighted average remaining life (Year)	4 years 328 days
Options outstanding, intrinsic value per share (in dollars per share)	$ 1.68
Exercisable at end of year (in shares)	6,479
Exercisable, weighted average remaining life (Year)	4 years 182 days
Exercisable, intrinsic value per share (in dollars per share)	$ 1.78
Weighted average value per option granted during the period (in dollars per share)	$ 1.87	$ 1.81	$ 0.68
Total fair value of options vested (000's)	$ 2,054	$ 2,795	$ 2,776
Total intrinsic value of options exercised (000's)	$ 395	$ 5	$ 39

Note 7 - Stock-based Compensa_6

Note 7 - Stock-based Compensation and Option Plans - Stock Options Outstanding (Details)	12 Months Ended
	Dec. 31, 2018$ / sharesshares
Outstanding options, number outstanding (in shares) | shares	7,549,448
Outstanding options, weighted average remaining life (Year)	4 years 328 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 2.37
Exercisable, number outstanding (in shares) | shares	6,478,948
Exercisable, weighted average remaining life (Year)	4 years 182 days
Exercisable, weighted average exercise price (in dollars per share)	$ 2.50
Range One [Member]
Exercise price range, lower limit (in dollars per share)	0.97
Exercise price range, upper limit (in dollars per share)	$ 1.99
Outstanding options, number outstanding (in shares) | shares	3,270,117
Outstanding options, weighted average remaining life (Year)	4 years 328 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 1.26
Exercisable, number outstanding (in shares) | shares	2,490,367
Exercisable, weighted average remaining life (Year)	4 years 73 days
Exercisable, weighted average exercise price (in dollars per share)	$ 1.32
Range Two [Member]
Exercise price range, lower limit (in dollars per share)	2
Exercise price range, upper limit (in dollars per share)	$ 2.99
Outstanding options, number outstanding (in shares) | shares	1,422,975
Outstanding options, weighted average remaining life (Year)	4 years 146 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 2.44
Exercisable, number outstanding (in shares) | shares	1,319,725
Exercisable, weighted average remaining life (Year)	4 years
Exercisable, weighted average exercise price (in dollars per share)	$ 2.43
Range Three [Member]
Exercise price range, lower limit (in dollars per share)	3
Exercise price range, upper limit (in dollars per share)	$ 3.99
Outstanding options, number outstanding (in shares) | shares	2,212,606
Outstanding options, weighted average remaining life (Year)	5 years 146 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 3.29
Exercisable, number outstanding (in shares) | shares	2,025,106
Exercisable, weighted average remaining life (Year)	5 years 109 days
Exercisable, weighted average exercise price (in dollars per share)	$ 3.30
Range Four [Member]
Exercise price range, lower limit (in dollars per share)	4
Exercise price range, upper limit (in dollars per share)	$ 4.99
Outstanding options, number outstanding (in shares) | shares	544,750
Outstanding options, weighted average remaining life (Year)	4 years 73 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 4.54
Exercisable, number outstanding (in shares) | shares	544,750
Exercisable, weighted average remaining life (Year)	4 years 73 days
Exercisable, weighted average exercise price (in dollars per share)	$ 4.54
Range Five [Member]
Exercise price range, lower limit (in dollars per share)	5
Exercise price range, upper limit (in dollars per share)	$ 5.99
Outstanding options, number outstanding (in shares) | shares	98,000
Outstanding options, weighted average remaining life (Year)	5 years 146 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 5.38
Exercisable, number outstanding (in shares) | shares	98,000
Exercisable, weighted average remaining life (Year)	5 years 146 days
Exercisable, weighted average exercise price (in dollars per share)	$ 5.38
Range Six [Member]
Exercise price range, lower limit (in dollars per share)	6
Exercise price range, upper limit (in dollars per share)	$ 6.28
Outstanding options, number outstanding (in shares) | shares	1,000
Outstanding options, weighted average remaining life (Year)	5 years 182 days
Outstanding options, weighted average exercise price (in dollars per share)	$ 6.28
Exercisable, number outstanding (in shares) | shares	1,000
Exercisable, weighted average remaining life (Year)	5 years 182 days
Exercisable, weighted average exercise price (in dollars per share)	$ 6.28

Note 7 - Stock-based Compensa_7

Note 7 - Stock-based Compensation and Option Plans - Restricted Stock Activity (Details) - Restricted Stock [Member] - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Unvested (in shares)	1,479,375	1,492,465	1,643,284
Unvested, weighted average grant date fair value (in dollars per share)	$ 3.43	$ 3.47	$ 3.44
Granted (in shares)	861,113	44,000
Granted, weighted average grant date fair value (in dollars per share)	$ 2.17	$ 1.75
Vested/Released (in shares)	(1,326,250)	(56,340)	(52,017)
Vested/Released, weighted average grant date fair value (in dollars per share)	$ 3.43	$ 3.14	$ 2.40
Forfeited (in shares)	(187,557)	(750)	(98,802)
Forfeited, weighted average grant date fair value (in dollars per share)	$ 3.22	$ 2.63	$ 3.63
Unvested (in shares)	826,681	1,479,375	1,492,465
Unvested, weighted average grant date fair value (in dollars per share)	$ 2.15	$ 3.43	$ 3.47

Note 7 - Stock-based Compensa_8

Note 7 - Stock-based Compensation and Option Plans - Performance Based Restricted Stock Awards (Details) - Performance Shares [Member]	12 Months Ended
	Dec. 31, 2018$ / sharesshares
Unvested (in shares) | shares
Unvested, weighted average grant date fair value (in dollars per share) | $ / shares
Granted (in shares) | shares	464
Granted, weighted average grant date fair value (in dollars per share) | $ / shares	$ 2.37
Vested/Released (in shares) | shares
Vested/Released, weighted average grant date fair value (in dollars per share) | $ / shares
Forfeited (in shares) | shares	(59)
Forfeited, weighted average grant date fair value (in dollars per share) | $ / shares	$ 2.37
Unvested (in shares) | shares	405
Unvested, weighted average grant date fair value (in dollars per share) | $ / shares	$ 2.37

Note 8 - Income Taxes (Details

Note 8 - Income Taxes (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Deferred Tax Assets, Valuation Allowance, Total	$ 67,310	$ 80,445	$ 137,754
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued, Total	$ 0	$ 0	$ 0
Open Tax Year	2013 2014 2015 2016 2017 2018
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%
Pre 2018 [Member] | Domestic Tax Authority [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards, Total	$ 245,200
Tax Year 2018 [Member] | Domestic Tax Authority [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards, Total	$ 46,800
Earliest Tax Year [Member]
Operating Loss Carryforwards, Expiration Date	Jan. 1, 2023
Latest Tax Year [Member]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037

Note 8 - Income Taxes - Deferre

Note 8 - Income Taxes - Deferred Tax Liabilities and Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Hedge contracts	$ 3,167
Assets held for sale			3,390
Other	2,977	2,834	4,431
Total deferred tax liabilities	6,144	2,834	7,821
Oil and gas properties	4,310	20,011	48,436
Capital loss carryforwards	3,980	3,015	7,361
Depletion carryforward	3,098	3,174	5,216
U.S. net operating loss carryforward	61,309	53,545	80,670
Alternative minimum tax credit	757	757	757
Hedge contracts		2,777	3,135
Total deferred tax assets	73,454	83,279	145,575
Valuation allowance for deferred tax assets	(67,310)	(80,445)	(137,754)
Net deferred tax assets	6,144	2,834	7,821
Net deferred tax

Note 8 - Income Taxes - Provisi

Note 8 - Income Taxes - Provision (Benefit) for Income Taxes (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Federal
State
Federal

Note 8 - Income Taxes - Reconci

Note 8 - Income Taxes - Reconciliation of Income Tax (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Tax (expense) benefit at U.S. Statutory rates	$ (12,142)	$ (5,602)	$ 33,732
(Increase) decrease in deferred tax asset valuation allowance	13,135	57,309	(34,072)
Permanent differences	(500)	(1,134)	(1,133)
Return to provision estimated revision	(470)	2,494	1,473
Change in deferred tax rate		(53,125)
Other	$ (23)	$ 58

Note 9 - Commitments and Cont_2

Note 9 - Commitments and Contingencies (Details Textual) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Leases, Rent Expense, Net, Total	$ 24,300,000	$ 15,197,000	$ 18,205,000
Office Space in Dickinson, North Dakota [Member]
Operating Leases, Rent Expense, Net, Total	$ 23,200	27,840	27,165
Office Space in Lusk, Wyoming [Member]
Operating Leases, Rent Expense, Net, Total		9,000	9,000
Office Space in Denver, Colorado [Member]
Operating Leases, Rent Expense, Net, Total		$ 13,837	$ 15,601

Note 10 - Earnings Per Share (D

Note 10 - Earnings Per Share (Details Textual) - shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	4,007	5,018	1,635

Note 10 - Earnings Per Share -

Note 10 - 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, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net (loss) income	$ 55,819	$ 1,777	$ (10,554)	$ 10,779	$ (4,109)	$ (770)	$ 7,195	$ 13,690	$ 57,821	$ 16,006	$ (96,378)
Basic (in shares)									165,635	161,141	122,132
Effect of dilutive securities: Stock options, restricted shares and performance based shares (in shares)									2,054	1,703
Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and performance based shares (in shares)									167,689	162,844	122,132
Net income (loss) per common share - basic (in dollars per share)	$ 0.34	$ 0.01	$ (0.06)	$ 0.07	$ (0.02)		$ 0.04	$ 0.09	$ 0.35	$ 0.10	$ (0.79)
Net income (loss) per common share - diluted (in dollars per share)	$ 0.33	$ 0.01	$ (0.06)	$ 0.06	$ (0.02)		$ 0.04	$ 0.09	$ 0.34	$ 0.10	$ (0.79)

Note 11- Quarterly Results of O

Note 11- 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, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net revenue	$ 35,996	$ 41,625	$ 30,916	$ 40,630	$ 29,588	$ 24,722	$ 13,152	$ 18,802	$ 149,167	$ 86,264	$ 56,555
Operating income	8,722	17,735	10,931	20,090	9,470	5,654	1,260	4,953	57,528	20,886	(73,878)
Net income (loss)	$ 55,819	$ 1,777	$ (10,554)	$ 10,779	$ (4,109)	$ (770)	$ 7,195	$ 13,690	$ 57,821	$ 16,006	$ (96,378)
Net income (loss) per common share - basic (in dollars per share)	$ 0.34	$ 0.01	$ (0.06)	$ 0.07	$ (0.02)		$ 0.04	$ 0.09	$ 0.35	$ 0.10	$ (0.79)
Net income (loss) per common share - diluted (in dollars per share)	$ 0.33	$ 0.01	$ (0.06)	$ 0.06	$ (0.02)		$ 0.04	$ 0.09	$ 0.34	$ 0.10	$ (0.79)

Note 12 - Benefit Plans (Detail

Note 12 - Benefit Plans (Details Textual) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Deferred Compensation Arrangement with Individual, Contributions by Employer	$ 331,957	$ 330,415	$ 256,309
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	1.00%
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 0.50
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	5.00%
Defined Contribution Plan Employee Contribution Limit Below 50 Years of Age	$ 18,500	18,000	18,000
Defined Contribution Plan Employee Contribution Limit 50 Years of Age or Older	$ 24,500	$ 24,000	$ 24,000

Note 13 - Hedging Program and_3

Note 13 - Hedging Program and Derivatives (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative Asset, Total	$ 20,129
Gain (Loss) on Sale of Derivatives	8,060	(1,849)	$ (18,028)
Commodity Contract [Member]
Derivative Asset, Total	15,100
Commodity Contract [Member] | (Gain) Loss on Derivative Contracts [Member]
Gain (Loss) on Sale of Derivatives	8,100	(1,800)
Commodity Closed Contracts [Member] | (Gain) Loss on Derivative Contracts [Member]
Gain (Loss) on Sale of Derivatives	(19,000)	2,500
Commodity Open Contracts [Member] | (Gain) Loss on Derivative Contracts [Member]
Gain (Loss) on Sale of Derivatives	$ 27,100	$ (4,300)

Note 13 - Hedging Program and_4

Note 13 - Hedging Program and Derivatives - Summary Position of Derivative Contracts (Details) - Oil - WTI [Member]	12 Months Ended
	Dec. 31, 2018$ / bblbbl
Fixed Swap, Contract Period 2018 October - December [Member]
Daily volume (Barrel of Oil) | bbl	2,941
Swap price (in USD per Barrel of Oil) | $ / bbl	56.2
Fixed Swap, Contract Period 2019 January - December [Member]
Daily volume (Barrel of Oil) | bbl	2,204
Swap price (in USD per Barrel of Oil) | $ / bbl	54.35
Fixed Swap, Contract Period 2020 January - December [Member]
Daily volume (Barrel of Oil) | bbl	1,815
Swap price (in USD per Barrel of Oil) | $ / bbl	60.32
Fixed Swap, Contract Period 2021 January - December [Member]
Daily volume (Barrel of Oil) | bbl	4,000
Swap price (in USD per Barrel of Oil) | $ / bbl	2.98
Basis Swap, Contract Period 2019 January - December [Member]
Daily volume (Barrel of Oil) | bbl	4,000
Swap price (in USD per Barrel of Oil) | $ / bbl	2.98

Note 13 - Hedging Program and_5

Note 13 - Hedging Program and Derivatives - Impact of Derivative Contracts on Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Derivative asset, current	$ 9,602
Derivative liability, current	616	10,837
Derivative asset, long-term	10,527
Derivative liability, long-term	4,434	2,387
Derivative Asset, Total	20,129
Derivative liability	5,050	13,224
Commodity Contract [Member]
Derivative Asset, Total	15,100
Commodity Contract [Member] | Derivative Assets Current [Member]
Derivative asset, current	9,602
Commodity Contract [Member] | Derivative Liabilities Current [Member]
Derivative liability, current	616	10,837
Commodity Contract [Member] | Derivative Assets Noncurrent [Member]
Derivative asset, long-term	10,527
Commodity Contract [Member] | Derivative Liabilities Noncurrent [Member]
Derivative liability, long-term	$ 4,434	$ 2,387

Note 14 - Financial Instrumen_3

Note 14 - Financial Instruments - Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Derivative assets	$ 20,129
Derivative liabilities	5,050	13,224
Fair Value, Measurements, Recurring [Member]
Derivative assets	20,129
Derivative liabilities	5,050	13,224
Fair Value, Measurements, Recurring [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets	18,172
Derivative liabilities		13,208
Fair Value, Measurements, Recurring [Member] | Basis Swap [Member]
Derivative assets	1,957
Derivative liabilities	5,050	16
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets
Derivative liabilities
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets
Derivative liabilities
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Basis Swap [Member]
Derivative assets
Derivative liabilities
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets	18,172
Derivative liabilities		13,208
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets	18,172
Derivative liabilities		13,208
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Basis Swap [Member]
Derivative assets
Derivative liabilities
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets	1,957
Derivative liabilities	5,050	16
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Price Derivative Contracts [Member]
Derivative assets
Derivative liabilities
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Basis Swap [Member]
Derivative assets	1,957
Derivative liabilities	$ 5,050	$ 16

Note 14 - Financial Instrumen_4

Note 14 - Financial Instruments - Recurring Fair Value Measurements Using Significant Unobservable Inputs (Details) - Fair Value, Inputs, Level 3 [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)
Unobservable inputs at January 1, 2018	$ (16)
Changes in market value	(3,093)
Settlements during the period	16
Unobservable inputs at December 31, 2018	$ (3,093)

Note 15 - Subsequent Events - D

Note 15 - Subsequent Events - Derivative Contracts (Details) - Subsequent Event [Member]	Mar. 14, 2019$ / bbl
Fixed Swap 2019 [Member]
Daily volume	1,156
Swap price (in USD per Barrel of Oil)	58.5
Fixed Swap 2020 [Member]
Daily volume	819
Swap price (in USD per Barrel of Oil)	57.65
Fixed Swap 2021 [Member]
Daily volume	236
Swap price (in USD per Barrel of Oil)	55.7

Note 16 - Supplemental Oil an_3

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) (Details Textual) Boe in Thousands	12 Months Ended
	Dec. 31, 2018Boe	Dec. 31, 2017Boe	Dec. 31, 2016Boe
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy		1,312	1,232
Proved Developed and Undeveloped Reserves Production, Energy	3,580	2,698	2,262
Proved Developed and Undeveloped Reserve, Purchase of Mineral in Place (Energy)		189
Ira Area [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy	203
Delaware Locations in Ward County, TX [Member]
Number of Producing Locations Sold	1
Number of Undeveloped Locations Sold	2
Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy	3,558
Other Miscellaneous Asset [Member]
Proved Developed and Undeveloped Reserves Sales of Minerals in Place, Energy	68
Change in Projections [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy	(45)	621
Conversion of Probable Undeveloped Locations to Proved Producing Reserves [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		3
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy		2,028
Conversion of Probable Undeveloped Locations to Proved Producing Reserves [Member] | Three Fork 2nd bench Locations [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy	6,525
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Location	13
Addition of Proved Undeveloped Operated Locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location	19
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	8,130
Addition of Proved Undeveloped Non-operated Locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location	2
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	838
Conversion of Probable Undeveloped Locations to Producing Reserves [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location	2
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	1,523
Conversion of Probable Undeveloped Locations to Proved Undeveloped Reserves [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location	5
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	2,670
Conversion of Probable Undeveloped Locations to Proved Undeveloped Reserves [Member] | Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		10
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy		4,343
Unit Line Well Configurations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location	3
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	1,692
Non-operated Proved Non-producintg Locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location	6
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	126
Minerals Purchased in Place [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy	877
Increase in Projections [Member] | Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy		1,951
Increase in Economic Life Expectations [Member] | Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy		523
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Location		7
Proved Developed and Undeveloped Reserves Production, Energy		2,698
Addition of New Producing Wells [Member] | Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		3
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy		1,229	449
Addition of New Producing Wells [Member] | Atascosa County, TX [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy		240
Addition of Proved Undeveloped Locations [Member] | Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location			5
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy		11,928	805
Addition of Proved Undeveloped Locations [Member] | Proved Undeveloped Wolfcamp A locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		27
Addition of Proved Undeveloped Locations [Member] | Third Bone Spring locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		4
Addition of Proved Undeveloped Locations [Member] | Wolfcamp B Locations [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location		2
Addition of Proved Undeveloped Locations [Member] | McKenzie County, ND [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Location			8
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy			18
Continued Improvement in Well Production Results [Member] | McKenzie County, ND [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy			5,005
Improved Performance [Member] | Ward County, TX [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy			1,360
Under-performance of Hedgehog State 16-2H [Member] | Porcupine Field, Campbell County, WY [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy			(670)
Shortened Economic Life Expectations [Member]
Proved Developed and Undeveloped Reserves Revisions of Previous Estimates, Energy			(2,271)
Development of New Austin Chalk Producer [Member] | Atascosa County, TX [Member]
Proved Developed and Undeveloped Reserves Extensions Discoveries and Additions, Energy			265

Note 16 - Supplemental Oil an_4

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Proved oil and gas properties	$ 1,091,905	$ 923,237
Unproved properties
Total	1,091,905	923,237
Accumulated depreciation, depletion, amortization and impairment	(748,773)	(706,537)
Net capitalized costs	$ 343,132	$ 216,700

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Development costs	$ 131,271	$ 94,478	$ 18,262
Exploration costs		8,509	12,529
Property acquisition costs	41,465	31,409
	$ 172,736	$ 134,396	$ 30,791

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, 2018USD ($)$ / bbl	Dec. 31, 2017USD ($)$ / bbl	Dec. 31, 2016USD ($)$ / bbl
Revenues	$ 149,030	$ 86,189	$ 56,493
Production costs	(36,323)	(22,425)	(23,659)
Depreciation, depletion and amortization	(42,237)	(25,676)	(22,803)
Proved property impairment			(67,626)
Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs)	$ 72,488	$ 38,088	$ (57,595)
Depletion rate per barrel of oil equivalent (in USD per Barrel of Oil) | $ / bbl	11.8	9.52	10.08

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Oil [Member]
Balance (Barrel of Oil)	37,071	24,209	24,131
Revisions of previous estimates (Barrel of Oil)	(4,206)	259	1,379
Extensions and discoveries (Barrel of Oil)	11,270	14,533	1,183
Sales of minerals in place (Barrel of Oil)	(278)	(364)	(1,112)
Production (Barrel of Oil)	(2,308)	(1,574)	(1,372)
Purchases of minerals in place (Barrel of Oil)	688	8
Balance (Barrel of Oil)	42,237	37,071	24,209
Proved developed reserves (Barrel of Oil)	13,586	10,820	7,818
Porved undeveloped reserves (Barrel of Oil)	28,651	25,808	16,391
Natural Gas Liquids [Member]
Balance (Barrel of Oil)	11,975	8,644	6,556
Revisions of previous estimates (Barrel of Oil)	(1,927)	1,269	2,300
Extensions and discoveries (Barrel of Oil)	1,797	2,813	157
Sales of minerals in place (Barrel of Oil)	(1,303)	(289)	(6)
Production (Barrel of Oil)	(508)	(476)	(363)
Purchases of minerals in place (Barrel of Oil)		14
Balance (Barrel of Oil)	10,034	11,975	8,644
Proved developed reserves (Barrel of Oil)	3,804	3,794	2,568
Porved undeveloped reserves (Barrel of Oil)	6,230	8,181	6,076
Natural Gas [Member]
Balance (Barrel of Oil)	97,828	70,829	75,027
Revisions of previous estimates (Barrel of Oil)	(2,618)	19,311	(1,537)
Extensions and discoveries (Barrel of Oil)	11,475	14,534	1,179
Sales of minerals in place (Barrel of Oil)	(13,491)	(3,958)	(680)
Production (Barrel of Oil)	(4,587)	(3,889)	(3,160)
Purchases of minerals in place (Barrel of Oil)	1,137	1,001
Balance (Barrel of Oil)	89,744	97,828	70,829
Proved developed reserves (Barrel of Oil)	43,271	39,974	27,792
Porved undeveloped reserves (Barrel of Oil)	46,473	57,854	43,037
Oil Equivalents [Member]
Balance (Barrel of Oil)	65,351	44,657	43,190
Revisions of previous estimates (Barrel of Oil)	(6,570)	4,747	3,424
Extensions and discoveries (Barrel of Oil)	14,979	19,768	1,537
Sales of minerals in place (Barrel of Oil)	(3,829)	(1,312)	(1,232)
Production (Barrel of Oil)	(3,580)	(2,698)	(2,262)
Purchases of minerals in place (Barrel of Oil)	877	189
Balance (Barrel of Oil)	67,228	65,351	44,657
Proved developed reserves (Barrel of Oil)	24,602	21,720	15,018
Porved undeveloped reserves (Barrel of Oil)	42,626	43,631	29,639

Note 16 - Supplemental Oil an_8

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Future Net Cash Inflows (Details) - USD ($) $ in Thousands		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Future cash inflows		$ 2,876,976	$ 2,035,619	$ 999,716
Future production costs		(849,063)	(609,921)	(357,917)
Future development costs		(547,163)	(461,619)	(267,836)
Future income tax expense (1)	[1]	(181,224)	(83,915)
Future net cash flows		1,299,526	880,164	373,963
Discount		(647,642)	(474,423)	(213,363)
Standardized Measure of discounted future net cash relating to proved reserves		$ 651,884	$ 405,741	$ 160,600	$ 197,251
[1]	There was no provision for future income tax expense for the year ended December 31, 2016 due to net operating loss carryovers.

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Standardized Measure, beginning of year	$ 405,741	$ 160,600	$ 197,251
Sales and transfers of oil and gas produced, net of production costs	(112,707)	(63,764)	(32,834)
Net change in prices and development and production costs from prior year	268,942	159,661	(58,425)
Extensions, discoveries, and improved recovery, less related costs	153,544	129,277	5,531
Sales of minerals in place	(39,253)	(8,583)	(4,433)
Purchases of minerals in place	8,990	1,238
Revisions of previous estimates	(67,345)	31,044	12,317
Change in timing and other	30,811	1,908	21,468
Change in future income tax expense	(37,413)	(21,700)
Accretion of discount	40,574	16,060	19,725
Standardized Measure, end of year	$ 651,884	$ 405,741	$ 160,600

Note 16 - Supplemental Oil a_10

Note 16 - Supplemental Oil and Gas Disclosures (Unaudited) - Oil and Gas Prices (Details)		12 Months Ended
		Dec. 31, 2018$ / bbl$ / BTU	Dec. 31, 2017$ / bbl$ / BTU	Dec. 31, 2016$ / bbl$ / BTU
Oil (per Bbl) (1) (in USD per Barrel of Oil)	[1]	65.56	51.34	42.74
Gas (per MMbtu) (2) (in USD per British Thermal Unit) | $ / BTU	[2]	3.05	2.99	2.5
Oil (per Bbl) (3) (in USD per Barrel of Oil)	[3]	56.95	46.83	35.54
Gas (per MMbtu) (4) (in USD per British Thermal Unit) | $ / BTU	[4]	1.76	1.79	1.41
NGL's (per Bbl) (5) (in USD per Barrel of Oil)	[5]	19.95	13.19	5.17
[1]	The quoted oil price for the year ended December 31 of each year, 2016, 2017 and 2018 is the 12-month unweighted average first-day-of-the-month West Texas Intermediate spot price for each month of 2016, 2017 and 2018.
[2]	The quoted gas price for the year ended December 31, 2016, 2017 and 2018 is the 12-month unweighted average first-day-of-the-month Henry Hub spot price for each month of 2016, 2017 and 2018.
[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.