Riley Exploration Permian (REPX) 10-Q 13 Nov 19 2019 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Nov. 04, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Entity Registrant Name	TENGASCO INC
Entity Central Index Key	0001001614
Entity Filer Category	Non-accelerated Filer
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		10,658,775
Title of 12(b) Security	Common Stock
Trading Symbol	tgc
Security Exchange Name	NYSE
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current
Cash and cash equivalents	$ 3,482	$ 3,115
Accounts receivable	511	533
Inventory	325	464
Prepaid expenses	192	235
Total current assets	4,510	4,347
Loan fees, net	5	9
Right of use asset - operating leases	55
Oil and gas properties, net (full cost accounting method)	4,344	4,804
Other property and equipment, net	134	190
Accounts receivable - noncurrent	130	130
Other noncurrent assets	4	4
Total assets	9,182	9,484
Current liabilities
Accounts payable - trade	127	132
Accrued liabilities	231	282
Lease liabilities - operating leases - current	56
Lease liabilities - finance leases - current	59
Current maturities of long-term debt		51
Asset retirement obligation - current	83	83
Total current liabilities	556	548
Lease liabilities - operating leases - noncurrent
Lease liabilities - finance leases - noncurrent	29
Long term debt, less current maturities		73
Asset retirement obligation - non current	2,085	2,096
Total liabilities	2,670	2,717
Commitments and contingencies (Note 12)
Preferred stock, 25,000,000 shares authorized:
Series A Preferred stock, $0.0001 par value, 10,000 shares designated; 0 shares issued and outstanding
Common stock, $.001 par value, authorized 100,000,000 shares, 10,653,550 and 10,639,290 shares issued and outstanding	11	11
Additional paid-in capital	58,290	58,276
Accumulated deficit	(51,789)	(51,520)
Total stockholders' equity	6,512	6,767
Total liabilities and stockholders' equity	$ 9,182	$ 9,484

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2019	Dec. 31, 2018
Preferred stock, shares authorized	25,000,000	25,000,000
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	10,653,550	10,639,290
Common stock, shares outstanding	10,653,550	10,639,290
Series A Preferred Stock [Member]
Preferred stock, par value	$ 0.0001	$ 0.0001
Preferred stock, shares authorized	10,000	10,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0

Condensed Consolidated Statemen

Condensed Consolidated Statements Of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues
Revenues	$ 1,215	$ 1,654	$ 3,777	$ 4,497
Cost and expenses
Production costs and taxes	913	862	2,604	2,502
Depreciation, depletion, and amortization	186	219	566	599
General and administrative	297	288	913	896
Total cost and expenses	1,396	1,369	4,083	3,997
Net income (loss) from operations	(181)	285	(306)	500
Other income (expense)
Interest expense	(2)	(1)	(8)	(4)
Gain on sale of assets	1	14	45	34
Total other income (expense)	(1)	13	37	30
Net income (loss) from operations before income tax	(182)	298	(269)	530
Deferred income tax benefit
Net income (loss) from continuing operations	(182)	298	(269)	530
Net income from discontinued operations				1,120
Net income (loss)	$ (182)	$ 298	$ (269)	$ 1,650
Net income (loss) per share - basic and fully diluted
Continuing operations	$ (0.02)	$ 0.03	$ (0.03)	$ 0.05
Discontinued operations				$ 0.11
Shares used in computing earnings per share
Basic and fully diluted	10,653,550	10,624,493	10,648,838	10,624,476
Oil And Gas Proeprties [Member]
Revenues
Revenues	$ 1,215	$ 1,654	$ 3,777	$ 4,497

Condensed Consolidated Statem_2

Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Operating activities
Net income (loss) from continuing operations	$ (269)	$ 530
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, and amortization	566	599
Amortization of loan fees-interest expense	4	3
Accretion on asset retirement obligation	100	106
Gain on asset sales	(45)	(34)
Stock based compensation	14	4
Changes in assets and liabilities:
Accounts receivable	22	(57)
Inventory and other assets	78	(144)
Accounts payable	4	(14)
Accrued and other current liabilities	(51)	30
Settlement on asset retirement obligation	(52)	(5)
Net cash provided by operating activities - continuing operations	371	1,018
Net cash provided by operating activities - discontinued operations		45
Net cash provided by operating activities	371	1,063
Investing activities
Additions to oil and gas properties	(153)	(453)
Proceeds from sale of oil and gas properties	41	7
Additions to other property and equipment	(2)	(28)
Proceeds from sale of other property and equipment		8
Proceeds from sale of materials inventory	150
Net cash provided by (used in) investing activities - continuing operations	36	(466)
Net cash provided by investing activities - discontinued operations		2,650
Net cash provided by investing activities	36	2,184
Financing activities
Repayments of borrowings	(40)	(130)
Proceeds from borrowings		100
Net cash used in financing activities - continuing operations	(40)	(30)
Net cash provided by (used in) financing activities - discontinued operations
Net cash used in financing activities	(40)	(30)
Net change in cash and cash equivalents	367	3,217
Cash and cash equivalents, beginning of period	3,115	185
Cash and cash equivalents, end of period	3,482	3,402
Supplemental cash flow information:
Cash interest payments	4
Supplemental non-cash investing and financing activities:
Financed company vehicles	$ 30	76
Capital expenditures included in accounts payable and accrued liabilities		$ 227

Changes In Stockholders' Equity

Changes In Stockholders' Equity - USD ($) $ in Thousands	Common Stock [Member]	Paid-In Capital [Member]	Accumulated Deficit [Member]	Total
Balance, value at Dec. 31, 2017	$ 11	$ 58,253	$ (53,089)	$ 5,175
Balance, shares at Dec. 31, 2017	10,619,924
Net income (loss)			1,243	1,243
Compensation expense related to stock issued		4		4
Compensation expense related to stock issued, shares	4,569
Balance, shares at Mar. 31, 2018	10,624,493
Balance, value at Mar. 31, 2018	$ 11	58,257	(51,846)	6,422
Balance, value at Dec. 31, 2017	$ 11	58,253	(53,089)	5,175
Balance, shares at Dec. 31, 2017	10,619,924
Net income (loss)				1,650
Balance, shares at Sep. 30, 2018	10,624,493
Balance, value at Sep. 30, 2018	$ 11	58,257	(51,439)	6,829
Balance, value at Mar. 31, 2018	$ 11	58,257	(51,846)	6,422
Balance, shares at Mar. 31, 2018	10,624,493
Net income (loss)			109	109
Compensation expense related to stock issued
Compensation expense related to stock issued, shares
Balance, shares at Jun. 30, 2018	10,624,493
Balance, value at Jun. 30, 2018	$ 11	58,257	(51,737)	6,531
Net income (loss)			298	298
Compensation expense related to stock issued
Compensation expense related to stock issued, shares
Balance, shares at Sep. 30, 2018	10,624,493
Balance, value at Sep. 30, 2018	$ 11	58,257	(51,439)	6,829
Balance, value at Dec. 31, 2018	$ 11	58,276	(51,520)	$ 6,767
Balance, shares at Dec. 31, 2018	10,639,290			10,639,290
Net income (loss)			(96)	$ (96)
Compensation expense related to stock issued		4		4
Compensation expense related to stock issued, shares	4,962
Balance, shares at Mar. 31, 2019	10,644,252
Balance, value at Mar. 31, 2019	$ 11	58,280	(51,616)	6,675
Balance, value at Dec. 31, 2018	$ 11	58,276	(51,520)	$ 6,767
Balance, shares at Dec. 31, 2018	10,639,290			10,639,290
Net income (loss)				$ (269)
Balance, shares at Sep. 30, 2019	10,653,550			10,653,550
Balance, value at Sep. 30, 2019	$ 11	58,290	(51,789)	$ 6,512
Balance, value at Mar. 31, 2019	$ 11	58,280	(51,616)	6,675
Balance, shares at Mar. 31, 2019	10,644,252
Net income (loss)			9	9
Compensation expense related to stock issued		6		6
Compensation expense related to stock issued, shares	4,411
Balance, shares at Jun. 30, 2019	10,648,663
Balance, value at Jun. 30, 2019	$ 11	58,286	(51,607)	6,690
Net income (loss)			(182)	(182)
Compensation expense related to stock issued		4		$ 4
Compensation expense related to stock issued, shares	4,887
Balance, shares at Sep. 30, 2019	10,653,550			10,653,550
Balance, value at Sep. 30, 2019	$ 11	$ 58,290	$ (51,789)	$ 6,512

Description Of Business And Sig

Description Of Business And Significant Accounting Policies	9 Months Ended
	Sep. 30, 2019
Description Of Business And Significant Accounting Policies [Abstract]
Description Of Business And Significant Accounting Policies	(1) D escription of Business and Significant Accounting Policies  Tengasco, Inc. (the “Company”) is a Delaware corporation. The Company is in the business of exploration for and production of oil and natural gas. The Company’s primary area of exploration and production is in Kansas.  The Company’s wholly-owned subsidiary, Manufactured Methane Corporation (“MMC”) operated treatment and delivery facilities in Church Hill, Tennessee for the extraction of methane gas from a landfill for eventual sale as natural gas and for the generation of electricity. The Company sold all its methane facility assets, except the applicable U.S. patent, on January 26, 2018 for $2.65 million. (See Note 10. Discontinued Operations)  Basis of Presentation  The accompanying unaudited condensed consolidated financial statements as of September 30, 2019 and September 30, 2018 have been prepared in accordance with generally accepted accounting principles in the United States of America (“U.S. GAAP”) for interim financial information and with the instructions to Form 10-Q and Item 210 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements. The condensed consolidated balance sheet as of December 31, 2018 is derived from the audited financial statements, but does not include all disclosures required by U.S. GAAP. The Company believes that the disclosures made are adequate to make the information not misleading. In the opinion of management, all adjustments (consisting of only normal recurring accruals) considered necessary for a fair presentation for the periods presented have been included as required by Regulation S-X, Rule 10-01. Operating results for the nine months ended September 30, 2019 are not necessarily indicative of the results that may be expected for the year ended December 31, 2019. It is suggested that these condensed consolidated financial statements be read in conjunction with the Company’s consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018.  Principles of Consolidation  The accompanying condensed consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries after elimination of all significant intercompany transactions and balances.  Use of Estimates  The accompanying condensed consolidated financial statements are prepared in conformity with U.S. GAAP which require management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the dates of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Significant estimates include reserve quantities and estimated future cash flows associated with proved reserves, which significantly impact depletion expense and potential impairments of oil and natural gas properties, income taxes and the valuation of deferred tax assets, stock-based compensation , and commitments and contingencies. We analyze our estimates based on historical experience and various other assumptions that we believe to be reasonable. While we believe that our estimates and assumptions used in preparation of the condensed consolidated financial statements are appropriate, actual results could differ from those estimates and assumptions.  Revenue Recognition  The Company identifies the contracts with each of its customers and the separate performance obligations associated with each of these contracts. Revenues are recognized when the performance obligations are satisfied and when control of goods or services are transferred to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services.  Crude oil is sold on a month-to-month contract at a price based on an index price from the purchaser, net of differentials. Crude oil that is produced is stored in storage tanks. The Company will contact the purchaser and request it to pick up the crude oil from the storage tanks. When the purchaser picks up the crude from the storage tanks, control of the crude transfers to the purchaser, the Company’s contractual obligation is satisfied, and revenues are recognized. The sales of oil represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling oil on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports revenues on a net basis to the Company. Fees and other deductions incurred prior to transfer of control are recorded as production costs. Revenues are reported net of fees and other deductions incurred after transfer of control.  Electricity from the Company’s methane facility was sold on a long term contract. There was no specific quantity of electricity that was required to be delivered under this contract. Electricity passed through sales meters located at the Carter Valley landfill site, at which time control of the electricity transferred to the purchaser, the Company’s contractual obligation was satisfied, and revenues were recognized . The Company sold its methane facility and generation assets on January 26, 2018 and therefore has not recognized revenues associated with any sales volumes after that date. Revenues associated with the methane facility are included in Discontinued Operations. (See Note 10. Discontinued Operations)  The Company operates certain salt water disposal wells, some of which accept water from third parties. The contracts with the third parties primarily require a flat monthly fee for the third parties to dispose water into the wells. In some cases, the contract is based on a per barrel charge to dispose water into the wells. There is no requirement under the contracts for these third parties to use these wells for their water disposal. If the third parties do dispose water into the Company operated wells during a given month, the Company has met its contractual obligations and revenues are recognized for that month.  The following table presents the disaggregated revenue by commodity for the three months and nine months ended September 30, 2019 and 2018 (in thousands) :       For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018   Crude oil $ 1,208 $ 1,647 $ 3,757 $ 4,472  Saltwater disposal fees 7 7 20 25  Total $ 1,215 $ 1,654 $ 3,777 $ 4,497  There were no natural gas imbalances at September 30, 2019 or December 31, 2018.  Cash and Cash Equivalents  Cash and cash equivalents include temporary cash investments with a maturity of ninety days or less at date of purchase.  Inventory  Inventory consists of crude oil in tanks and is carried at lower of cost or market value. The cost component of the oil inventory is calculated using the average cost per barrel for the three months ended September 30, 2019 and December 31, 2018. These costs include production costs and taxes. The market value component is calculated using the average September 2019 and December 2018 oil sales prices received from the Company’s Kansas properties. In addition, at December 31, 2018, the Company recorded equipment and materials to be used in its Kansas operation as inventory and was carried at the lower of cost or market value. The equipment inventory was sold to a third party during the three months ended March 31, 2019. The cost component of the equipment and materials inventory represented the original cost paid for the equipment and materials. The market component is based on estimated sales value for similar equipment and materials at the end of each period. At September 30, 2019 and December 31, 2018, inventory consisted of the following (in thousands) :      September 30, December 31,  2019 2018  Oil – carried at cost $ 325 $ 359  Equipment and materials – carried at market — 105  Total inventory $ 325 $ 464  Full Cost Method of Accounting  The Company follows the full cost method of accounting for oil and gas property acquisition, exploration, and development activities. Under this method, all costs incurred in connection with acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs include lease acquisitions, seismic related costs, certain internal exploration costs, drilling, completion, and estimated asset retirement costs. The capitalized costs of oil and gas properties, plus estimated future development costs relating to proved reserves and estimated asset retirement costs which are not already included, net of estimated salvage value, are amortized on the unit-of-production method based on total proved reserves. The Company has determined its reserves based upon reserve reports provided by LaRoche Petroleum Consultants Ltd. since 2009. The costs of unproved properties are excluded from amortization until the properties are evaluated, subject to an annual assessment of whether impairment has occurred. The Company had $0 in unevaluated properties as of September 30, 2019 and $23,000 at December 31, 2018. Proceeds from the sale of oil and gas properties are accounted for as reductions to capitalized costs unless such sales cause a significant change in the relationship between costs and the estimated value of proved reserves, in which case a gain or loss is recognized.  At the end of each reporting period, the Company performs a “ceiling test” on the value of the net capitalized cost of oil and gas properties. This test compares the net capitalized cost (capitalized cost of oil and gas properties, net of accumulated depreciation, depletion and amortization and related deferred income taxes) to the present value of estimated future net revenues from oil and gas properties using an average price (arithmetic average of the beginning of month prices for the prior 12 months) and current cost discounted at 10% plus cost of properties not being amortized and the lower of cost or estimated fair value of unproven properties included in the cost being amortized (ceiling). If the net capitalized cost is greater than the ceiling, a write-down or impairment is required. A write-down of the carrying value of the asset is a non-cash charge that reduces earnings in the current period. Once incurred, a write-down may not be reversed in a later period. The Company did not record any impairment of its oil and gas properties during the nine months ended September 30, 2019 and 2018.  Accounts Receivable  Accounts receivable consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date, uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days of sales of oil and gas production, and other miscellaneous receivables. No interest is charged on past-due balances. Payments made on accounts receivable are applied first to the earliest unpaid items. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. There was no allowance recorded at September 30, 2019 or December 31, 2018.  The following table sets forth information concerning the Company’s accounts receivable (in thousands) :      September 30, December 31,  2019 2018  Revenue $ 378 $ 396  Tax 129 129  Joint interest 4 8  Accounts receivable - current $ 511 $ 533   Tax - noncurrent $ 130 $ 130 At September 30, 2019 and December 31, 2018, the Company recorded a tax related current receivable of $129,000 and a tax related non-current receivable of $130,000 . (See Note 2. Income Taxes)  Reclassifications  Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2019
Income Taxes [Abstract]
Income Taxes	(2) Income Taxes  Income taxes are reported in accordance with U.S. GAAP, which requires the establishment of deferred tax accounts for all temporary differences between the financial reporting and tax bases of assets and liabilities, using currently enacted federal and state income tax rates. In addition, deferred tax accounts must be adjusted to reflect new rates if enacted into law.  The deferred income tax assets or liabilities for an oil and gas exploration and development company are dependent on many variables such as estimates of the economic lives of depleting oil and gas reserves and commodity prices. Accordingly, the asset or liability is subject to continuous recalculation and revision of the numerous estimates required, and may change significantly in the event of occurrences such as major acquisitions, divestitures, commodity price changes, changes in reserve estimates, changes in reserve lives, and changes in tax rates or tax laws.  The estimated annual effective tax rate of 0% differs from the statutory rate of 21% due primarily to adjustments to the valuation allowance on the deferred tax assets.  At December 31, 2018, federal net operating loss carryforwards amounted to approximately $35.8 million, of which $34.8 million expires between 2019 and 2037, which can offset 100% of taxable income and $1 million that has an indefinite carryforward period which can offset 80% of taxable income per year. The Company has approximately $260,000 in refundable credits, and it expects that a substantial portion will be refunded between 2018 and 2021. As 50% of the credit will be refunded when we file the 2018 tax return, this amount is recorded as a current accounts receivable on the Balance Sheet at September 30, 2019 and December 31, 2018, with balance of this refund recorded as a non-current accounts receivable. The Company recorded a valuation allowance on the remaining deferred tax assets at September 30, 2019 and December 31, 2018 as such amounts were not considered to be more-likely-than-not realizable. There were no recorded unrecognized tax benefits at September 30, 2019 and December 31, 2018.

Capital Stock

Capital Stock	9 Months Ended
	Sep. 30, 2019
Capital Stock [Abstract]
Capital Stock	(3) Capital Stock Common Stock On July 1, 2019, the Company issued 4,887 shares of common stock in the aggregate to the Company’s three directors and CFO and interim CEO. On October 1, 2019, the Company issued 5,225 shares of common stock in the aggregate to the Company’s three directors and CFO and interim CEO.  Rights Agreement Effective March 17, 2017 the Board of Directors declared a dividend of one right (a “ Right ”) for each of the Company’s issued and outstanding shares of common stock, $0.001 par value per share (“ Common Stock ”). The dividend was paid to the stockholders of record at the close of business on March 27, 2017 (the “ Record Date ”). Each Right entitles the registered holder, subject to the terms of the Rights Agreement dated as of March 16, 2017 (the “ Rights Agreement ”) between the Company and the Rights Agent, Continental Stock Transfer & Trust Company, to purchase from the Company one one-thousandth of a share of the Company’s Series A Preferred Stock at a price of $1.10 (the “ Exercise Price ”), subject to certain adjustments. The purpose of the Rights Agreement is to reduce the risk that the Company’s ability to use its net operating losses to reduce potential future federal income tax obligations would be limited if the Company’s experiences an “ownership change,” as defined in Section 382 of the Internal Revenue Code. A company generally experiences an ownership change if the percentage of its stock owned by its “5-percent shareholders,” as defined in Section 382 of the Tax Code, increases by more than 50 percentage points over a rolling three-year period. The Rights Agreement is designed to reduce the likelihood that the Company will experience an ownership change under Section 382 of the Tax Code by discouraging any person or group from becoming a 4.95% shareholder and also discouraging any existing 4.95% (or more) shareholder from acquiring additional shares of the Company’s stock. The Rights will not be exercisable until the “ Distribution Date ”, which is generally defined as the earlier to occur of:(i) a public announcement or filing that a person or group has, become an “ Acquiring Person ” which is defined as a person or group of affiliated or associated persons or persons acting in concert who, at any time after the date of the Rights Agreement, have acquired, or obtained the right to acquire, beneficial ownership of 4.95% or more of the Company’s outstanding shares of Common Stock; or a person or group currently owning 4.95% (or more) of the Company’s outstanding shares acquires additional shares of the Company’s stock; subject to certain exceptions; or (ii) the commencement of, or announcement of an intention to commence, a tender offer or exchange offer the consummation of which would result in any person becoming an Acquiring Person. The Rights, unless extended by the Board of Directors will expire prior to the earlier of March 16, 2020; or a date the Board of Directors determines by resolution in its business judgment that the Agreement is no longer necessary or appropriate; or in certain other specified circumstances. At any time after any person or group of affiliated or associated persons becomes an Acquiring Person, the Board, at its option, may exchange each Right (other than Rights owned by such person or group of affiliated or associated persons which will have become void), in whole or in part, at an exchange ratio of two shares of Common Stock per outstanding Right (subject to adjustment). For further information on the Rights Agreement, please refer to the Rights Agreement that was attached in full as an exhibit to the Company’s Form 8-K filed with SEC on March 17, 2017.  Preferred Stock Series A Preferred Stock has a par value of $0.0001 and 10,000 shares have been designated. No shares of Series A Preferred Stock have been issued by the Company pursuant to the Rights Agreement described above or otherwise.

Earnings Per Common Share

Earnings Per Common Share	9 Months Ended
	Sep. 30, 2019
Earnings Per Common Share [Abstract]
Earnings Per Common Share	(4) Earnings per Common Share  We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share which include the effect of all potentially dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators of our basic and diluted earnings per share, (in thousands except for share and per share amounts):      For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018  Income (numerator):  Net income (loss) from continuing operations $ (182) $ 298 $ (269) $ 530  Net income from discontinued operations $ — $ — $ — $ 1,120  Weighted average shares (denominator):  Weighted average shares – basic 10,653,550 10,624,493 10,648,838 10,624,476  Dilution effect of share-based compensation, treasury method — — — —  Weighted average shares – dilutive 10,653,550 10,624,493 10,648,838 10,624,476  Income (loss) per share – basic and dilutive:  Continuing operations $ (0.02) $ 0.03 $ (0.03) $ 0.05  Discontinued operations $ — $ — $ — $ 0.11  Options issued to the Company’s directors in which the exercise price was higher than the average market price each quarter were excluded from diluted shares as they would have been anti-dilutive . In addition, the shares that would be issued to employees and Company directors if the thirty day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $85 per barrel have also been excluded from this calculation. (See Note 12. Commitments and Contingencies)

Recent Accounting Pronouncement

Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2019
Recent Accounting Pronouncements [Abstract]
Recent Accounting Pronouncements	(5) Recent Accounting Pronouncements  In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) . This guidance was issued to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. This guidance is e ffective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application of the amendments was permitted for all entities. The Company has identified each of its leases and determined the impact of this new guidance on each of the identified leases. The Company implemented ASU 2016-02 Leases (Topic 842) as of January 1, 2019 using the modified retrospective approach. As a result of this implementation, the Company recorded right-of-use assets and liabilities associated with operating leases of approximately $98,000 . There was no transition adjustment related to finance leases.  The Company elected the package of practical expedients within ASU 2016-02 Leases (Topic 842) that allows an entity to not reassess, prior to the effective date, (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification of any expired or existing leases, or (iii) initial direct costs for any existing leases. Additionally, the Company elected the practical expedient to not evaluate existing or expired land easements not previously accounted for as leases prior to the effective date. The Company also made an account policy election not to apply the lease recognition requirements to leases with an initial term of 12 months or less. 

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Related Party Transactions	(6) Related Party Transactions  On September 17, 2007, Hoactzin Partners, L.P. (“Hoactzin”) subscribed to a drilling program offered by the Company consisting of wells to be drilled on the Company’s Kansas Properties (the “Program”). Peter E. Salas, the Chairman of the Board of Directors of the Company, is the controlling person of Hoactzin and of Dolphin Offshore Partners, L.P., the Company’s largest shareholder. Hoactzin was also conveyed a net profits interest in the MMC facility at the Carter Valley municipal solid waste landfill owned and operated by Republic Services, Inc. in Church Hill, Tennessee where the Company installed a propriety combination of advanced gas treatment technology to extract the methane component of the purchased gas stream (the “Methane Project”). As a result of the startup costs, monthly operating expenses, and gas production levels experienced, no net profits as defined were realized during the period from startup in April, 2009 through January 26, 2018 (the date the Company sold the Methane Project to a third party, and the net profits interest of Hoactzin terminated). Consequently, no payment to Hoactzin were made under the net profits interest at any time. In addition, during the fourth quarter of 2018, the Company acquired all of Hoactzin’s working interest in the drilling program wells for $134,690 .  On December 18, 2007, the Company entered into a Management Agreement with Hoactzin to manage on behalf of Hoactzin all of its working interest in certain oil and gas properties owned by Hoactzin and located in the onshore Texas Gulf Coast, and offshore Texas and offshore Louisiana. As part of the consideration for the Company’s agreement to enter into the Management Agreement, Hoactzin granted to the Company an option to participate in up to a 15% working interest on a dollar for dollar cost basis in any new drilling or workover activities undertaken on Hoactzin’s managed properties during the term of the Management Agreement. The Management Agreement expired on December 18, 2012.  The Company entered into a transition agreement with Hoactzin effective December 18, 2012 whereby the Company no longer performs operations, but administratively assists Hoactzin in becoming operator of record of these wells and transferring all bonds from the Company to Hoactzin. This assistance is primarily related to signing the necessary documents to effectuate this transition. Hoactzin and its controlling member are indemnifying the Company for any costs or liabilities incurred by the Company resulting from such assistance or the fact that the Company is the operator of record on certain of these wells. As of the date of this Report, the Company continues to administratively assist Hoactzin with this transition process.

Oil And Gas Properties

Oil And Gas Properties	9 Months Ended
	Sep. 30, 2019
Oil And Gas Properties [Abstract]
Oil And Gas Properties	 (7) Oil and Gas Properties  The following table sets forth information concerning the Company’s oil and gas properties (in thousands) :      September 30, December 31,  2019 2018  Oil and gas properties $ 6,574 $ 6,503  Unevaluated properties — 23  Accumulated depreciation, depletion, and amortization (2,230) (1,722)  Oil and gas properties, net $ 4,344 $ 4,804  The Company recorded depletion expense of $504,000 and $546,000 for the nine months ended September 30, 2019 and 2018, respectively. During the nine months ended September 30, 2019 and 2018, the Company also recorded in “Accumulated depreciation, depletion, and amortization” a $4,000 gain on asset retirement obligations and an $8,000 gain on asset retirement obligations, respectively.

Asset Retirement Obligation

Asset Retirement Obligation	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligation [Abstract]
Asset Retirement Obligation	 (8) Asset Retirement Obligation  Our asset retirement obligations represent the estimated present value of the amount we will incur to plug, abandon, and remediate our producing properties at the end of their productive lives in accordance with applicable laws. The following table summarizes the Company’s Asset Retirement Obligation transactions for the nine months ended September 30, 2019 (in thousands) :      Balance December 31, 2018 $ 2,179  Accretion expense 100  Liabilities incurred —  Liabilities settled (56)  Liabilities relieved - sold properties (55)  Balance September 30, 2019 $ 2,168

Long-Term Debt And Lease Liabil

Long-Term Debt And Lease Liabilities	9 Months Ended
	Sep. 30, 2019
Long-Term Debt And Lease Liabilities [Abstract]
Long-Term Debt And Lease Liabilities	 (9) Long-Term Debt and Lease Liabilities  Long Term Debt  Long-term debt to unrelated entities consisted of the following (in thousands) :      September 30, December 31,  2019 2018  Note payable to a financial institution, with interest only payment until maturity. $ — $ —  Installment notes bearing interest at the rate of 5.0% to 6.5% per annum collateralized by vehicles with monthly payments including interest, insurance and maintenance of approximately $5 — 124  Total long-term debt — 124  Less current maturities — (51)  Long-term debt, less current maturities $ — $ 73  At September 30, 2019, installment notes are recorded to Lease liabilities – finance leases.  At September 30, 2019, the Company had a revolving credit facility with Prosperity Bank. This has historically been the Company’s primary source to fund working capital and capital spending. Under the credit facility, loans and letters of credit are available to the Company on a revolving basis in an amount outstanding not to exceed the lesser of $50 million or the Company’s borrowing base in effect from time to time. As of September 30, 2019, the Company’s borrowing base was $4 million, subject to a credit limit based on current covenants of $3.8 million. The credit facility is secured by substantially all of the Company’s producing and non-producing oil and gas properties. The credit facility includes certain covenants with which the Company is required to comply. At September 30, 2019, these covenants include the following: (a) Current Ratio > 1 :1; (b) Funded Debt to EBITDA < 3.5 x; and (c) Interest Coverage > 3.0 x. At September 30, 2019, the interest rate on this credit facility was 5.50% . The Company was in compliance with all covenants during the quarter ended September 30, 2019. The Company had no outstanding borrowing under the facility as of September 30, 2019 or December 31, 2018.  During July 2019 , the Company’s senior credit facility with Prosperity Bank after Prosperity Bank’s most recent review of the Company’s currently owned producing properties was amended to increase the borrowing base to $4 million , subject to a credit limit based on current covenants of $3.8 million, and the maturity date was extended to July 31, 202 1 . The borrowing base remains subject to the existing periodic redetermination provisions in the credit facility. The interest rate remained prime plus 0.50% per annum. This rate was 6.00% at the date of the amendment. The maximum line of credit of the Company under the Prosperity Bank credit facility remained $50 million. The next borrowing base review will take place in November 2019.  Lease Liabilities  Effective January 1, 2018, the Company adopted ASU 2016-02 Leases (Topic 842) . We first determine if a contract is a lease at inception of the arrangement. To the extent that we determine an arrangement represents a lease, we then classify that lease as an operating lease or a finance lease. As of January 1, 2019, the Company capitalizes its operating leases on the Consolidated Balance Sheet as a right of use asset and a corresponding lease liability. The Company also capitalizes its finance leases on the Consolidated Balance Sheet as other property and equipment and a corresponding lease liability. The right of use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Short term leases that have an initial term of one year or less are not capitalized unless the Company intends to renew the lease to extend the initial term past one year.  We lease certain office space, a storage yard, and field vehicles to support our operations. A more detailed description of the Company’s lease types is included below.  Office and Storage Yard  The Company maintains an office to support its corporate operations. This office agreement is with a third party and was structured with a 39 month initial term. The Company can renew the lease for 36 additional months by providing to the Landlord written notice of intent to exercise the renewal not less than nine months prior to expiration of the initial term. The Company’s corporate office lease is classified as an operating lease.  The Company maintains an office to support its field operations. This office is with a third party and is on a month-to-month lease. However, the Company intends to continue to renew this lease for the foreseeable future. Based on the Company’s intent to renew the lease, the Company is assuming the same lease term as its corporate office lease for calculation of its right of use asset and lease liability. The Company’s field office lease is classified as an operating lease.  The Company maintains a yard to store certain equipment used in its field operations. This storage yard agreement is with a third party and is on a month-to-month lease. However, the Company intends to continue to renew this lease for the foreseeable future. Based on the Company’s intent to renew the lease, the Company is assuming the same lease term as its corporate office lease for calculation of its right of use asset and lease liability. The Company’s storage yard is classified as an operating lease.  Field Vehicles  The Company leases certain vehicles from a third party for use in its field operations. The lease term for each vehicle is based on expected daily use of the vehicles by the field personnel, typically between 18 and 36 months. The Company also pays an upfront fee at the commencement of the lease term. The Company can continue to lease the vehicles past the initial lease term on a month-to-month basis. In addition, each vehicle has a residual value guarantee at the end of the lease term. The Company’s field vehicle leases are classified as finance leases.  Significant Judgment  In order to determine whether the Company’s contracts contain a lease component, the Company is required to exercise significant judgment. The Company will review each contract to determine if: an asset is specified in the contract; the asset is physically distinct; the supplier does not have substantive substitution rights; the Company obtains substantially all economic benefit from use of the asset; and the Company can direct the use of the asset. The Company also determines the appropriate discount rate to use on each lease. If there is a stated rate in the contract, the Company will use the stated rate as its discount rate. The contract associated with the field vehicles includes a stated rate typically between 5% and 6.5% . These stated rates for the field vehicle agreements were used as the discount rates. If there is no stated rate, the Company will use its borrowing rate as the discount rate. The contracts associated with the offices and yard do not include a stated rate. The Company used its borrowing rate of 6% as the discounts rate for these agreements.  Components of lease costs for the three months and nine months ended September 30, 2019 (in thousands):     Period Ended  Three Months Nine Months  Income Statement Account September 30, 2019 September 30, 2019   Operating lease cost:  Production costs and taxes $ 3 $ 10  General and administrative 12 37  Total operating lease cost $ 15 $ 47   Finance lease cost:  Amortization of right of use assets Depreciation, depletion, and amortization $ 21 $ 62  Interest on lease liabilities Net interest expense 1 4  Total finance lease cost $ 22 $ 66  Supplemental lease related cash flow information for the three months and nine months ended September 30, 2019 (in thousands):     Period Ended  Three Months Nine Months  September 30, 2019 September 30, 2019   Cash paid for amounts included in the measurement of lease liabilities:  Operating cash flows from operating leases $ 15 $ 45  Operating cash flows from finance leases 1 4  Finance cash flows from finance leases 9 40   Right of use assets obtained in exchange for lease obligations:  Operating leases — 98  Supplemental lease related balance sheet information as of September 30, 2019 and December 31, 2018 (in thousands):     Balance Sheet as of  September 30, 2019 December 31, 2018   Operating Leases:   Right of use asset - operating leases $ 55 $ —   Lease liabilities - current $ 56 $ —  Lease liabilities - noncurrent — —  Total operating lease liabilities $ 56 $ —    Finance Leases:   Other property and equipment, gross $ 263 $ —  Accumulated depreciation (129) —  Other property and equipment, net $ 134 $ —   Lease liabilities - current $ 59 $ —  Lease liabilities - noncurrent 29 —  Total finance lease liabilities $ 88 $ —  Weighted average remaining lease term and discount rate as of September 30, 2019:     Operating Leases Finance Leases   Weighted average remaining lease term 0.9 years 0.9 years  Weighted average discount rate 6.0% 5.7%  Maturity of lease liabilities as of September 30, 2019 (in thousands):     Operating Leases Finance Leases   2019 (October 2019 - December 2019) $ 16 $ 27  2020 42 43  2021 — 20  Total lease payments 58 90  Less imputed interest (2) (2)  Total $ 56 $ 88 

Discontinued Operations

Discontinued Operations	9 Months Ended
	Sep. 30, 2019
Discontinued Operations [Abstract]
Discontinued Operations	(10) Discontinued Operations  The following table sets forth information concerning the Discontinued Operations (in thousands):     For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018   Revenues $ — $ — $ — $ 6  Production costs and taxes — — — (40)  Depreciation, depletion, and amortization — — — (4)  Interest income — — — 1  Gain on sale of assets — — — 1,157  Deferred income tax benefit — — — —  Net income from discontinued operations $ — $ — $ — $ 1,120    Discontinued operations are related to the Manufactured Methane facilities. The Company sold all its methane facility assets, except the applicable U.S. patent, on January 26, 2018 for $2.65 million.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2019
Fair Value Measurements [Abstract]
Fair Value Measurements	 (11) Fair Value Measurements  FASB ASC 820, “Fair Value Measurements and Disclosures”, establishes a framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under FASB ASC 820 are described as follows:  Level 1 – Observable inputs, such as unadjusted quoted prices in active markets, for substantially identical assets and liabilities.  Level 2 – Observable inputs other than quoted prices within Level 1 for similar assets and liabilities. These include quoted prices for similar assets and liabilities in active markets, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data. If the asset or liability has a specified or contractual term, the input must be observable for substantially the full term of the asset or liability.  Level 3 – Unobservable inputs that are supported by little or no market activity, generally requiring a significant amount of judgment by management. The assets or liabilities fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Valuation techniques used need to maximize the use of observable inputs and minimize the use of unobservable inputs.  The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Further, although the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.  Upon completion of wells, the Company records an asset retirement obligation at fair value using Level 3 assumptions.  Nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis upon impairment. The carrying amounts of other financial instruments including cash and cash equivalents, accounts receivable, account payables, accrued liabilities and long-term debt in our balance sheet approximates fair value as of September 30, 2019 and December 31, 2018.

Commitments And Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments And Contingencies [Abstract]
Commitments And Contingencies	 (12) Commitments and Contingencies  The Company as designated operator of the Hoactzin properties was administratively issued an “Incident of Non-Compliance” by the Bureau of Safety and Environmental Enforcement (“BSEE”) during the quarter ended September 30, 2012 concerning one of Hoactzin’s operated properties. This action called for payment of a civil penalty of $386,000 for failure to provide, upon request, documentation to the BSEE evidencing that certain safety inspections and tests had been conducted in 2011. On July 14, 2015, the federal district court in the Eastern District of Louisiana affirmed the civil penalty without reduction. The Company did not further appeal. In the third quarter of 2015, the Company paid the civil penalty and statutory interest thereon from funds borrowed under its credit facility. In the fourth quarter of 2015, the Company received a return of the cash collateral previously provided to RLI Insurance Company. The Company has not advanced any funds to pay any obligations of Hoactzin and no borrowing capability of the Company has been used in connection with its obligations under the Management Agreement, except for those funds used to pay the civil penalty and interest thereon.  During the second quarter of 2015, the Company received from Hoactzin a copy of an internal analysis prepared by Hoactzin setting out certain issues that Hoactzin may consider to form the basis of operational and other claims against the Company primarily under the Management Agreement. This analysis raised issues other than the “Incident of Non-Compliance” discussed above. The Company is discussing this analysis, as well as the civil penalty discussed above, with Hoactzin in an effort to determine whether there is possibility of a reasonable resolution of some or all of these matters on a negotiated basis .  In the normal course of business, the Company enters into commitments to spend capital on oil and gas properties. Since September 30, 2019, the Company has entered into a drilling commitment in the amount of approximate ly $293,000 . In addition, the Company was in the process of drilling a well at September 30, 2019. Drilling commitments by the Company in excess of costs incurred through September 30, 2019 were approximately $73,000 .  Cost Reduction Measures  Commencing in the quarter ended March 31, 2015 and continuing into the quarter ended June 30, 2018, the Company implemented cost reduction measures including compensation reductions for each employee as well as members of the Board of Directors. These compensation reductions were to remain in place until such time, if any, that the market price of crude oil, calculated as a thirty-day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $70 per barrel. In May 2018, oil prices as so calculated exceeded $70 and compensation reverted to the levels in place before the reductions became effective. At such time, if any, that the market price of crude oil, calculated as a thirty - day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $85 per barrel, all previous reductions made will be reimbursed, a portion which may be paid in stock, to each employee and members of the Board of Directors if is still employed by the Company or still a member of the Board of Directors. For the period January 1, 2015 through September 30, 2019, the reductions were approximately $389,000 . Of the $389,000, approximately $61,000 would be paid in the Company’s common stock. The $61,000 value represents approximately 100,000 common shares valued at $0.61 per share which represents the closing price on September 30, 2019. The Company has not accrued any liabilities associated with these compensation reductions.  Legal Proceedings  The Company is not a party to any pending material legal proceeding. To the knowledge of management, no federal, state, or local governmental agency is presently contemplating any proceeding against the Company which would have a result materially adverse to the Company. To the knowledge of management, no director, executive officer or affiliate of the Company or owner of record or beneficial owner of more than 5% of the Company’s common stock is a party adverse to the Company or has a material interest adverse to the Company in any proceeding .

Description Of Business And S_2

Description Of Business And Significant Accounting Policies (Policy)	9 Months Ended
	Sep. 30, 2019
Description Of Business And Significant Accounting Policies [Abstract]
Basis Of Presentation	Basis of Presentation  The accompanying unaudited condensed consolidated financial statements as of September 30, 2019 and September 30, 2018 have been prepared in accordance with generally accepted accounting principles in the United States of America (“U.S. GAAP”) for interim financial information and with the instructions to Form 10-Q and Item 210 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements. The condensed consolidated balance sheet as of December 31, 2018 is derived from the audited financial statements, but does not include all disclosures required by U.S. GAAP. The Company believes that the disclosures made are adequate to make the information not misleading. In the opinion of management, all adjustments (consisting of only normal recurring accruals) considered necessary for a fair presentation for the periods presented have been included as required by Regulation S-X, Rule 10-01. Operating results for the nine months ended September 30, 2019 are not necessarily indicative of the results that may be expected for the year ended December 31, 2019. It is suggested that these condensed consolidated financial statements be read in conjunction with the Company’s consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018.
Principles Of Consolidation	Principles of Consolidation  The accompanying condensed consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries after elimination of all significant intercompany transactions and balances.
Use Of Estimates	Use of Estimates  The accompanying condensed consolidated financial statements are prepared in conformity with U.S. GAAP which require management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the dates of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Significant estimates include reserve quantities and estimated future cash flows associated with proved reserves, which significantly impact depletion expense and potential impairments of oil and natural gas properties, income taxes and the valuation of deferred tax assets, stock-based compensation , and commitments and contingencies. We analyze our estimates based on historical experience and various other assumptions that we believe to be reasonable. While we believe that our estimates and assumptions used in preparation of the condensed consolidated financial statements are appropriate, actual results could differ from those estimates and assumptions.
Revenue Recognition	Revenue Recognition  The Company identifies the contracts with each of its customers and the separate performance obligations associated with each of these contracts. Revenues are recognized when the performance obligations are satisfied and when control of goods or services are transferred to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services.  Crude oil is sold on a month-to-month contract at a price based on an index price from the purchaser, net of differentials. Crude oil that is produced is stored in storage tanks. The Company will contact the purchaser and request it to pick up the crude oil from the storage tanks. When the purchaser picks up the crude from the storage tanks, control of the crude transfers to the purchaser, the Company’s contractual obligation is satisfied, and revenues are recognized. The sales of oil represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling oil on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports revenues on a net basis to the Company. Fees and other deductions incurred prior to transfer of control are recorded as production costs. Revenues are reported net of fees and other deductions incurred after transfer of control.  Electricity from the Company’s methane facility was sold on a long term contract. There was no specific quantity of electricity that was required to be delivered under this contract. Electricity passed through sales meters located at the Carter Valley landfill site, at which time control of the electricity transferred to the purchaser, the Company’s contractual obligation was satisfied, and revenues were recognized . The Company sold its methane facility and generation assets on January 26, 2018 and therefore has not recognized revenues associated with any sales volumes after that date. Revenues associated with the methane facility are included in Discontinued Operations. (See Note 10. Discontinued Operations)  The Company operates certain salt water disposal wells, some of which accept water from third parties. The contracts with the third parties primarily require a flat monthly fee for the third parties to dispose water into the wells. In some cases, the contract is based on a per barrel charge to dispose water into the wells. There is no requirement under the contracts for these third parties to use these wells for their water disposal. If the third parties do dispose water into the Company operated wells during a given month, the Company has met its contractual obligations and revenues are recognized for that month.  The following table presents the disaggregated revenue by commodity for the three months and nine months ended September 30, 2019 and 2018 (in thousands) :       For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018   Crude oil $ 1,208 $ 1,647 $ 3,757 $ 4,472  Saltwater disposal fees 7 7 20 25  Total $ 1,215 $ 1,654 $ 3,777 $ 4,497  There were no natural gas imbalances at September 30, 2019 or December 31, 2018.
Cash And Cash Equivalents	Cash and Cash Equivalents  Cash and cash equivalents include temporary cash investments with a maturity of ninety days or less at date of purchase.
Inventory	Inventory  Inventory consists of crude oil in tanks and is carried at lower of cost or market value. The cost component of the oil inventory is calculated using the average cost per barrel for the three months ended September 30, 2019 and December 31, 2018. These costs include production costs and taxes. The market value component is calculated using the average September 2019 and December 2018 oil sales prices received from the Company’s Kansas properties. In addition, at December 31, 2018, the Company recorded equipment and materials to be used in its Kansas operation as inventory and was carried at the lower of cost or market value. The equipment inventory was sold to a third party during the three months ended March 31, 2019. The cost component of the equipment and materials inventory represented the original cost paid for the equipment and materials. The market component is based on estimated sales value for similar equipment and materials at the end of each period. At September 30, 2019 and December 31, 2018, inventory consisted of the following (in thousands) :      September 30, December 31,  2019 2018  Oil – carried at cost $ 325 $ 359  Equipment and materials – carried at market — 105  Total inventory $ 325 $ 464 
Full Cost Method Of Accounting	Full Cost Method of Accounting  The Company follows the full cost method of accounting for oil and gas property acquisition, exploration, and development activities. Under this method, all costs incurred in connection with acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs include lease acquisitions, seismic related costs, certain internal exploration costs, drilling, completion, and estimated asset retirement costs. The capitalized costs of oil and gas properties, plus estimated future development costs relating to proved reserves and estimated asset retirement costs which are not already included, net of estimated salvage value, are amortized on the unit-of-production method based on total proved reserves. The Company has determined its reserves based upon reserve reports provided by LaRoche Petroleum Consultants Ltd. since 2009. The costs of unproved properties are excluded from amortization until the properties are evaluated, subject to an annual assessment of whether impairment has occurred. The Company had $0 in unevaluated properties as of September 30, 2019 and $23,000 at December 31, 2018. Proceeds from the sale of oil and gas properties are accounted for as reductions to capitalized costs unless such sales cause a significant change in the relationship between costs and the estimated value of proved reserves, in which case a gain or loss is recognized.  At the end of each reporting period, the Company performs a “ceiling test” on the value of the net capitalized cost of oil and gas properties. This test compares the net capitalized cost (capitalized cost of oil and gas properties, net of accumulated depreciation, depletion and amortization and related deferred income taxes) to the present value of estimated future net revenues from oil and gas properties using an average price (arithmetic average of the beginning of month prices for the prior 12 months) and current cost discounted at 10% plus cost of properties not being amortized and the lower of cost or estimated fair value of unproven properties included in the cost being amortized (ceiling). If the net capitalized cost is greater than the ceiling, a write-down or impairment is required. A write-down of the carrying value of the asset is a non-cash charge that reduces earnings in the current period. Once incurred, a write-down may not be reversed in a later period. The Company did not record any impairment of its oil and gas properties during the nine months ended September 30, 2019 and 2018.
Accounts Receivable	Accounts Receivable  Accounts receivable consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date, uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days of sales of oil and gas production, and other miscellaneous receivables. No interest is charged on past-due balances. Payments made on accounts receivable are applied first to the earliest unpaid items. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. There was no allowance recorded at September 30, 2019 or December 31, 2018.  The following table sets forth information concerning the Company’s accounts receivable (in thousands) :      September 30, December 31,  2019 2018  Revenue $ 378 $ 396  Tax 129 129  Joint interest 4 8  Accounts receivable - current $ 511 $ 533   Tax - noncurrent $ 130 $ 130 At September 30, 2019 and December 31, 2018, the Company recorded a tax related current receivable of $129,000 and a tax related non-current receivable of $130,000 . (See Note 2. Income Taxes)
Reclassifications	Reclassifications  Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income.

Description Of Business And S_3

Description Of Business And Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2019
Description Of Business And Significant Accounting Policies [Abstract]
Disaggregation Of Revenue	   For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018   Crude oil $ 1,208 $ 1,647 $ 3,757 $ 4,472  Saltwater disposal fees 7 7 20 25  Total $ 1,215 $ 1,654 $ 3,777 $ 4,497 
Inventory	   September 30, December 31,  2019 2018  Oil – carried at cost $ 325 $ 359  Equipment and materials – carried at market — 105  Total inventory $ 325 $ 464 
Accounts Receivable	   September 30, December 31,  2019 2018  Revenue $ 378 $ 396  Tax 129 129  Joint interest 4 8  Accounts receivable - current $ 511 $ 533   Tax - noncurrent $ 130 $ 130 

Earnings Per Common Share (Tabl

Earnings Per Common Share (Tables)	9 Months Ended
	Sep. 30, 2019
Earnings Per Common Share [Abstract]
Reconciliations Of The Numerators And Denominators Of Basic And Diluted Earnings Per Share	   For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018  Income (numerator):  Net income (loss) from continuing operations $ (182) $ 298 $ (269) $ 530  Net income from discontinued operations $ — $ — $ — $ 1,120  Weighted average shares (denominator):  Weighted average shares – basic 10,653,550 10,624,493 10,648,838 10,624,476  Dilution effect of share-based compensation, treasury method — — — —  Weighted average shares – dilutive 10,653,550 10,624,493 10,648,838 10,624,476  Income (loss) per share – basic and dilutive:  Continuing operations $ (0.02) $ 0.03 $ (0.03) $ 0.05  Discontinued operations $ — $ — $ — $ 0.11 

Oil And Gas Properties (Tables)

Oil And Gas Properties (Tables)	9 Months Ended
	Sep. 30, 2019
Oil And Gas Properties [Abstract]
Schedule Of Oil And Gas Properties	   September 30, December 31,  2019 2018  Oil and gas properties $ 6,574 $ 6,503  Unevaluated properties — 23  Accumulated depreciation, depletion, and amortization (2,230) (1,722)  Oil and gas properties, net $ 4,344 $ 4,804 

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligation [Abstract]
Asset Retirement Obligation Transactions	   Balance December 31, 2018 $ 2,179  Accretion expense 100  Liabilities incurred —  Liabilities settled (56)  Liabilities relieved - sold properties (55)  Balance September 30, 2019 $ 2,168 

Long-Term Debt And Lease Liab_2

Long-Term Debt And Lease Liabilities (Tables)	9 Months Ended
	Sep. 30, 2019
Long-Term Debt And Lease Liabilities [Abstract]
Schedule Of Long-Term Debt To Unrelated Entites	   September 30, December 31,  2019 2018  Note payable to a financial institution, with interest only payment until maturity. $ — $ —  Installment notes bearing interest at the rate of 5.0% to 6.5% per annum collateralized by vehicles with monthly payments including interest, insurance and maintenance of approximately $5 — 124  Total long-term debt — 124  Less current maturities — (51)  Long-term debt, less current maturities $ — $ 73 
Components Of Lease Cost	  Period Ended  Three Months Nine Months  Income Statement Account September 30, 2019 September 30, 2019   Operating lease cost:  Production costs and taxes $ 3 $ 10  General and administrative 12 37  Total operating lease cost $ 15 $ 47   Finance lease cost:  Amortization of right of use assets Depreciation, depletion, and amortization $ 21 $ 62  Interest on lease liabilities Net interest expense 1 4  Total finance lease cost $ 22 $ 66 
Supplemental Cash Flow Information Related To Leases	  Period Ended  Three Months Nine Months  September 30, 2019 September 30, 2019   Cash paid for amounts included in the measurement of lease liabilities:  Operating cash flows from operating leases $ 15 $ 45  Operating cash flows from finance leases 1 4  Finance cash flows from finance leases 9 40   Right of use assets obtained in exchange for lease obligations:  Operating leases — 98 
Supplemental Balance Sheet Information Related To Leases	  Balance Sheet as of  September 30, 2019 December 31, 2018   Operating Leases:   Right of use asset - operating leases $ 55 $ —   Lease liabilities - current $ 56 $ —  Lease liabilities - noncurrent — —  Total operating lease liabilities $ 56 $ —    Finance Leases:   Other property and equipment, gross $ 263 $ —  Accumulated depreciation (129) —  Other property and equipment, net $ 134 $ —   Lease liabilities - current $ 59 $ —  Lease liabilities - noncurrent 29 —  Total finance lease liabilities $ 88 $ — 
Schedule Of Weighted Average Remaining Lease Term And Discount Rate	  Operating Leases Finance Leases   Weighted average remaining lease term 0.9 years 0.9 years  Weighted average discount rate 6.0% 5.7% 
Maturity Analysis For Operating and Finance Lease Liabilities	  Operating Leases Finance Leases   2019 (October 2019 - December 2019) $ 16 $ 27  2020 42 43  2021 — 20  Total lease payments 58 90  Less imputed interest (2) (2)  Total $ 56 $ 88 

Discontinued Operations (Tables

Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2019
Discontinued Operations [Abstract]
Schedule Of The Amounts In Net Loss From Discontinued Operations	  For the Three Months Ended For the Nine Months Ended  September 30, September 30,  2019 2018 2019 2018   Revenues $ — $ — $ — $ 6  Production costs and taxes — — — (40)  Depreciation, depletion, and amortization — — — (4)  Interest income — — — 1  Gain on sale of assets — — — 1,157  Deferred income tax benefit — — — —  Net income from discontinued operations $ — $ — $ — $ 1,120 

Description Of Business And S_4

Description Of Business And Significant Accounting Policies (Narrative) (Details) - USD ($)	Jan. 26, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Description Of Business And Significant Accounting Policies [Line Items]
Unevaluated properties		$ 0		$ 23,000
Impairment		0	$ 0
Sale of methane facility assets	$ 2,650,000
Accounts receivable - current		511,000		533,000
Allowance for doubtful accounts		0
Tax [Member]
Description Of Business And Significant Accounting Policies [Line Items]
Accounts receivable - current		129,000		129,000
Accounts receivable - noncurrent		$ 130,000		$ 130,000

Description Of Business And S_5

Description Of Business And Significant Accounting Policies (Disaggregation Of Revenue) (Details) - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue	$ 1,215,000	$ 1,654,000	$ 3,777,000	$ 4,497,000
Crude Oil [Member]
Disaggregation of Revenue [Line Items]
Revenue	1,208,000	1,647,000	3,757,000	4,472,000
Saltwater Disposal Fees [Member]
Disaggregation of Revenue [Line Items]
Revenue	$ 7,000	$ 7,000	20,000	$ 25,000
Natural Gas Imbalances [Member]
Disaggregation of Revenue [Line Items]
Revenue			$ 0		$ 0

Description Of Business And S_6

Description Of Business And Significant Accounting Policies (Inventory) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Description Of Business And Significant Accounting Policies [Abstract]
Oil - carried at cost	$ 325	$ 359
Equipment and materials - carried at market		105
Total inventory	$ 325	$ 464

Description Of Business And S_7

Description Of Business And Significant Accounting Policies (Accounts Receivable) (Details) - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable - current	$ 511,000	$ 533,000
Revenue [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable - current	378,000	396,000
Tax [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable - current	129,000	129,000
Accounts receivable - noncurrent	130,000	130,000
Joint Interest [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable - current	$ 4,000	$ 8,000

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Income Taxes [Line Items]
Unrecognized tax benefits	$ 0	$ 0
Federal net operating loss carryforwards		35,800,000
Federal tax rate	21.00%
Refundable credits		260,000
Estimated annual effective tax rate	0.00%
Tax Period Between 2019 And 2037 [Member]
Income Taxes [Line Items]
Federal net operating loss carryforwards		34,800,000
Indefinite Tax Period [Member]
Income Taxes [Line Items]
Federal net operating loss carryforwards		$ 1,000,000
Minimum [Member] | Tax Period Between 2019 And 2037 [Member]
Income Taxes [Line Items]
Federal net operating loss carryforwards expiration between, years	Jan. 1, 2019
Maximum [Member] | Tax Period Between 2019 And 2037 [Member]
Income Taxes [Line Items]
Federal net operating loss carryforwards expiration between, years	Dec. 31, 2037

Capital Stock (Narrative) (Deta

Capital Stock (Narrative) (Details)	Oct. 01, 2019itemshares	Jul. 01, 2019itemshares	Mar. 17, 2017$ / shares	Sep. 30, 2019$ / sharesshares	Dec. 31, 2018$ / sharesshares	Mar. 16, 2017$ / shares
Capital Stock [Line Items]
Common stock, par value | $ / shares			$ 0.001	$ 0.001	$ 0.001
Number of directors | item		3
Preferred stock, shares authorized				25,000,000	25,000,000
Rights Plan [Member]
Capital Stock [Line Items]
Number of preferred share purchase right for each outstanding share of its common stock to shareholder | $ / shares			$ 1
Common stock, Threshold for exercise of rights percentage			4.95%
Subsequent Event [Member]
Capital Stock [Line Items]
Number of directors | item	3
Right [Member]
Capital Stock [Line Items]
Date declared				Mar. 17, 2017
Date to be paid				Mar. 27, 2017
Date of record				Mar. 16, 2017
Directors, CFO And Interim CEO [Member]
Capital Stock [Line Items]
Common stock, New shares issued		4,887
Directors, CFO And Interim CEO [Member] | Subsequent Event [Member]
Capital Stock [Line Items]
Common stock, New shares issued	5,225
Series A Preferred Stock [Member]
Capital Stock [Line Items]
Preferred stock, par value | $ / shares				$ 0.0001	$ 0.0001
Preferred stock, shares issued				0	0
Preferred stock, shares authorized				10,000	10,000
Dividends conversion ratio				0.001
Exercise price | $ / shares						$ 1.10
Series A Preferred Stock [Member] | Rights Plan [Member]
Capital Stock [Line Items]
Preferred stock, shares issued				0

Earnings Per Common Share (Narr

Earnings Per Common Share (Narrative) (Details)	9 Months Ended
	Sep. 30, 2019$ / bbl
Derivative [Line Items]
Period of trailing average of WTI	30 days
Minimum [Member] | West Texas Intermediate [Member]
Derivative [Line Items]
Compensation reimbursement	85

Earnings Per Common Share (Reco

Earnings Per Common Share (Reconciliations Of The Numerators And Denominators Of Basic And Diluted Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Earnings Per Common Share [Abstract]
Net income (loss) from continuing operations	$ (182)	$ 298	$ (269)	$ 530
Net income from discontinued operations				$ 1,120
Weighted average shares - basic	10,653,550	10,624,493	10,648,838	10,624,476
Dilution effect of share-based compensation, treasury method
Weighted average shares - dilutive	10,653,550	10,624,493	10,648,838	10,624,476
Continuing operations	$ (0.02)	$ 0.03	$ (0.03)	$ 0.05
Discontinued operations				$ 0.11

Recent Accounting Pronounceme_2

Recent Accounting Pronouncements (Narrative) (Details)	Sep. 30, 2019USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease, Right-of-use asset	$ 55,000
Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease, Right-of-use asset	98,000
Finance Lease, Right-of-Use Asset	$ 0

Related Party Transactions (Nar

Related Party Transactions (Narrative) (Details) - USD ($)	Dec. 18, 2007	Dec. 31, 2018	Sep. 30, 2019	Jan. 31, 2018
Related Party Transaction [Line Items]
Working interest percent	15.00%
Payments to acquire interest in the drilling program wells		$ 134,690
Hoactzin Partners, L.P. [Member] | Methane Project [Member]
Related Party Transaction [Line Items]
Net profits			$ 0	$ 0

Oil And Gas Properties (Narrati

Oil And Gas Properties (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Oil And Gas Properties [Abstract]
Depletion expense	$ 504,000	$ 546,000
Gain (loss) on asset retirement obligations	$ 4,000	$ 8,000

Oil And Gas Properties (Schedul

Oil And Gas Properties (Schedule Of Oil And Gas Properties) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Oil And Gas Properties [Abstract]
Oil and gas properties	$ 6,574	$ 6,503
Unevaluated properties		23
Accumulated depreciation, depletion, and amortization	(2,230)	(1,722)
Oil and gas properties, net	$ 4,344	$ 4,804

Asset Retirement Obligation (As

Asset Retirement Obligation (Asset Retirement Obligation Transactions) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Asset Retirement Obligation [Abstract]
Balance	$ 2,179
Accretion expense	100	$ 106
Liabilities incurred
Liabilities settled	(56)
Liabilities relieved - sold properties	(55)
Balance	$ 2,168

Long-Term Debt And Lease Liab_3

Long-Term Debt And Lease Liabilities (Narrative) (Details)	1 Months Ended	9 Months Ended
	Jul. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
Borrowing rate		6.00%
Office [Member]
Debt Instrument [Line Items]
Term of contract		39 months
Lease renewal term		36 months
Prosperity Bank [Member]
Debt Instrument [Line Items]
Rate above prime	0.50%
Interest rate	6.00%	5.50%
Credit facility maximum borrowing capacity	$ 3,800,000
Credit facility current borrowing capacity	$ 4,000,000	$ 4,000,000
Credit facility amount outstanding		0	$ 0
Credit limit		3,800,000
Prosperity Bank [Member] | Loans And Letters Of Credit [Member]
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity		$ 50,000,000
Maximum [Member]
Debt Instrument [Line Items]
Borrowing rate		6.50%
Maximum [Member] | Vehicles [Member]
Debt Instrument [Line Items]
Term of contract		36 months
Discount rate		6.50%
Maximum [Member] | Prosperity Bank [Member]
Debt Instrument [Line Items]
Funded debt to EBITDA		3.5
Minimum [Member]
Debt Instrument [Line Items]
Borrowing rate		5.00%
Minimum [Member] | Vehicles [Member]
Debt Instrument [Line Items]
Term of contract		18 months
Discount rate		5.00%
Minimum [Member] | Prosperity Bank [Member]
Debt Instrument [Line Items]
Current ratio		1
Interest coverage		3

Long-Term Debt And Lease Liab_4

Long-Term Debt And Lease Liabilities (Schedule Of Long-Term Debt To Unrelated Entities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Note payable to a financial institution, with interest only payment until maturity
Installment notes bearing interest at the rate of 5.0% to 6.5% per annum collateralized by vehicles with monthly payments including interest, insurance and maintenance of approximately $5		124
Total long-term debt		124
Less current maturities		(51)
Long-term debt, less current maturities		$ 73
Interest rate per annum	6.00%
Periodic payments including interest, insurance and maintenance	$ 5
Maximum [Member]
Debt Instrument [Line Items]
Interest rate per annum	6.50%
Minimum [Member]
Debt Instrument [Line Items]
Interest rate per annum	5.00%

Long-Term Debt And Lease Liab_5

Long-Term Debt And Lease Liabilities (Components Of Lease Cost) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Lease Cost [Line Items]
Total operating lease cost	$ 15	$ 47
Amortization of right of use assets	21	62
Interest on lease liabilities	1	4
Total finance lease cost	22	66
Production Costs And Taxes [Member]
Lease Cost [Line Items]
Total operating lease cost	3	10
General and Administrative [Member]
Lease Cost [Line Items]
Total operating lease cost	$ 12	$ 37

Long-Term Debt And Lease Liab_6

Long-Term Debt And Lease Liabilities (Supplemental Cash Flow Information Related To Leases) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Long-Term Debt And Lease Liabilities [Abstract]
Operating cash flows from operating leases	$ 15	$ 45
Operating cash flows from finance leases	1	4
Finance cash flows from finance leases	$ 9	40
Right of use assets obtained in exchange for lease obligations, Operating leases		$ 98

Long-Term Debt And Lease Liab_7

Long-Term Debt And Lease Liabilities (Supplemental Balance Sheet Information Related To Leases) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Long-Term Debt And Lease Liabilities [Abstract]
Right of use asset - operating leases	$ 55
Lease liabilities - current	56
Lease liabilities - noncurrent
Total operating lease liabilities	56
Other property and equipment, gross	263
Accumulated depreciation	(129)
Other property and equipment, net	134
Lease liabilities - current	59
Lease liabilities - noncurrent	29
Total finance lease liabilities	$ 88

Long-Term Debt And Lease Liab_8

Long-Term Debt And Lease Liabilities (Schedule Of Weighted Average Remaining Lease Term And Discount Rate) (Details)	Sep. 30, 2019
Long-Term Debt And Lease Liabilities [Abstract]
Weighted average remaining lease term, Operating Leases	10 months 24 days
Weighted average discount rate, Operating Leases	6.00%
Weighted average remaining lease term, Finance Leases	10 months 24 days
Weighted average discount rate, Finance Leases	5.70%

Long-Term Debt And Lease Liab_9

Long-Term Debt And Lease Liabilities (Maturity Analysis For Operating and Finance Lease Liabilities) (Details) $ in Thousands	Sep. 30, 2019USD ($)
Long-Term Debt And Lease Liabilities [Abstract]
2019 (October 2019 - December 2019)	$ 16
2020	42
Total lease payments	58
Less imputed interest	(2)
Total operating lease liabilities	56
2019 (October 2019 - December 2019)	27
2020	43
2021	20
Total lease payments	90
Less imputed interest	(2)
Total finance lease liabilities	$ 88

Discontinued Operations (Schedu

Discontinued Operations (Schedule Of The Amounts In Net Loss From Discontinued Operations) (Details) - USD ($) $ in Thousands	Jan. 26, 2018	Sep. 30, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net income from discontinued operations		$ 1,120
Sale of methane facility assets	$ 2,650
Discontinued Operations [Member] | Methane Facilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues		6
Production costs and taxes		(40)
Depreciation, depletion, and amortization		(4)
Interest income		1
Gain on sale of assets		1,157
Net income from discontinued operations		$ 1,120

Commitments And Contingencies (

Commitments And Contingencies (Narrative) (Details)	9 Months Ended	57 Months Ended
	Sep. 30, 2019USD ($)$ / shares$ / bblshares	Sep. 30, 2019USD ($)$ / shares	Sep. 30, 2012USD ($)
Loss Contingencies [Line Items]
Cost reduction		$ 389,000
Cost reduction paid into common stock	$ 61,000
Shares issued for services | shares	100,000
Share price | $ / shares	$ 0.61	$ 0.61
Period of trailing average of WTI	30 days
Drilling commitment	$ 293,000	$ 293,000
Drilling commitment incurred	73,000
Cost reduction liability accrued	$ 0	$ 0
Incidence Of Non-Compliance [Member]
Loss Contingencies [Line Items]
Maximum potential loss			$ 386,000
Minimum [Member] | West Texas Intermediate [Member]
Loss Contingencies [Line Items]
Compensation reduction | $ / bbl	70
Compensation reimbursement | $ / bbl	85