10-Q

U.S. Securities and Exchange Commission

Washington, D.C. 20549

Form 10-Q

QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2019

Commission File No. 1-15555

Tengasco, Inc.

(Exact name of registrant as specified in its charter)

Delaware	87-0267438
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)

8000 E. Maplewood Ave, Suite 130, Greenwood Village, CO 80111

(Address of principal executive offices)

720-420-4460

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.   Yes ☒   No ☐

Indicate by checkmark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).   ☒ Yes    ☐ No

Indicate by check mark whether the registrant is a large accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer  ☐	Accelerated filer  ☐
Non-accelerated filer  ☐	Smaller reporting company  ☒
	Emerging growth company  ☐ If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act  ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).   Yes ☐   No ☒

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock	TGC	NYSE American

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 10,648,663 common shares at May 6, 2019.

TABLE OF CONTENTS

		PAGE
PART I.	FINANCIAL INFORMATION
	ITEM 1. FINANCIAL STATEMENTS
	*    Unaudited Condensed Consolidated Balance Sheets as of March 31, 2019 and December 31, 2018	3
	*    Unaudited Condensed Consolidated Statements of Operations for the three months ended March 31, 2019 and 2018	5
	*    Unaudited Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2019 and 2018	6
	*    Notes to Unaudited Condensed Consolidated Financial Statements	7
	ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	18
	ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	19
	ITEM 4. CONTROLS AND PROCEDURES	21
PART II.	OTHER INFORMATION	21
	ITEM 1. LEGAL PROCEEDINGS	21
	ITEM 1A. RISK FACTORS	21
	ITEM 2. UNREGISTERD SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	21
	ITEM 3. DEFAULTS UPON SENIOR SECURITIES	21
	ITEM 4. MINE SAFTY DISCLOSURES	21
	ITEM 5. OTHER INFORMATION	21
	ITEM 6. EXHIBITS	22
	*    SIGNATURES	23
	*    CERTIFICATIONS

Tengasco, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(unaudited)

(in thousands, except share data)

	March 31, 2019		December 31, 2018
Assets
Current
Cash and cash equivalents	$	3,224	$	3,115
Accounts receivable		608		533
Inventory		423		464
Prepaid expenses		226		235
Total current assets		4,481		4,347
Loan fees, net		7		9
Right of use asset - operating leases		84		—
Oil and gas properties, net (full cost accounting method)		4,650		4,804
Other property and equipment, net		169		190
Accounts receivable - noncurrent		130		130
Other noncurrent assets		4		4
Total assets	$	9,525	$	9,484

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

3

Tengasco, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(unaudited)

(in thousands, except share data)

	March 31, 2019			December 31, 2018
Liabilities and Stockholders’ Equity
Current liabilities
Accounts payable – trade	$	173		$	132
Accrued liabilities		267			282
Lease liabilities - operating leases - current		59			—
Lease liabilities - finance leases - current		77			—
Current maturities of long-term debt		—			51
Asset retirement obligation - current		83			83
Total current liabilities		659			548
Lease liabilities - operating leases - noncurrent		25			—
Lease liabilities - finance leases - noncurrent		35			—
Long term debt, less current maturities		—			73
Asset retirement obligation - noncurrent		2,131			2,096
Total liabilities		2,850			2,717
Commitments and contingencies (Note 13)
Stockholders’ equity
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; 10,644,252 and 10,639,290 shares issued and outstanding		11			11
Additional paid–in capital		58,280			58,276
Accumulated deficit		(51,616	)		(51,520	)
Total stockholders’ equity		6,675			6,767
Total liabilities and stockholders’ equity	$	9,525		$	9,484

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

4

Tengasco, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(unaudited)

(in thousands, except share and per share data)

	For the Three Months Ended March 31,
	2019			2018
Revenues
Oil and gas properties	$	1,171		$	1,367
Total revenues		1,171			1,367
Cost and expenses
Production costs and taxes		779			730
Depreciation, depletion, and amortization		184			183
General and administrative		346			336
Total cost and expenses		1,309			1,249
Net income (loss) from operations		(138	)		118
Other expense
Net interest expense		(3	)		(1	)
Gain on sale of assets		45			16
Total other expenses		42			15
Income (loss) from continuing operations before income tax		(96	)		133
Deferred income tax benefit		—			—
Net income (loss) from continuing operations		(96	)		133
Net income from discontinued operations		—			1,110
Net income (loss)	$	(96	)	$	1,243
Net income (loss) per share - Basic and Fully Diluted
Continuing operations	$	(0.01	)	$	0.01
Discontinued operations	$	—		$	0.10
Shares used in computing earnings per share
Basic and fully diluted		10,644,197			10,624,442

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

5

Tengasco, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(unaudited)

(in thousands)

	For the Three Months Ended March 31,
	2019			2018
Operating activities
Net income (loss) from continuing operations	$	(96	)	$	133
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, depletion, and amortization		184			183
Amortization of loan fees-interest expense		2			1
Accretion on asset retirement obligation		35			36
Gain on asset sales		(45	)		(16	)
Stock based compensation		4			4
Changes in assets and liabilities:
Accounts receivable		(75	)		(33	)
Inventory and other assets		(55	)		(200	)
Accounts payable		50			(48	)
Accrued and other current liabilities		(15	)		18
Settlement on asset retirement obligation		(7	)		(7	)
Net cash provided by (used in) operating activities - continuing operations		(18	)		71
Net cash provided by operating activities - discontinued operations		—			67
Net cash provided by (used in) operating activities		(18	)		138
Investing activities
Additions to oil and gas properties		(11	)		(32	)
Proceeds from sale of oil and gas properties		—			3
Additions to other property and equipment		—			(19	)
Proceeds from sale of other property and equipment		—			7
Proceeds from sale of materials inventory		150			—
Net cash provided by (used in) investing activities - continuing operations		139			(41	)
Net cash provided by investing activities - discontinued operations		—			2,650
Net cash provided by investing activities		139			2,609
Financing activities
Repayments of borrowings		(12	)		(116	)
Proceeds from borrowings		—			100
Net cash used in financing activities - continuing operations		(12	)		(16	)
Net cash provided by (used in) financing activities - discontinued operations		—			—
Net cash used in financing activities		(12	)		(16	)
Net change in cash and cash equivalents		109			2,731
Cash and cash equivalents, beginning of period		3,115			185
Cash and cash equivalents, end of period	$	3,224		$	2,916
Supplemental cash flow information:
Cash interest payments	$	1		$	—
Supplemental non-cash investing and financing activities:
Financed company vehicles	$	—		$	109
Capital expenditures included in accounts payable and accrued liabilities	$	—		$	6

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

6

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

(1) Description 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 11. Discontinued Operations)

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements as of March 31, 2019 and March 31, 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 three months ended March 31, 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.

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 it transfers control of goods or services to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods 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 them 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.  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 will not recognize revenues associated with any sales volumes after that date.  Revenues associated with the methane facility are included in Discontinued Operations.  (See Note 11. Discontinued Operations)

7

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

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 in 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 ended March 31, 2019 and 2018 (in thousands):

	March 31, 2019		March 31, 2018
Crude oil	$	1,164	$	1,357
Salt water disposal fees		7		10
Total	$	1,171	$	1,367

There were no natural gas imbalances at March 31, 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 March 31, 2019 and December 31, 2018.  These costs include production costs and taxes.  The market value component is calculated using the average March 2019 and December 2018 oil sales prices received from the Company’s Kansas properties.  In addition, at December 31, 2018, the Company also carried equipment and materials to be used in its Kansas operation 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 March 31, 2019 and December 31, 2018, inventory consisted of the following (in thousands):

	March 31, 2019		December 31, 2018
Oil – carried at cost	$	423	$	359
Equipment and materials – carried at market		—		105
Total inventory	$	423	$	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 March 31, 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.

8

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

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 three months ended March 31, 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 March 31, 2019 and December 31, 2018.

The following table sets forth information concerning the Company’s accounts receivable (in thousands):

	March 31, 2019		December 31, 2018
Revenue	$	474	$	396
Tax		129		129
Joint interest		5		8
Accounts receivable - current	$	608	$	533
Tax - noncurrent	$	130	$	130

At March 31, 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 3. Income Taxes)

Reclassifications

Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income.

(2) Changes in Stockholders’ Equity

Three Months Ended March 31, 2019:

	Common Stock				Paid-in Capital		Accumulated Deficit			Total
	Shares		Amount
Balance, December 31, 2018		10,639,290	$	11	$	58,276	$	(51,520	)	$	6,767
Net loss		—		—		—		(96	)		(96	)
Compensation expense related to stock issued		4,962		—		4		—			4
Balance, March 31, 2019		10,644,252	$	11	$	58,280	$	(51,616	)	$	6,675

9

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

Three Months Ended March 31, 2018:

	Common Stock				Paid-in Capital		Accumulated Deficit			Total
	Shares		Amount
Balance, December 31, 2017		10,619,924	$	11	$	58,253	$	(53,089	)	$	5,175
Net income		—		—		—		1,243			1,243
Compensation expense related to stock issued		4,569		—		4		—			4
Balance, March 31, 2018		10,624,493	$	11	$	58,257	$	(51,846	)	$	6,422

(3) 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 $35.6 million, of which $34.6 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 March 31, 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 March 31, 2019 and December 31, 2018 as such amounts were not considered to be more-likely-than-not realizable due to cumulative losses incurred during the preceding 3 year period.  There were no recorded unrecognized tax benefits at March 31, 2019 and December 31, 2018.

(4) Capital Stock

Common Stock

On January 2, 2019, the Company issued 4,962 shares of common stock in the aggregate to the Company’s three directors and CFO and interim CEO.

On April 1, 2019, the Company issued 4,411 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.

10

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

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 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.

(5) 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 March 31,
	2019			2018
Income (numerator):
Net income (loss) from continuing operations	$	(96	)	$	133
Net income from discontinued operations	$	—		$	1,110
Weighted average shares (denominator):
Weighted average shares – basic		10,644,197			10,624,442
Dilution effect of share-based compensation, treasury method		—			—
Weighted average shares – dilutive		10,644,197			10,624,442
Income (loss) per share – Basic and Dilutive:
Continuing operations	$	(0.01	)	$	0.01
Discontinued operations	$	—		$	0.10

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 13. Commitments and Contingencies)

11

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

(6) 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 guidanceis effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years.  Early application of the amendments in this Update is 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 contract 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.

(7) 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, for payment to Hoactzin under the net profits interest.  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.

(8) Oil and Gas Properties

The following table sets forth information concerning the Company’s oil and gas properties (in thousands):

	March 31, 2019			December 31, 2018
Oil and gas properties	$	6,528		$	6,503
Unevaluated properties		—			23
Accumulated depreciation, depletion, and amortization		(1,878	)		(1,722	)
Oil and gas properties	$	4,650		$	4,804

12

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

The Company recorded depletion expense of $163,000 and $172,000 for the three months ended March 31, 2019 and 2018, respectively.  During the three months ended March 31, 2019 and 2018, the Company also recorded in “Accumulated depreciation, depletion, and amortization” a $(7,000) loss on asset retirement obligations and a $7,000 gain on asset retirement obligations, respectively.

(9) 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 three months ended March 31, 2019 (in thousands):

Balance December 31, 2018	$	2,179
Accretion expense		35
Liabilities incurred		—
Liabilities settled		—
Balance March 31, 2019	$	2,214

(10) Long-Term Debt and Lease Liabilities

Long Term Debt

Long-term debt to unrelated entities consisted of the following (in thousands):

	March 31, 2019		December 31, 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 debt		—		124
Less current maturities		—		(51	)
Long-term debt, less current maturities	$	—	$	73

At March 31, 2019, installment notes are recorded to Lease liabilities – finance leases.

At March 31, 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 March 31, 2019, the Company’s borrowing base was $3 million, subject to a credit limit based on current covenants of approximately $2.74 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 March 31, 2019, these covenants include the following: (a) Current Ratio > 1:1; (b) Funded Debt to EBITDA < 3.5x; and (c) Interest Coverage > 3.0x.  At March 31, 2019, the interest rate on this credit facility was 6.00%.  The Company was in compliance with all covenants during the quarter ended March 31, 2019.  The Company had no outstanding borrowing under the facility as of March 31, 2019 or December 31, 2018.  The next borrowing base review will take place in May 2019.

Lease Liabilities

Effective January 1, 2018, the Company adopted ASU 2016-02 Leases (Topic 842).  We determined if a contract is a lease at inception of the arrangement.  To the extent that we determine an arrangement represents a lease, we 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.

13

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

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 Judgements

In order to determine whether the Company’s contracts contain a lease component, the Company is required to excise significant judgement.  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 ended March 31, 2019 (in thousands):

	Income Statement Account	March 31, 2019
Operating lease cost:
	Production costs and taxes	$	3
	General and administrative		12
Total operating lease cost		$	15
Finance lease cost:
Amortization of right of use assets	Depreciation, depletion and amortization	$	21
Interest on lease liabilities	Net interest expense		1
Total finance lease cost		$	22

14

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

Supplemental lease related cash flow information for the three months ended March 31, 2019 (in thousands):

	March 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	15
Operating cash flows from finance leases		1
Finance cash flows from finance leases		12
Right of use assets obtained in exchange for lease obligations:
Operating leases		98

Supplemental lease related balance sheet information as of March 31, 2019 (in thousands):

	March 31, 2019
Operating Leases
Right of use asset – operating leases	$	84
Lease liabilities - current	$	59
Lease liabilities - noncurrent		25
Total operating lease liabilities	$	84
Finance Leases
Other property and equipment, gross	$	293
Accumulated depreciation		(124	)
Other property and equipment, net	$	169
Lease liabilities - current	$	77
Lease liabilities - noncurrent		35
Total finance lease liabilities	$	112

Weighted average remaining lease term and discount rate as of March 31, 2019:

	Operating Leases			Finance Leases
Weighted average remaining lease term		1.4 years		1.4 years
Weighted average discount rate		6.0	%		5.7	%

Maturity of lease liabilities as of March 31, 2019 (in thousands):

	Operating Leases			Finance Leases
2019 (April 2019 – December 2019)	$	46		$	65
2020		42			37
2021		-			16
Total lease payments		88			118
Less imputed interest		(4	)		(6	)
Total	$	84		$	112

15

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

(11) Discontinued Operations

The following table sets forth information concerning the Discontinued Operations (in thousands):

	For the Three Months Ended March 31,
	2019		2018
Revenues	$	—	$	6
Production costs and taxes		—		(50	)
Depreciation, depletion, and amortization		—		(4	)
Interest income		—		1
Gain on sale of assets		—		1,157
Net income from discontinued operations	$	—	$	1,110

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.

(12) 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 March 31, 2019 and December 31, 2018.

(13) 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.

16

Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

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.

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 March 31, 2019, the reductions were approximately $432,000.  Of the $432,000, approximately $103,000 will be paid in the Company’s common stock.  The $103,000 value represents approximately 100,000 common share valued at $1.03 per share which represents the closing price on March 29, 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 beneficially 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.

17

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Results of Operations and Financial Condition

During the first three months of 2019, 30.0 MBbl gross of oil were sold from the Company’s properties.  Of the 30.0 MBbl sold, 23.4 MBbl were net to the Company after required payments to all of the royalty interests and drilling program participants.  The Company’s net sales from its properties during the first three months of 2019 of 23.4 MBbl of oil compares to net sales of 23.7 MBbl of oil during the first three months of 2018.  The Company’s net revenue from its oil and gas properties was $1.2 million during the first three months of 2019 compared to $1.4 million during the first three months of 2018.  This decrease in net revenue was primarily due to a $175,000 decrease related to an $7.48 per barrel decrease in the average oil price from $57.36 per barrel during the first three months of 2018 to $49.88 per barrel during the first three months of 2019, and a $17,000 decrease related to approximately a 300 Bbl decrease in sales volumes.  The 300 Bbl decrease was primarily due to natural declines, partially offset by increased production on the Veverka D lease as a result of a polymer work performed in the second quarter 2018, and by increased production on the BSU #1-30 well which was completed in October 2018.

Comparison of the Quarters Ended March 31, 2019 and 2018

The Company reported a net loss from continuing operations of $(96,000) or $(0.01) per share of common stock during the first quarter of 2019 compared to a net income from continuing operations of $133,000 or $0.01 per share of common stock during the first quarter of 2018.  The $229,000 decrease in net income was primarily due to a $196,000 decrease in revenues, a $49,000 increase in production cost and taxes, partially offset by a $29,000 increase in gain on sale of assets.

The Company recognized $1.2 million in revenues during the first quarter of 2019 compared to $1.4 million during the first quarter of 2018. The $196,000 decrease in net revenue was primarily due to a $175,000 decrease related to an $7.48 per barrel decrease in the average oil price from $57.36 per barrel during the first three months of 2018 to $49.88 per barrel during the first three months of 2019, and a $17,000 decrease related to approximately a 300 Bbl decrease in sales volumes.  The 300 Bbl decrease was primarily due to natural declines, partially offset by increased production on the Veverka D lease as a result of a polymer performed in the second quarter 2018, and by increased production on the BSU #1-30 well which was completed in October 2018.

Production cost and taxes increased $49,000 from $730,000 during the first quarter of 2019 to $779,000 during the first quarter of 2018.  This decrease was primarily due to a $51,000 increase related to change in the oil inventory quarterly adjustments, a $20,000 increase in pumping charges primarily related to replacement of a company pumper with a contract pumper, and a $17,000 increase in chemical costs, partially offset by a $38,000 decrease in well and equipment repair costs.

Gain on sale of assets increased $29,000 from $16,000 during the first quarter of 2018 to $45,000 during the first quarter of 2019.  This increase was primarily related to recording sale of equipment inventory to a third party during the first quarter of 2019, partially offset by recording gains on sales of company vehicles during the first quarter of 2018.

Liquidity and Capital Resources

At March 31, 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 future 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 March 31, 2019, the Company’s borrowing base was $3 million, subject to a credit limit based on current covenants of approximately $2.74 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 March 31, 2019, these covenants include the following: (a) Current Ratio > 1:1; (b) Funded Debt to EBITDA < 3.5x; and (c) Interest Coverage > 3.0x.  At March 31, 2019, the interest rate on this credit facility was 6.00%.  The Company was in compliance with all covenants during the quarter ended March 31, 2019.  The Company had no outstanding borrowing under the facility as of March 31, 2019 or December 31, 2018.  The next borrowing base review will take place in May 2019.

Net cash used in operating activities from continuing operations was $18,000 during the first three months of 2019 compared to $71,000 provided by operating activities from continuing operations during the first three months of 2018.  Cash flow used in working capital was $102,000 during the first three months of 2019 compared to $270,000 used in working capital during the first three months of 2018. The $168,000 decrease in cash flow used in working capital was primarily due to changes in inventory, and changes in accounts payable.  The $89,000 decrease in cash provided by operating activities was primarily due to a $196,000 decrease in revenues, and a $49,000 increase in production cost and taxes, partially offset by the $168,000 decrease in cash flow used in working capital.  Net cash provided by investing activities from continuing operations was $139,000 during the first three months of 2019 compared to $(41,000) used in investing activities from continuing operations during the first three months of 2018.  This increase in cash flow provided by investing activities was primarily due to sale of materials inventory to a third party during the first three months of 2019.  Cash flow used in financing activities from continuing operations during the first three months of 2019 was $(12,000) compared to $(16,000) used in financing activities during the first three months of 2018.

18

Critical Accounting Policies

Effective January 1, 2019, the Company adopted ASU 2016-02 Leases (Topic 842).

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.

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 March 31, 2019, the reductions were approximately $432,000.  Of the $432,000, approximately $103,000 will be paid in the Company’s common stock.  The $103,000 value represents approximately 100,000 common share valued at $1.03 per share which represents the closing price on March 29, 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 beneficially 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.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company’s Borrowing Base under its Credit Facility may be reduced by the lender.

The borrowing base under the Company’s revolving credit facility will be determined from time to time by the lender, consistent with its customary natural gas and crude oil lending practices. Reductions in estimates of the Company’s natural gas and crude oil reserves could result in a reduction in the Company’s borrowing base, which would reduce the amount of financial resources available under the Company’s revolving credit facility to meet its capital requirements. Such a reduction could be the result of lower commodity prices or production, inability to drill or unfavorable drilling results, changes in natural gas and crude oil reserve engineering, the lender’s inability to agree to an adequate borrowing base or adverse changes in the lenders’ practices regarding estimation of reserves.  If cash flow from operations or the Company’s borrowing base decreases for any reason, the Company’s ability to undertake exploration and development activities could be adversely affected.  As a result, the Company’s ability to replace naturally declining production may be limited. In addition, if the borrowing base is reduced, the Company may be required to pay down its borrowings under the revolving credit facility so that outstanding borrowings do not exceed the reduced borrowing base. This requirement could further reduce the cash available to the Company for capital spending and, if the Company did not have sufficient capital to reduce its borrowing level, could cause the Company to default under its revolving credit facility.

19

As of March 31, 2019, the Company’s borrowing base was $3 million, subject to a credit limit based on current covenants of approximately $2.74 million, of which zero had been drawn down by the Company.  The Company’s next periodic borrowing base review will take place in May 2019.

Commodity Risk

The Company's major market risk exposure is in the pricing applicable to its oil production.  Realized pricing is primarily driven by the prevailing worldwide price for crude oil.  Historically, prices received for oil and gas production have been volatile and unpredictable and price volatility is expected to continue.  The average monthly Kansas oil prices received during the first three months of 2019 ranged from a low of $46.39 per barrel to a high of $52.93 per barrel.

As of March 31, 2019, the Company has no open positions related to derivative agreements relating to commodities.

Interest Rate Risk

At March 31, 2019, the Company had balances on financing leases outstanding of approximately $112,000, and no balance owed on its credit facility with Prosperity Bank.  As of March 31, 2019, the interest rate on the credit facility was variable at a rate equal to prime plus 0.50% per annum.  The Company’s credit facility interest rate at March 31, 2019 was 6.00%.  The Company’s financing leases of $112,000 have fixed interest rates ranging from 5.0% to 6.5%.

The annual impact on interest expense and the Company’s cash flows of a 10% increase in the interest rate on the credit facility would be approximately zero assuming borrowed amounts under the credit facility remained at the same amount owed as of March 31, 2019.  The Company did not have any open derivative contracts relating to interest rates at March 31, 2019 or December 31, 2018.

Forward-Looking Statements and Risk

Certain statements in this report, including statements of the future plans, objectives, and expected performance of the Company, are forward-looking statements that are dependent upon certain events, risks and uncertainties that may be outside the Company’s control, and which could cause actual results to differ materially from those anticipated. Some of these include, but are not limited to, the market prices of oil and gas, economic and competitive conditions, inflation rates, legislative and regulatory changes, financial market conditions, political and economic uncertainties of foreign governments, future business decisions, and other uncertainties, all of which are difficult to predict.

There are numerous uncertainties inherent in projecting future rates of production and the timing of development expenditures. The total amount or timing of actual future production may vary significantly from estimates. The drilling of exploratory wells can involve significant risks, including those related to timing, success rates and cost overruns. Lease and rig availability, complex geology and other factors can also affect these risks.  Additionally, fluctuations in oil and gas prices, or a prolonged period of low prices, may substantially adversely affect the Company's financial position, results of operations, and cash flows.

20

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The Company’s Chief Executive Officer and Chief Financial Officer has evaluated the effectiveness of the Company’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Based on such evaluation, the Company’s Chief Executive Officer and Chief Financial Officer has concluded that the Company’s disclosure controls and procedures, as of the end of the period covered by this Report, were adequate and effective to provide reasonable assurance that information required to be disclosed by the Company in reports that it files or submits under the Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms. The effectiveness of a system of disclosure controls and procedures is subject to various inherent limitations, including cost limitations, judgments used in decision making, assumptions about the likelihood of future events, the soundness of internal controls, and fraud. Due to such inherent limitations, there can be no assurance that any system of disclosure controls and procedures will be successful in preventing all errors or fraud, or in making all material information known in a timely manner to the appropriate levels of management.

Changes in Internal Controls

During the three months ended March 31, 2019, there have been no changes to the Company’s system of internal controls over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company’s system of controls over financial reporting.  As part of a continuing effort to improve the Company’s business processes, management is evaluating its internal controls and may update certain controls to accommodate any modifications to its business processes or accounting procedures.

PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

ITEM 1A. RISK FACTORS

Refer to Item 1A Risk Factors in the Company’s Report on Form 10-K for the year ended December 31, 2018 filed on March 28, 2019 which is incorporated by this reference.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not Applicable

ITEM 5. OTHER INFORMATION

None.

21

ITEM 6. EXHIBITS

The following exhibits are filed with this report:

31	Certification of the Chief Executive Officer and Chief Financial Officer, pursuant to Exchange Act Rule, Rule 13a-14a/15d-14a.
32	Certification of the Chief Executive Officer and Chief Financial Officer, pursuant to 18 U.S.C Section 1350 as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Calculation Linkbase Document
101.DEF	XBRL Taxonomy Definition Linkbase Document
101.LAB	XBRL Taxonomy Label Linkbase Document
101.PRE	XBRL Taxonomy Presentation Linkbase Document

22

SIGNATURES

Pursuant to the requirements of the Securities and Exchange Act of 1934, the Registrant duly caused this report to be signed on its behalf by the undersigned hereto duly authorized.

Dated:  May 14, 2019

TENGASCO, INC.

By:	/s/Michael J. Rugen
	Michael J. Rugen
	Chief Executive Officer and Chief Financial Officer

23

EX-31

Exhibit 31   CERTIFICATION

I, Michael J. Rugen, certify that:

1.  I have reviewed this Quarterly Report on Form 10-Q of Tengasco, Inc. for the quarter ended March 31, 2019.

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other information included in this annual report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.  The registrant’s certifying officers are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-(f) for the registrant and we have:

(a)  designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)  designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)  disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.  The Registrant’s certifying officers have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)  All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)  Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Dated: May 14, 2019
By:	/s/ Michael J. Rugen
	Michael J. Rugen
	Chief Executive Officer and Chief Financial Officer

EX-32

Exhibit 32

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 I hereby certify that:

I have reviewed the Quarterly Report on Form 10-Q for the quarter ended March 31, 2019.

To the best of my knowledge this Quarterly Report on Form 10-Q (i) fully complies with the requirements of section 13(a) or 15(d) of the Securities and Exchange Act of 1934 (15 U.S.C. 78m (a) or 78o (d)); and, (ii) the information contained in this Report fairly present, in all material respects, the financial condition and results of operations of Tengasco, Inc. and its subsidiaries during the period covered by this report.

Dated:  May 14, 2019

By:	/s/ Michael J. Rugen
	Michael J. Rugen
	Chief Executive Officer and Chief Financial Officer

XML

Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2019	May 06, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
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		10,648,663
Trading Symbol	tgc
Entity Small Business	true
Entity Emerging Growth Company	false

XML

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Current
Cash and cash equivalents	$ 3,224	$ 3,115
Accounts receivable	608	533
Inventory	423	464
Prepaid expenses	226	235
Total current assets	4,481	4,347
Loan fees, net	7	9
Right-of-use asset - operating leases	84
Oil and gas properties, net (full cost accounting method)	4,650	4,804
Other property and equipment, net	169	190
Accounts receivable - noncurrent	130	130
Other noncurrent assets	4	4
Total assets	9,525	9,484
Current liabilities
Accounts payable - trade	173	132
Accrued liabilities	267	282
Lease liabilities - operating leases - current	59
Lease liabilities - finance leases - current	77
Current maturities of long-term debt		51
Asset retirement obligation - current	83	83
Total current liabilities	659	548
Lease liabilities - operating leases - noncurrent	25
Lease liabilities - finance leases - noncurrent	35
Long term debt, less current maturities		73
Asset retirement obligation - non current	2,131	2,096
Total liabilities	2,850	2,717
Commitments and contingencies (Note 13)
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, 10,644,252 and 10,639,290 shares issued and outstanding	11	11
Additional paid-in capital	58,280	58,276
Accumulated deficit	(51,616)	(51,520)
Total stockholders' equity	6,675	6,767
Total liabilities and stockholders' equity	$ 9,525	$ 9,484

XML

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 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	10,644,252	10,639,290
Common stock, shares outstanding	10,644,252	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

XML

Condensed Consolidated Statements Of Operations - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Revenues
Revenues	$ 1,171	$ 1,367
Cost and expenses
Production costs and taxes	779	730
Depreciation, depletion, and amortization	184	183
General and administrative	346	336
Total cost and expenses	1,309	1,249
Net income (loss) from operations	(138)	118
Other expense
Net interest expense	(3)	(1)
Gain on sale of assets	45	16
Total other expense	42	15
Income (loss) from continuing operations before income tax	(96)	133
Deferred income tax benefit
Net income (loss) from continuing operations	(96)	133
Net income from discontinued operations		1,110
Net income (loss)	$ (96)	$ 1,243
Net income (loss) per share - Basic and Fully Diluted
Continuing operations	$ (0.01)	$ 0.01
Discontinued operations		$ 0.10
Shares used in computing earnings per share
Basic and fully diluted	10,644,197	10,624,442
Oil And Gas Proeprties [Member]
Revenues
Revenues	$ 1,171	$ 1,367

XML

Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating activities
Net income (loss) from continuing operations	$ (96)	$ 133
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
Depreciation, depletion, and amortization	184	183
Amortization of loan fees-interest expense	2	1
Accretion of asset retirement obligation	35	36
Gain on asset sales	(45)	(16)
Stock based compensation	4	4
Changes in assets and liabilities:
Accounts receivable	(75)	(33)
Inventory and other assets	(55)	(200)
Accounts payable	50	(48)
Accrued and other current liabilities	(15)	18
Settlement on asset retirement obligation	(7)	(7)
Net cash provided by (used in) operating activities - continuing operations	(18)	71
Net cash provided by operating activities - discontinued operations		67
Net cash provided by (used in) operating activities	(18)	138
Investing activities
Additions to oil and gas properties	(11)	(32)
Proceeds from sale of oil and gas properties		3
Additions to other property and equipment		(19)
Proceeds from sale of other property and equipment		7
Proceeds from sale of materials inventory	150
Net cash provided by (used in) investing activities - continuing operations	139	(41)
Net cash provided by investing activities - discontinued operations		2,650
Net cash provided by investing activities	139	2,609
Financing activities
Repayment of borrowings	(12)	(116)
Proceeds from borrowings		100
Net cash used in financing activities	(12)	(16)
Net cash provided by (used in) financing activities - discontinued operations
Net cash used in financing activities	(12)	(16)
Net change in cash and cash equivalents	109	2,731
Cash and cash equivalents, beginning of period	3,115	185
Cash and cash equivalents, end of period	3,224	2,916
Supplemental cash flow information:
Cash interest payments	$ 1
Supplemental non-cash investing and financing activities:
Financed company vehicles		109
Capital expenditures included in accounts payable and accrued liabilities		$ 6

XML

Description Of Business And Significant Accounting Policies

3 Months Ended

Mar. 31, 2019

Description Of Business And Significant Accounting Policies [Abstract]

Description Of Business And Significant Accounting Policies

(1)  Description 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 11. Discontinued Operations)

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements as of March 31, 2019 and March 31, 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 three months ended March 31, 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.

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 it transfers control of goods or services to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods 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 them 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.  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 will not recognize revenues associated with any sales volumes after that date.  Revenues associated with the methane facility are included in Discontinued Operations.  (See Note 11. 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 in 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 ended March 31, 2019 and 2018 (in thousands):  

	March 31,		March 31,
	2019		2018
Crude oil	$	1,164	$	1,357
Salt water disposal fees		7		10
Total	$	1,171	$	1,367

There were no natural gas imbalances at March 31, 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 March 31, 2019 and December 31, 2018.  These costs include production costs and taxes.  The market value component is calculated using the average March 2019 and December 2018 oil sales prices received from the Company’s Kansas properties.  In addition, at December 31, 2018, the Company also carried equipment and materials to be used in its Kansas operation 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 March 31, 2019 and December 31, 2018, inventory consisted of the following (in thousands):

	March 31,		December 31,
	2019		2018
Oil – carried at cost	$	423	$	359
Equipment and materials – carried at market		—		105
Total inventory	$	423	$	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 March 31, 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 three months ended March 31, 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 March 31, 2019 and December 31, 2018.

The following table sets forth information concerning the Company’s accounts receivable (in thousands):

	March 31,		December 31,
	2019		2018
Revenue	$	474	$	396
Tax		129		129
Joint interest		5		8
Accounts receivable - current	$	608	$	533
Tax - noncurrent	$	130	$	130

At March 31, 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 3. Income Taxes) 

Reclassifications

Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income. 

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Changes in Stockholders' Equity

3 Months Ended

Mar. 31, 2019

Changes in Stockholders' Equity [Abstract]

Changes in Stockholders' Equity

(2) Changes in Stockholders’ Equity

Three Months Ended March 31, 2019:
	Common Stock			Paid-in		Accumulated
	Shares	Amount		Capital		Deficit		Total
Balance, December 31, 2018	10,639,290	$	11	$	58,276	$	(51,520)	$	6,767
Net loss	—		—		—		(96)		(96)
Compensation expense related to stock issued	4,962		—		4		—		4
Balance, March 31, 2019	10,644,252	$	11	$	58,280	$	(51,616)	$	6,675

Three Months Ended March 31, 2018:
	Common Stock			Paid-in		Accumulated
	Shares	Amount		Capital		Deficit		Total
Balance, December 31, 2017	10,619,924	$	11	$	58,253	$	(53,089)	$	5,175
Net income	—		—		—		1,243		1,243
Compensation expense related to stock issued	4,569		—		4		—		4
Balance, March 31, 2018	10,624,493	$	11	$	58,257	$	(51,846)	$	6,422

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Income Taxes

3 Months Ended

Mar. 31, 2019

Income Taxes [Abstract]

Income Taxes

(3)  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 $35.6 million, of which $34.6 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 March 31, 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 March 31, 2019 and December 31, 2018 as such amounts were not considered to be more-likely-than-not realizable due to cumulative losses incurred during the preceding 3 year period.  There were no recorded unrecognized tax benefits at March 31, 2019 and December 31, 2018. 

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Capital Stock

3 Months Ended

Mar. 31, 2019

Capital Stock [Abstract]

Capital Stock

(4) Capital Stock

Common Stock

On January 2, 2019, the Company issued 4,962 shares of common stock in the aggregate to the Company’s three directors and CFO and interim CEO.

On April 1, 2019, the Company issued 4,411 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 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.

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Earnings Per Common Share

3 Months Ended

Mar. 31, 2019

Earnings Per Common Share [Abstract]

Earnings Per Common Share

(5)  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
	March 31,
	2019		2018
Income (numerator):
Net income (loss) from continuing operations	$	(96)	$	133
Net income from discontinued operations	$	—	$	1,110
Weighted average shares (denominator):
Weighted average shares – basic		10,644,197		10,624,442
Dilution effect of share-based compensation, treasury method		—		—
Weighted average shares – dilutive		10,644,197		10,624,442
Income (loss) per share – Basic and Dilutive:
Continuing operations	$	(0.01)	$	0.01
Discontinued operations	$	—	$	0.10

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 13. Commitments and Contingencies)

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Recent Accounting Pronouncements

3 Months Ended

Mar. 31, 2019

Recent Accounting Pronouncements [Abstract]

Recent Accounting Pronouncements

(6)  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 guidanceis effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years.  Early application of the amendments in this Update is 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 contract 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.

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Related Party Transactions

3 Months Ended

Mar. 31, 2019

Related Party Transactions [Abstract]

Related Party Transactions

(7) 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, for payment to Hoactzin under the net profits interest.  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.

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Oil And Gas Properties

3 Months Ended

Mar. 31, 2019

Oil And Gas Properties [Abstract]

Oil And Gas Properties

(8)  Oil and Gas Properties

The following table sets forth information concerning the Company’s oil and gas properties (in thousands):

	March 31,		December 31,
	2019		2018
Oil and gas properties	$	6,528	$	6,503
Unevaluated properties		—		23
Accumulated depreciation, depletion, and amortization		(1,878)		(1,722)
Oil and gas properties	$	4,650	$	4,804

The Company recorded depletion expense of $163,000 and $172,000 for the three months ended March 31, 2019 and 2018, respectively.  During the three months ended March 31, 2019 and 2018, the Company also recorded in “Accumulated depreciation, depletion, and amortization” a $(7,000) loss on asset retirement obligations and a $7,000 gain on asset retirement obligations, respectively.

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Asset Retirement Obligation

3 Months Ended

Mar. 31, 2019

Asset Retirement Obligation [Abstract]

Asset Retirement Obligation

(9)  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 three months ended March 31, 2019 (in thousands):

Balance December 31, 2018	$	2,179
Accretion expense		35
Liabilities incurred		—
Liabilities settled		—
Balance March 31, 2019	$	2,214

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Long-Term Debt And Lease Liabilities

3 Months Ended

Mar. 31, 2019

Long-Term Debt And Lease Liabilities [Abstract]

Long-Term Debt And Lease Liabilities

(10)  Long-Term Debt and Lease Liabilities

Long Term Debt

Long-term debt to unrelated entities consisted of the following (in thousands):

	March 31,		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 debt		—		124
Less current maturities		—		(51)
Long-term debt, less current maturities	$	—	$	73

At March 31, 2019, installment notes are recorded to Lease liabilities – finance leases.

At March 31, 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 March 31, 2019, the Company’s borrowing base was $3 million, subject to a credit limit based on current covenants of approximately $2.74 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 March 31, 2019, these covenants include the following: (a) Current Ratio > 1:1; (b) Funded Debt to EBITDA < 3.5x; and (c) Interest Coverage > 3.0x.  At March 31, 2019, the interest rate on this credit facility was 6.00%.  The Company was in compliance with all covenants during the quarter ended March 31, 2019.  The Company had no outstanding borrowing under the facility as of March 31, 2019 or December 31, 2018.  The next borrowing base review will take place in May 2019. 

Lease Liabilities

Effective January 1, 2018, the Company adopted ASU 2016-02 Leases (Topic 842).We determined if a contract is a lease at inception of the arrangement.  To the extent that we determine an arrangement represents a lease, we 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 Judgements

In order to determine whether the Company’s contracts contain a lease component, the Company is required to excise significant judgement.  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 ended March 31, 2019 (in thousands):

	Income Statement Account	March 31, 2019
Operating lease cost:
	Production costs and taxes	$	3
	General and administrative		12
Total operating lease cost		$	15
Finance lease cost:
Amortization of right of use assets	Depreciation, depletion and amortization	$	21
Interest on lease liabilities	Net interest expense		1
Total finance lease cost		$	22

Supplemental lease related cash flow information for the three months ended March 31, 2019 (in thousands):

	March 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	15
Operating cash flows from finance leases		1
Finance cash flows from finance leases		12
Right of use assets obtained in exchange for lease obligations:
Operating leases		98

Supplemental lease related balance sheet information as of March 31, 2019 (in thousands):

	March 31, 2019
Operating Leases
Right of use asset – operating leases	$	84
Lease liabilities - current	$	59
Lease liabilities - noncurrent		25
Total operating lease liabilities	$	84
Finance Leases
Other property and equipment, gross	$	293
Accumulated depreciation		(124)
Other property and equipment, net	$	169
Lease liabilities - current	$	77
Lease liabilities - noncurrent		35
Total finance lease liabilities	$	112

Weighted average remaining lease term and discount rate as of March 31, 2019:

	Operating Leases		Finance Leases
Weighted average remaining lease term		1.4 years		1.4 years
Weighted average discount rate		6.0%		5.7%

Maturity of lease liabilities as of March 31, 2019 (in thousands):

	Operating Leases		Finance Leases
2019 (April 2019 – December 2019)	$	46	$	65
2020		42		37
2021		-		16
Total lease payments		88		118
Less imputed interest		(4)		(6)
Total	$	84	$	112

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Discontinued Operations

3 Months Ended

Mar. 31, 2019

Discontinued Operations [Abstract]

Discontinued Operations

(11)  Discontinued Operations

The following table sets forth information concerning the Discontinued Operations (in thousands):

	For the Three Months Ended
	March 31,
	2019		2018
Revenues	$	—	$	6
Production costs and taxes		—		(50)
Depreciation, depletion, and amortization		—		(4)
Interest income		—		1
Gain on sale of assets		—		1,157
Net income from discontinued operations	$	—	$	1,110

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.

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Fair Value Measurements

3 Months Ended

Mar. 31, 2019

Fair Value Measurements [Abstract]

Fair Value Measurements

(12)  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 March 31, 2019 and December 31, 2018.

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Commitments And Contingencies

3 Months Ended

Mar. 31, 2019

Commitments And Contingencies [Abstract]

Commitments And Contingencies

(13)  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.

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 March 31, 2019, the reductions were approximately $432,000.  Of the $432,000, approximately $103,000 will be paid in the Company’s common stock.  The $103,000 value represents approximately 100,000 common share valued at $1.03 per share which represents the closing price on March 29, 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 beneficially 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.

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Description Of Business And Significant Accounting Policies (Policy)

3 Months Ended

Mar. 31, 2019

Description Of Business And Significant Accounting Policies [Abstract]

Basis Of Presentation

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements as of March 31, 2019 and March 31, 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 three months ended March 31, 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.

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 it transfers control of goods or services to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods 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 them 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.  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 will not recognize revenues associated with any sales volumes after that date.  Revenues associated with the methane facility are included in Discontinued Operations.  (See Note 11. 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 in 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 ended March 31, 2019 and 2018 (in thousands):  

	March 31,		March 31,
	2019		2018
Crude oil	$	1,164	$	1,357
Salt water disposal fees		7		10
Total	$	1,171	$	1,367

There were no natural gas imbalances at March 31, 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 March 31, 2019 and December 31, 2018.  These costs include production costs and taxes.  The market value component is calculated using the average March 2019 and December 2018 oil sales prices received from the Company’s Kansas properties.  In addition, at December 31, 2018, the Company also carried equipment and materials to be used in its Kansas operation 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 March 31, 2019 and December 31, 2018, inventory consisted of the following (in thousands):

	March 31,		December 31,
	2019		2018
Oil – carried at cost	$	423	$	359
Equipment and materials – carried at market		—		105
Total inventory	$	423	$	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 March 31, 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 three months ended March 31, 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 March 31, 2019 and December 31, 2018.

The following table sets forth information concerning the Company’s accounts receivable (in thousands):

	March 31,		December 31,
	2019		2018
Revenue	$	474	$	396
Tax		129		129
Joint interest		5		8
Accounts receivable - current	$	608	$	533
Tax - noncurrent	$	130	$	130

At March 31, 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 3. Income Taxes) 

Reclassifications

Reclassifications

Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income. 

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Description Of Business And Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2019

Description Of Business And Significant Accounting Policies [Abstract]

Disaggregation Of Revenue

	March 31,		March 31,
	2019		2018
Crude oil	$	1,164	$	1,357
Salt water disposal fees		7		10
Total	$	1,171	$	1,367

Inventory

	March 31,		December 31,
	2019		2018
Oil – carried at cost	$	423	$	359
Equipment and materials – carried at market		—		105
Total inventory	$	423	$	464

Accounts Receivable

	March 31,		December 31,
	2019		2018
Revenue	$	474	$	396
Tax		129		129
Joint interest		5		8
Accounts receivable - current	$	608	$	533
Tax - noncurrent	$	130	$	130

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Changes in Stockholders' Equity (Tables)

3 Months Ended

Mar. 31, 2019

Changes in Stockholders' Equity [Abstract]

Changes In Stockholders' Equity

Three Months Ended March 31, 2019:
	Common Stock			Paid-in		Accumulated
	Shares	Amount		Capital		Deficit		Total
Balance, December 31, 2018	10,639,290	$	11	$	58,276	$	(51,520)	$	6,767
Net loss	—		—		—		(96)		(96)
Compensation expense related to stock issued	4,962		—		4		—		4
Balance, March 31, 2019	10,644,252	$	11	$	58,280	$	(51,616)	$	6,675

Three Months Ended March 31, 2018:
	Common Stock			Paid-in		Accumulated
	Shares	Amount		Capital		Deficit		Total
Balance, December 31, 2017	10,619,924	$	11	$	58,253	$	(53,089)	$	5,175
Net income	—		—		—		1,243		1,243
Compensation expense related to stock issued	4,569		—		4		—		4
Balance, March 31, 2018	10,624,493	$	11	$	58,257	$	(51,846)	$	6,422

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Earnings Per Common Share (Tables)

3 Months Ended

Mar. 31, 2019

Earnings Per Common Share [Abstract]

Reconciliations Of The Numerators And Denominators On Basic And Diluted Earnings Per Share

	For the Three Months Ended
	March 31,
	2019		2018
Income (numerator):
Net income (loss) from continuing operations	$	(96)	$	133
Net income from discontinued operations	$	—	$	1,110
Weighted average shares (denominator):
Weighted average shares – basic		10,644,197		10,624,442
Dilution effect of share-based compensation, treasury method		—		—
Weighted average shares – dilutive		10,644,197		10,624,442
Income (loss) per share – Basic and Dilutive:
Continuing operations	$	(0.01)	$	0.01
Discontinued operations	$	—	$	0.10

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Oil And Gas Properties (Tables)

3 Months Ended

Mar. 31, 2019

Oil And Gas Properties [Abstract]

Schedule Of Oil And Gas Properties

	March 31,		December 31,
	2019		2018
Oil and gas properties	$	6,528	$	6,503
Unevaluated properties		—		23
Accumulated depreciation, depletion, and amortization		(1,878)		(1,722)
Oil and gas properties	$	4,650	$	4,804

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Asset Retirement Obligation (Tables)

3 Months Ended

Mar. 31, 2019

Asset Retirement Obligation [Abstract]

Asset Retirement Obligation Transactions

Balance December 31, 2018	$	2,179
Accretion expense		35
Liabilities incurred		—
Liabilities settled		—
Balance March 31, 2019	$	2,214

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Long-Term Debt And Lease Liabilities (Tables)

3 Months Ended

Mar. 31, 2019

Long-Term Debt And Lease Liabilities [Abstract]

Schedule Of Long-term Debt To Unrelated Entites

	March 31,		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 debt		—		124
Less current maturities		—		(51)
Long-term debt, less current maturities	$	—	$	73

Components Of Lease Cost

	Income Statement Account	March 31, 2019
Operating lease cost:
	Production costs and taxes	$	3
	General and administrative		12
Total operating lease cost		$	15
Finance lease cost:
Amortization of right of use assets	Depreciation, depletion and amortization	$	21
Interest on lease liabilities	Net interest expense		1
Total finance lease cost		$	22

Supplemental Cash Flow Information Related To Leases

	March 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	15
Operating cash flows from finance leases		1
Finance cash flows from finance leases		12
Right of use assets obtained in exchange for lease obligations:
Operating leases		98

Supplemental Balance Sheet Information Related To Leases

	March 31, 2019
Operating Leases
Right of use asset – operating leases	$	84
Lease liabilities - current	$	59
Lease liabilities - noncurrent		25
Total operating lease liabilities	$	84
Finance Leases
Other property and equipment, gross	$	293
Accumulated depreciation		(124)
Other property and equipment, net	$	169
Lease liabilities - current	$	77
Lease liabilities - noncurrent		35
Total finance lease liabilities	$	112

Schedule Of Weighted Average Remaining Lease Term And Discount Rate

	Operating Leases		Finance Leases
Weighted average remaining lease term		1.4 years		1.4 years
Weighted average discount rate		6.0%		5.7%

Maturity Analysis For Operating and Finance Lease Liabilities

	Operating Leases		Finance Leases
2019 (April 2019 – December 2019)	$	46	$	65
2020		42		37
2021		-		16
Total lease payments		88		118
Less imputed interest		(4)		(6)
Total	$	84	$	112

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Discontinued Operations (Tables)

3 Months Ended

Mar. 31, 2019

Discontinued Operations [Abstract]

Schedule Of The Amounts In Net Loss From Discontinued Operations

	For the Three Months Ended
	March 31,
	2019		2018
Revenues	$	—	$	6
Production costs and taxes		—		(50)
Depreciation, depletion, and amortization		—		(4)
Interest income		—		1
Gain on sale of assets		—		1,157
Net income from discontinued operations	$	—	$	1,110

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Description Of Business And Significant Accounting Policies (Narrative) (Details) - USD ($)		3 Months Ended
	Jan. 26, 2018	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Description Of Business And Significant Accounting Policies [Abstract]
Unevaluated properties		$ 0		$ 23,000
Impairment		0	$ 0
Sale of methane facility assets	$ 2,650,000
Accounts receivable - current		608,000		533,000
Accounts receivable - noncurrent		130,000		$ 130,000
Allowance for doubtful accounts		$ 0

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Description Of Business And Significant Accounting Policies (Disaggregation Of Revenue) (Details) - USD ($)	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue	$ 1,171,000	$ 1,367,000
Crude Oil [Member]
Disaggregation of Revenue [Line Items]
Revenue	1,164,000	1,357,000
Salt Water Disposal Fees [Member]
Disaggregation of Revenue [Line Items]
Revenue	7,000	$ 10,000
Natural Gas Imbalances [Member]
Disaggregation of Revenue [Line Items]
Revenue	$ 0		$ 0

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Description Of Business And Significant Accounting Policies (Inventory) (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Description Of Business And Significant Accounting Policies [Abstract]
Oil - carried at cost	$ 423	$ 359
Equipment and materials - carried at market		105
Total inventory	$ 423	$ 464

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Description Of Business And Significant Accounting Policies (Accounts Receivable) (Details) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable - current	$ 608,000	$ 533,000
Allowance for doubtful accounts	0
Revenue [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable - current	474,000	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	$ 5,000	$ 8,000

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Changes in Stockholders' Equity (Changes In Stockholders' Equity) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Balance, value	$ 6,767	$ 5,175
Balance, shares	10,639,290
Net income (loss)	$ (96)	1,243
Compensation expense related to stock issued	$ 4	4
Balance, shares	10,644,252
Balance, value	$ 6,675	6,422
Common Stock [Member]
Balance, value	$ 11	$ 11
Balance, shares	10,639,290	10,619,924
Compensation expense related to stock issued, shares	4,962	4,569
Balance, shares	10,644,252	10,624,493
Balance, value	$ 11	$ 11
Paid-In Capital [Member]
Balance, value	58,276	58,253
Compensation expense related to stock issued	4	4
Balance, value	58,280	58,257
Accumulated Deficit [Member]
Balance, value	(51,520)	(53,089)
Net income (loss)	(96)	1,243
Balance, value	$ (51,616)	$ (51,846)

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Income Taxes (Narrative) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Income Taxes [Line Items]
Unrecognized tax benefits	$ 0	$ 0
Federal net operating loss carryforwards		35,600,000
Federal tax rate	21.00%
Refundable credits		260,000
Estimated annual effective tax rate	0.00%
Cumulative loss period	3 years
Tax Period Between 2019 And 2037 [Member]
Income Taxes [Line Items]
Federal net operating loss carryforwards		34,600,000
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. 01, 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

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Capital Stock (Narrative) (Details)				3 Months Ended
	Apr. 01, 2019 item shares	Jan. 02, 2019 item shares	Mar. 17, 2017 $ / shares	Mar. 31, 2019 $ / shares shares	Dec. 31, 2018 $ / shares shares	Mar. 16, 2017 $ / shares
Capital Stock [Line Items]
Common stock, par value | $ / shares			$ 0.001	$ 0.001	$ 0.001
Dividends conversion ratio				0.001
Exercise price | $ / shares						$ 1.10
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%
Rights [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		4,962
Number of directors | item		3
Directors, CFO And Interim CEO [Member] | Subsequent Event [Member]
Capital Stock [Line Items]
Common stock, New shares issued	4,411
Number of directors | item	3
Series A Preferred Stock [Member]
Capital Stock [Line Items]
Preferred stock, shares issued				0	0
Series A Preferred Stock [Member] | Rights Plan [Member]
Capital Stock [Line Items]
Preferred stock, shares issued				0

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Earnings Per Common Share (Narrative) (Details)	3 Months Ended
	Mar. 31, 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

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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
	Mar. 31, 2019	Mar. 31, 2018
Earnings Per Common Share [Abstract]
Net income (loss) from continuing operations	$ (96)	$ 133
Net income from discontinued operations		$ 1,110
Weighted average shares - basic	10,644,197	10,624,442
Dilution effect of share-based compensation, treasury method
Weighted average shares - dilutive	10,644,197	10,624,442
Continuing operations	$ (0.01)	$ 0.01
Discontinued operations		$ 0.10

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Recent Accounting Pronouncements (Narrative) (Details)	Mar. 31, 2019 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease, Right-of-use asset	$ 84,000
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

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Related Party Transactions (Narrative) (Details) - USD ($)		3 Months Ended	100 Months Ended
	Dec. 18, 2007	Dec. 31, 2018	Jan. 31, 2018	Mar. 31, 2019
Related Party Transaction [Line Items]
Working interest percent	15.00%
Related party allowance for doubtful accounts receivable				$ 0
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

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Oil And Gas Properties (Narrative) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Oil And Gas Properties [Abstract]
Depletion expense	$ 163,000	$ 172,000
Gain (loss) on asset retirement obligations	$ (7,000)	$ 7,000

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Oil And Gas Properties (Schedule Of Oil And Gas Properties) (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Oil And Gas Properties [Abstract]
Oil and gas properties	$ 6,528	$ 6,503
Unevaluated properties		23
Accumulated depreciation, depletion and amortization	(1,878)	(1,722)
Oil and gas properties	$ 4,650	$ 4,804

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Asset Retirement Obligation (Asset Retirement Obligation Transactions) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Asset Retirement Obligation [Abstract]
Balance	$ 2,179
Accretion expense	35	$ 36
Liabilities incurred
Liabilities settled
Balance	$ 2,214

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Long-Term Debt And Lease Liabilities (Narrative) (Details)	3 Months Ended
	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
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]
Interest rate	6.00%
Credit facility current borrowing capacity	$ 3,000,000
Credit facility amount outstanding	0	$ 0
Credit limit	2,740,000
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	3.0

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Long-Term Debt And Lease Liabilities (Schedule Of Long-Term Debt To Unrelated Entities) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 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 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%

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Long-Term Debt And Lease Liabilities (Components Of Lease Cost) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Lease Cost [Line Items]
Total operating lease cost	$ 15
Amortization of right of use assets	21
Interest on lease liabilities	1
Total finance lease cost	22
Production Costs And Taxes [Member]
Lease Cost [Line Items]
Total operating lease cost	3
General and Administrative Expense [Member]
Lease Cost [Line Items]
Total operating lease cost	$ 12

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Long-Term Debt And Lease Liabilities (Supplemental Cash Flow Information Related To Leases) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Long-Term Debt And Lease Liabilities [Abstract]
Operating cash flows from operating leases	$ 15
Operating cash flows from finance leases	1
Finance cash flows from finance leases	12
Right of use assets obtained in exchange for lease obligations, Operating leases	$ 98

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Long-Term Debt And Lease Liabilities (Supplemental Balance Sheet Information Related To Leases) (Details) $ in Thousands	Mar. 31, 2019 USD ($)
Long-Term Debt And Lease Liabilities [Abstract]
Right of use asset - operating leases	$ 84
Lease liabilities - current	59
Lease liabilities - noncurrent	25
Total operating lease liabilities	84
Other property and equipment, gross	293
Accumulated depreciation	(124)
Other property and equipment, net	169
Lease liabilities - current	77
Lease liabilities - noncurrent	35
Total finance lease liabilities	$ 112

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Long-Term Debt And Lease Liabilities (Schedule Of Weighted Average Remaining Lease Term And Discount Rate) (Details)	Mar. 31, 2019
Long-Term Debt And Lease Liabilities [Abstract]
Weighted average remaining lease term, Operating Leases	1 year 4 months 24 days
Weighted average discount rate, Operating Leases	6.00%
Weighted average remaining lease term, Finance Leases	1 year 4 months 24 days
Weighted average discount rate, Finance Leases	5.70%

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Long-Term Debt And Lease Liabilities (Maturity Analysis For Operating and Finance Lease Liabilities) (Details) $ in Thousands	Mar. 31, 2019 USD ($)
Long-Term Debt And Lease Liabilities [Abstract]
2019 (April 2019 - December 2019)	$ 46
2020	42
Total lease payments	88
Less imputed interest	(4)
Total operating lease liabilities	84
2019 (April 2019 - December 2019)	65
2020	37
2021	16
Total lease payments	118
Less imputed interest	(6)
Total finance lease liabilities	$ 112

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Discontinued Operations (Schedule Of The Amounts In Net Loss From Discontinued Operations) (Details) - USD ($) $ in Thousands		3 Months Ended
	Jan. 26, 2018	Mar. 31, 2019	Mar. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net income from discontinued operations			$ 1,110
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			(50)
Depreciation, depletion, and amortization			(4)
Interest income			1
Gain on sale of assets			1,157
Net income from discontinued operations			$ 1,110

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Commitments And Contingencies (Narrative) (Details)	3 Months Ended	51 Months Ended
	Mar. 31, 2019 USD ($) $ / bbl shares	Mar. 31, 2019 USD ($)	Mar. 29, 2019 $ / shares	Sep. 30, 2012 USD ($)
Loss Contingencies [Line Items]
Cost reduction		$ 432,000
Cost reduction paid into common stock	$ 103,000
Shares issued for services | shares	100,000
Share price | $ / shares			$ 1.03
Period of trailing average of WTI	30 days
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 reimbursement | $ / bbl	85
Compensation reduction | $ / bbl	70