Riley Exploration Permian (REPX) 10-Q 14 Aug 14 2014 Q2 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 08, 2014
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Entity Registrant Name	'TENGASCO INC	'
Entity Central Index Key	'0001001614	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Smaller Reporting Company	'
Entity Common Stock, Shares Outstanding	'	60,842,413

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current [Abstract]	'	'
Cash and cash equivalents	$33	$54
Accounts receivable, less allowance for doubtful accounts of $14	1,390	1,285
Accounts receivable - related party, less allowance for doubtful accounts of $159	290	168
Inventory	1,042	1,253
Deferred tax asset-current	130	130
Other current assets	275	312
Total current assets	3,160	3,202
Restricted cash	507	507
Loan fees, net	26	35
Oil and gas properties, net (full cost accounting method)	24,571	24,123
Methane project, net	4,503	4,389
Other property and equipment, net	197	247
Deferred tax asset - noncurrent	6,694	7,209
Total assets	39,658	39,712
Liabilities and Stockholders' Equity	'	'
Accounts payable - trade	278	367
Accounts payable - other	449	327
Accounts payable - related party	539	412
Accrued and other current liabilities	797	444
Current maturities of long-term debt	74	82
Total current liabilities	2,137	1,632
Asset retirement obligation	1,816	1,780
Long term debt, less current maturities	1,960	3,375
Total liabilities	5,913	6,787
Commitments and contingencies (Note 11)	'	'
Stockholders' equity	'	'
Common stock, $.001 par value, authorized 100,000,000 shares, 60,842,413 shares issued and outstanding	61	61
Additional paid-in capital	55,689	55,671
Accumulated deficit	-22,005	-22,807
Total stockholders' equity	33,745	32,925
Total liabilities and stockholders' equity	$39,658	$39,712

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Allowance for doubtful accounts	$14,000	$14,000
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	60,842,413	60,842,413
Common stock, shares outstanding	60,842,413	60,842,413
Related Party [Member]	'	'
Allowance for doubtful accounts	$159,000	$159,000

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Operations (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Condensed Consolidated Statements Of Operations [Abstract]	'	'	'	'
Revenues	$3,985	$3,871	$7,489	$8,185
Cost and expenses	'	'	'	'
Production costs and taxes	1,906	1,191	3,305	2,561
Depreciation, depletion, and amortization	755	742	1,458	1,537
General and administrative	675	466	1,368	979
Total cost and expenses	3,336	2,399	6,131	5,077
Net income from operations	649	1,472	1,358	3,108
Other income (expense)	'	'	'	'
Interest expense	-29	-109	-59	-240
Gain on sale of assets	'	63	18	63
Total other income (expenses)	-29	-46	-41	-177
Income from continuing operations before income tax	620	1,426	1,317	2,931
Income tax expense	-243	-621	-515	-1,147
Income from continuing operations	377	805	802	1,784
(Loss) from discontinued operations, net of income tax benefit	'	-33	'	-74
Net income	$377	$772	$802	$1,710
Net income (loss) per share - Basic and Diluted	'	'	'	'
Net income from continuing operations	$0.01	$0.01	$0.01	$0.03
Net (loss) from discontinued operations	'	$0	'	$0
Shares used in computing earnings per share	'	'	'	'
Basic	60,842,413	60,842,413	60,842,413	60,842,413
Diluted	60,858,223	60,928,397	60,853,001	60,991,055

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Stockholders' Equity (USD $)	Common Stock [Member]	Paid In Capital [Member]	Accumulated Deficit [Member]	Total
In Thousands, except Share data
Balance, value at Dec. 31, 2013	$61	$55,671	($22,807)	$32,925
Balance, shares at Dec. 31, 2013	60,842,413	'	'	60,842,413
Net income	'	'	802	802
Stock based compensation	'	18	'	18
Balance, value at Jun. 30, 2014	$61	$55,689	($22,005)	$33,745
Balance, shares at Jun. 30, 2014	60,842,413	'	'	60,842,413

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements Of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Operating activities	'	'
Net income from continuing operations	$802	$1,784
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion, and amortization	1,458	1,537
Amortization of loan fees-interest expense	9	16
Accretion on asset retirement obligation	57	70
Gain on sale of assets	-18	-63
Stock based compensation	18	18
Deferred tax expense	515	1,147
Changes in assets and liabilities:	'	'
Accounts receivable	-227	179
Inventory and other assets	248	14
Accounts payable	306	-242
Accrued and other current liabilities	366	-106
Settlement on asset retirement obligation	-86	-12
Net cash provided by operating activities - continuing operations	3,448	4,342
Net cash (used in) operating activities - discontinued operations	'	-122
Net cash provided by operating activities	3,448	4,220
Investing activities	'	'
Additions to oil and gas properties	-1,778	-385
Additions to methane project	-274	'
Additions to other property and equipment	-11	'
Proceeds from sale of other property and equipment	17	63
Net cash (used in) investing activities - continuing operations	-2,046	-322
Financing activities	'	'
Payment in lieu of exercise of options	'	-60
Repayments of borrowings	-5,482	-8,029
Proceeds from borrowings	-4,059	-4,200
Loan fees	'	-10
Net cash (used in) financing activities - continuing operations	-1,423	-3,899
Net cash provided by financing activities - discontinued operations	'	122
Net cash (used in) financing activities	-1,423	-3,777
Net change in cash and cash equivalents - continuing operations	-21	121
Cash and cash equivalents, beginning of period	54	31
Cash and cash equivalents, end of period	33	152
Supplemental cash flow information:	'	'
Cash interest payments	50	224
Supplemental non-cash investing and financing activities:	'	'
Asset retirement obligations incurred	26	3
Capital expenditures included in accounts payable and accrued liabilities	$16	$62

Description_Of_Business_And_Si

Description Of Business And Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
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 oil exploration and production is in Kansas. The Company's primary area of natural gas exploration and production was the Swan Creek Field in Tennessee. On August 16, 2013 the Company closed the sale of the Swan Creek assets and the other Tennessee oil and gas related acreage.
	The Company's wholly-owned subsidiary, Tengasco Pipeline Corporation ("TPC"), owned and operated a 65 mile intrastate pipeline which it constructed to transport natural gas from the Company's Swan Creek Field to customers in Kingsport, Tennessee. On August 16, 2013 the Company closed a sale of these pipeline related assets. The related results of operations were classified as "(Loss) from discontinued operations, net of income tax benefit" in the Consolidated Statement of Operations for the three and six months ended June 30, 2013.
	The Company's wholly-owned subsidiary, Manufactured Methane Corporation ("MMC") operates a treatment facility for the extraction of methane gas from nonconventional sources for eventual sale to natural gas customers and generation of electricity. This facility is located at the Carter Valley landfill site in Church Hill, Tennessee.
	Basis of Presentation
	The accompanying unaudited condensed consolidated financial statements 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, although 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 six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the year ended December 31, 2014. 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, 2013.
	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 consolidated financial statements are prepared in conformity with U.S. GAAP which requires 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 impairment 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 other assumptions that we believe to be reasonable. While we believe that our estimates and assumptions used in preparation of the consolidated financial statements are appropriate, actual results could differ from those estimates.
	Revenue Recognition
	Revenues are recognized based on actual volumes of oil, natural gas, methane, and electricity sold to purchasers at a fixed or determinable price, when delivery has occurred and title has transferred, and collectability is reasonably assured. Crude oil is stored and at the time of delivery to the purchasers, revenues are recognized. Prior to the sale of the Tennessee properties, natural gas meters were placed at the customer's location and usage was billed each month. As the natural gas properties were sold in August 2013, there were no natural gas imbalances at June 30, 2014 or December 31, 2013. Methane gas and electricity sales meters are located at the Carter Valley landfill site and sales of methane and electricity are billed each month.
	Cash and Cash Equivalents
	Cash and cash equivalents include temporary cash investments with a maturity of ninety days or less at date of purchase.
	Restricted Cash
	As security required by Tennessee oil and gas regulations, the Company placed $120,500 in a Certificate of Deposit to cover future asset retirement obligations for the Company's Tennessee wells. At June 30, 2014 and December 31, 2013, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash". On August 11, 2014, the State of Tennessee notified the holder of the Certificate of Deposit that the Company had fulfilled its obligations to the State with regard to future asset retirement obligation and therefore the Certificate of Deposit could be released. In addition, during the 4th quarter of 2012, the Company placed $386,000 as collateral for a bond to appeal a civil penalty related to issuance of an "Incidence of Non-Compliance" by the Bureau of Safety and Environmental Enforcement ("BSEE") concerning one of the Hoactzin properties operated by the Company pursuant to the Management Agreement (see Note 4). At June 30, 2014 and December 31, 2013, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash" (see Note 11).
	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 per barrel cost which includes production costs and taxes, allocated general and administrative costs, depreciation, and allocated interest cost. The market component is calculated using the average June 2014 and December 2013 oil sales prices received from the Company's Kansas properties. In addition, the Company also carried equipment and materials in inventory to be used in its Kansas operation and is carried at the lower of cost or market value. The cost component of the equipment and materials inventory represents the original cost paid for the equipment and materials. The market component is based on estimated sales value for similar equipment and materials as of June 30, 2014 and December 31, 2013. The following table sets forth information concerning the Company's inventory (in thousands):
			30-Jun-14		31-Dec-13
	Oil – carried at cost	$	774	$	765
	Equipment and materials – carried at cost		268		488
	Total inventory	$	1,042	$	1,253
	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 acquisition costs, 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. 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 $736,000 in unevaluated properties at both June 30, 2014 and December 31, 2013. 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.
	There was no impairment recorded at June 30, 2014 or December 31, 2013.
	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 production, and other miscellaneous receivables. No interest is charged on past-due balances. Payments made on accounts receivable are applied 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. An allowance was recorded at June 30, 2014 and December 31, 2013. At June 30, 2014 and December 31, 2013, accounts receivable consisted of the following (in thousands):
			30-Jun-14			31-Dec-13
	Revenue	$	1,354		$	1,214
	Joint interest		27			35
	Other		23			50
	Allowance for doubtful accounts		(14	)		(14	)
	Total accounts receivable	$	1,390		$	1,285
	Discontinued Operations
	During 2012, the Company committed to a plan to sell its Swan Creek and Pipeline assets. On March 1, 2013, the Company entered into an agreement to sell the Company's Swan Creek and Pipeline assets for $1.5 million. Closing of this transaction occurred on August 16, 2013. The related results of the pipeline operations were classified as "(Loss) from discontinued operations, net of income tax benefit" in the Consolidated Statement of Operations for the three and six months ended June 30, 2013. The pipeline related cash flows were classified as "Net cash (used in) operating activities – discontinued operations", "Net cash (used in) investing activities –discontinued operations", and Net cash (used in) financing activities – discontinued operations". As the Swan Creek assets represented only a small portion of the Company's full cost pool, these assets were classified in continuing operations for the three and six months ended June 30, 2013.

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
Income Taxes [Abstract]	'
Income Taxes	'
	(2) Income Taxes
	The total deferred tax asset was $6.8 million and $7.3 million at June 30, 2014 and December 31, 2013, respectively. At June 30, 2014 and December 31, 2013, the Company recorded a valuation allowance of $790,000. Although management considers our valuation allowance as of June 30, 2104 and December 31, 2013 adequate, material changes in these amounts may occur in the future based on tax audits and changes in legislation. The difference between the rate used to record tax expense and the statutory rate during the six months ended June 30, 2014 is primarily related to state income tax.

Earnings_Per_Common_Share

Earnings Per Common Share	6 Months Ended
	Jun. 30, 2014
Earnings Per Common Share [Abstract]	'
Earnings Per Common Share	'
	(3) Earnings per Common Share
	We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share which include the effect of all potentially dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators of our basic and diluted earnings per share, (in thousands except for share and per share amounts):
			For the Three Months Ended					For the Six Months Ended
			30-Jun-14		30-Jun-13			30-Jun-14		30-Jun-13
	Income (numerator):
	Net income from continuing operations	$	377	$	805		$	802	$	1,784
	Net loss from discontinued operations			$	(33	)			$	(74	)
	Weighted average shares (denominator):
	Weighted average shares – basic		60,842,413		60,842,413			60,842,413		60,842,413
	Dilution effect of share-based compensation,
	treasury method		15,810		85,984			10,588		148,642
	Weighted average shares – dilutive		60,858,223		60,928,397			60,853,001		60,991,055
	Earnings (loss) per share – Basic and Dilutive:
	Continuing Operations	$	0.01	$	0.01		$	0.01	$	0.03
	Discontinued Operations			$	(0.00	)			$	(0.00	)

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	(4) Related Party Transactions
	On September 17, 2007, the Company entered into a drilling program with Hoactzin Partners, L.P. ("Hoactzin") for ten wells consisting of approximately three wildcat wells and seven developmental wells to be drilled on the Company's Kansas Properties (the "Ten Well Program"). Peter E. Salas, the Chairman of the Board of Directors of the Company, is the controlling person of Hoactzin. He was also at the time the sole shareholder and controlling person of Dolphin Management, Inc., the general partner of Dolphin Offshore Partners, L.P., which was the Company's largest shareholder at that time.
	Under the terms of the Ten Well Program, Hoactzin paid the Company $0.4 million for each well drilled in the Ten Well Program completed as a producing well and $0.25 million for each well that was non-productive. The terms of the Ten Well Program also provided that Hoactzin would receive all the working interest in the ten wells in the Program, but would pay an initial fee to the Company of 25% of its working interest revenues net of operating expenses. This is referred to as a management fee but, as defined, is in the nature of a net profits interest. The fee paid to the Company by Hoactzin would increase to 85% if net revenues received by Hoactzin reached an agreed payout point of approximately 1.35 times Hoactzin's purchase price (the "Payout Point") for its interest in the Ten Well Program.
	In March 2008, the Company drilled and completed the final well in the Ten Well Program. Hoactzin paid a total of $3.85 million (the "Purchase Price") for its interest in the Ten Well Program resulting in the Payout Point being determined as $5.2 million.
	On September 17, 2007, Hoactzin, simultaneously with subscribing to participate in the Ten Well Program, pursuant to the second agreement referred to above was conveyed a 75% net profits interest in the methane extraction project developed by MMC at the Carter Valley landfill owned by Republic Services in Church Hill, Tennessee (the "Methane Project"). Net profits, if any, from the Methane Project received by Hoactzin would have been applied towards the determination of the Payout Point for the Ten Well Program. However, through June 30, 2014, no payments were made to Hoactzin for its 75% net profits interest in the Methane Project, because no net profits were generated.
	The method of calculation of the net profits interest takes into account specific costs and expenses as well as gross gas revenues for the Methane Project. As a result of the startup costs and ongoing operating expenses, no net profits, as defined in the agreement, have been generated from startup in April, 2009 through June 30, 2014 for payment to Hoactzin under the net profits interest conveyed. When the Payout Point was reached, Hoactzin's net profits interest in the Methane Project was reduced to a 7.5% net profits interest.
	In February 2014, net revenues earned by Hoactzin from the Ten Well Program had exceeded $5.2 million and thereby reached the Payout Point which increased the management fee due to the Company by Hoactzin from 25% to 85% and reduced the net profits interest in the Methane Project to 7.5%.
	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, 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 terminated by its own terms on December 18, 2012. The Company is assisting Hoactzin with becoming operator of record of these wells. The Company has entered into a transition agreement with Hoactzin whereby Hoactzin and its controlling member indemnify the Company for any costs or liabilities incurred by the Company resulting from such assistance, or the fact that the Company is still the operator of record on certain of these wells.
	During the course of the Management Agreement, the Company became the operator of certain properties owned by Hoactzin. The Company obtained from IndemCo, over time, bonds in the face amount of approximately $10.7 million for the purpose of covering plugging and abandonment obligations for Hoactzin's operated properties located in federal offshore waters in favor of the BSEE, as well as certain private parties. In connection with the issuance of these bonds the Company signed a Payment and Indemnity Agreement with IndemCo whereby the Company guaranteed payment of any bonding liabilities incurred by IndemCo. Dolphin Direct Equity Partners, LP also signed the Payment and Indemnity Agreement, thereby becoming jointly and severally liable with the Company for the obligations to IndemCo. Dolphin Direct Equity Partners, L.P. is a private equity fund controlled by Peter E. Salas that has a significant economic interest in Hoactzin. Hoactzin had provided $6.6 million in cash to IndemCo as collateral for these potential obligations. As of May 15, 2014, all bonds issued by IndemCo and subject to the Payment and Indemnity Agreement have been released by the BSEE and have been cancelled by IndemCo. Accordingly, the exposure to the Company under any of the now cancelled IndemCo bonds or the indemnity agreement relating to those now cancelled bonds has decreased to zero.
	As part of the transition process, Hoactzin has secured new bonds from Argonaut Insurance Company to replace the IndemCo bonds. As noted above, all of the IndemCo bonds were replaced, and all IndemCo bonds were cancelled. Also as part of the transition to Hoactzin becoming operator of its own properties, right-of-use and easement ("RUE") bonds in the amount of $1.55 million were required by the regulatory process to be issued by Argonaut in the Company's name. Hoactzin is in the process of transferring these RUE bonds from the Company to Hoactzin. Hoactzin and Dolphin Direct signed an indemnity agreement with Argonaut as well as provided the required collateral for the new Argonaut bonds, including 100% cash collateral for the RUE bonds issued in the Company's name. The Company is not party to the indemnity agreement with Argonaut and has not provided any collateral for any of the Argonaut bonds issued. When the transfer of the RUE's and associated bonds is approved, the transfer of operations to Hoactzin would be complete and the Company's involvement in the Hoactzin properties will be ended.
	As operator, the Company routinely contracted in its name for goods and services with vendors in connection with its operation of the Hoactzin properties. In practice, Hoactzin directly paid these invoices for goods and services that were contracted in the Company's name. During late 2009 and early 2010, Hoactzin undertook several significant operations, for which the Company contracted in the ordinary course. As a result of the operations performed in late 2009 and early 2010, Hoactzin had significant past due balances to several vendors, a portion of which were included on the Company's balance sheet. Payables related to these past due and ongoing operations remained outstanding at June 30, 2014 and December 31, 2013 in the amount of $449,000 and $327,000, respectively. The increase in payables was due to invoices received from IndemCo related to bond premiums. The Company has recorded the Hoactzin-related payables and the corresponding receivable from Hoactzin as of June 30, 2014 and December 31, 2013 in its Consolidated Balance Sheets under "Accounts payable – other" and "Accounts receivable – related party". In July 2014, bond premium invoices in the amount of $290,000 were paid by Hoactzin leaving a past due balance of $159,000 still outstanding. As the IndemCo bonds have been cancelled, this outstanding balance should not increase in the future. Since the second quarter of 2012, Hoactzin had not made payments to reduce these past due balances. Based on these circumstances, the Company has elected to establish an allowance in the amount of $159,000 for the balances outstanding at June 30, 2104 and December 31, 2013. This allowance was recorded in the Company's Consolidated Balance Sheets under "Accounts receivable – related party" and in its Consolidated Statements of Operations in "General and administrative".
	The Company has entered into an agreement with Hoactzin whereby Hoactzin and Dolphin Direct are indemnifying the Company for any costs or liabilities incurred by the Company resulting from such assistance, or the fact that the Company is still the operator of record on certain of these wells. Until such time as Hoactzin becomes operator of record on these wells and the corresponding bonding liability is transferred from the Company to Hoactzin, per the transition agreement, the Company is suspending drilling payments to Hoactzin. As of June 30, 2014, the Company has suspended approximately $539,000 in payments. This balance of these suspended payments is recorded in the Consolidated Balance Sheet under "Accounts payable – related party".
	The Company has not advanced any funds to pay any obligations of Hoactzin. No borrowing capability of the Company has been used by the Company in connection with its obligations under the Management Agreement, except for those funds used to collateralize the appeal bond with RLI Insurance Company.
	.

Oil_And_Gas_Properties

Oil And Gas Properties	6 Months Ended
	Jun. 30, 2014
Oil And Gas Properties [Abstract]	'
Oil And Gas Properties	'
	(5) Oil and Gas Properties
	The following table sets forth information concerning the Company's oil and gas properties (in thousands):
			30-Jun-14			31-Dec-13
	Oil and gas properties, at cost	$	46,835		$	45,101
	Unevaluated properties		736			736
	Accumulated depletion		(23,000	)		(21,714	)
	Oil and gas properties, net	$	24,571		$	24,123
	The Company recorded depletion expense of $1,325,000 and $1,370,000 for the six months ended June 30, 2014 and 2013, respectively.

Asset_Retirement_Obligation

Asset Retirement Obligation	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligation	'
	(6) 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 six months ended June 30, 2014 (in thousands):
	Balance December 31, 2013	$	1,780
	Accretion expense		57
	Liabilities incurred		26
	Liabilities settled		(47	)
	Balance June 30, 2014	$	1,816

LongTerm_Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2014
Long-Term Debt [Abstract]	'
Long-Term Debt	'
	(7) Long-Term Debt
	Long-term debt to unrelated entities consisted of the following (in thousands):
			30-Jun-14			31-Dec-13
	Note payable to a financial institution, with interest only
	payment until maturity.	$	1,865		$	3,257
	Installment notes bearing interest at the rate of 5.5% to
	8.25% per annum collateralized by vehicles with monthly
	payments including interest, insurance and maintenance of
	approximately $10		169			200
	Total long-term debt		2,034			3,457
	Less current maturities		(74	)		(82	)
	Long-term debt, less current maturities	$	1,960		$	3,375
	At June 30, 2014, the Company had a revolving credit facility with Prosperity Bank (formerly F&M Bank & Trust Company). 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 $40 million or the Company's borrowing base in effect from time to time. As of June 30, 2014, the Company's borrowing base was $14.3 million, the interest rate was prime plus 0.50% per annum, and the maturity date was Jan 27, 2016. The Company's interest rate at June 30, 2014 was 3.75%. The borrowing base is subject to an existing periodic redetermination provision in the credit facility. The credit facility is secured by substantially all of the Company's producing and non-producing oil and gas properties and the Company's Methane Project and electric generation assets. The credit facility includes certain covenants with which the Company is required to comply. These covenants include leverage, interest coverage, minimum liquidity, and general and administrative coverage ratios. The Company is in compliance with all of the credit facility covenants.
	The total borrowing by the Company under the Prosperity Bank facility at June 30, 2014 and December 31, 2013 was approximately $1.9 million and $3.3 million, respectively. The next borrowing base review will take place in August 2014.

Methane_Project

Methane Project	6 Months Ended
	Jun. 30, 2014
Methane Project [Abstract]	'
Methane Project	'
	(8) Methane Project
	The methane facilities were placed into service on April 1, 2009. The methane facilities are being depreciated over the estimated useful life of approximately 33 years based on estimated landfill closure date of December 2041. The Company recorded depreciation expense of $82,000 and $59,000 for the six months ended June 30, 2104 and 2013, respectively.

Discontinued_Operations

Discontinued Operations	6 Months Ended
	Jun. 30, 2014
Discontinued Operations [Abstract]	'
Discontinued Operations	'
	(9) Discontinued Operations
	The following table summarizes the pipeline related amounts included in "(Loss) from discontinued operations, net of income tax benefit" presented in the Company's Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2013 (in thousands):
			For the Three Months			For the Six Months
			Ended			Ended
			30-Jun-13			30-Jun-13
	Revenues	$	8		$	17
	Production costs and taxes		(67	)		(139	)
	Depreciation, depletion, and amortization		-			-
	Income tax benefit		26			48
	(Loss) from discontinued operations, net of
	income tax benefit	$	(33	)	$	(74	)

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	(10) Fair Value Measurements
	The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, accounts payable, accrued liabilities and long term debt in our balance sheet approximates fair value as of June 30, 2014 and December 31, 2013.

Commitments_And_Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	(11) Commitments and Contingencies
	The Company as designated operator of the Hoactzin properties was administratively issued an "Incidence of Non-Compliance" by BSEE during the quarter ended September 30, 2012 concerning one of Hoactzin's operated properties. This action calls 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 not been conducted in 2011. Tengasco believes such tests were conducted by the contractor on the facility, but the contractor failed to preserve adequate documentation. In the 4th quarter of 2012, the Company filed an administrative appeal with the Interior Board of Land Appeals ("IBLA") of this action in order to attempt to significantly reduce the civil penalty. This appeal required a fully collateralized appeal bond to postpone the payment obligation until the appeal was determined. The Company posted and collateralized this bond with RLI Insurance Company. If the bond was not posted, the appeal would have been administratively denied and the order to the Company as operator to pay the $386,000 penalty would have become final. On June 23, 2014, the IBLA affirmed the civil penalty without reduction. The Company is in the process of determining whether a further appeal of the final agency action affirming the civil penalty will be taken to federal district court. An appeal in the courts, if taken, would be filed by September 22, 2014. While the civil penalty could ultimately be reduced in the appeal process, as a result of the determination by the IBLA, the Company recorded a liability of $386,000 in the Company's Consolidated Balance Sheets under "Accrued and other current liabilities" and expense in its Consolidated Statements of Operations under "Production costs and taxes" for the three and six months ended June 30, 2014.

Description_Of_Business_And_Si1

Description Of Business And Significant Accounting Policies (Policy)	6 Months Ended
	Jun. 30, 2014
Description Of Business And Significant Accounting Policies [Abstract]	'
Basis Of Presentation	'
	Basis of Presentation
	The accompanying unaudited condensed consolidated financial statements 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, although 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 six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the year ended December 31, 2014. 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, 2013.
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 consolidated financial statements are prepared in conformity with U.S. GAAP which requires 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 impairment 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 other assumptions that we believe to be reasonable. While we believe that our estimates and assumptions used in preparation of the consolidated financial statements are appropriate, actual results could differ from those estimates.
Revenue Recognition	'
	Revenue Recognition
	Revenues are recognized based on actual volumes of oil, natural gas, methane, and electricity sold to purchasers at a fixed or determinable price, when delivery has occurred and title has transferred, and collectability is reasonably assured. Crude oil is stored and at the time of delivery to the purchasers, revenues are recognized. Prior to the sale of the Tennessee properties, natural gas meters were placed at the customer's location and usage was billed each month. As the natural gas properties were sold in August 2013, there were no natural gas imbalances at June 30, 2014 or December 31, 2013. Methane gas and electricity sales meters are located at the Carter Valley landfill site and sales of methane and electricity are billed each month.
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.
Restricted Cash	'
	Restricted Cash
	As security required by Tennessee oil and gas regulations, the Company placed $120,500 in a Certificate of Deposit to cover future asset retirement obligations for the Company's Tennessee wells. At June 30, 2014 and December 31, 2013, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash". On August 11, 2014, the State of Tennessee notified the holder of the Certificate of Deposit that the Company had fulfilled its obligations to the State with regard to future asset retirement obligation and therefore the Certificate of Deposit could be released. In addition, during the 4th quarter of 2012, the Company placed $386,000 as collateral for a bond to appeal a civil penalty related to issuance of an "Incidence of Non-Compliance" by the Bureau of Safety and Environmental Enforcement ("BSEE") concerning one of the Hoactzin properties operated by the Company pursuant to the Management Agreement (see Note 4). At June 30, 2014 and December 31, 2013, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash" (see Note 11).
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 per barrel cost which includes production costs and taxes, allocated general and administrative costs, depreciation, and allocated interest cost. The market component is calculated using the average June 2014 and December 2013 oil sales prices received from the Company's Kansas properties. In addition, the Company also carried equipment and materials in inventory to be used in its Kansas operation and is carried at the lower of cost or market value. The cost component of the equipment and materials inventory represents the original cost paid for the equipment and materials. The market component is based on estimated sales value for similar equipment and materials as of June 30, 2014 and December 31, 2013. The following table sets forth information concerning the Company's inventory (in thousands):
			30-Jun-14		31-Dec-13
	Oil – carried at cost	$	774	$	765
	Equipment and materials – carried at cost		268		488
	Total inventory	$	1,042	$	1,253
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 acquisition costs, 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. 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 $736,000 in unevaluated properties at both June 30, 2014 and December 31, 2013. 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.
	There was no impairment recorded at June 30, 2014 or December 31, 2013.
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 production, and other miscellaneous receivables. No interest is charged on past-due balances. Payments made on accounts receivable are applied 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. An allowance was recorded at June 30, 2014 and December 31, 2013. At June 30, 2014 and December 31, 2013, accounts receivable consisted of the following (in thousands):
			30-Jun-14			31-Dec-13
	Revenue	$	1,354		$	1,214
	Joint interest		27			35
	Other		23			50
	Allowance for doubtful accounts		(14	)		(14	)
	Total accounts receivable	$	1,390		$	1,285
Discontinued Operations	'
	Discontinued Operations
	During 2012, the Company committed to a plan to sell its Swan Creek and Pipeline assets. On March 1, 2013, the Company entered into an agreement to sell the Company's Swan Creek and Pipeline assets for $1.5 million. Closing of this transaction occurred on August 16, 2013. The related results of the pipeline operations were classified as "(Loss) from discontinued operations, net of income tax benefit" in the Consolidated Statement of Operations for the three and six months ended June 30, 2013. The pipeline related cash flows were classified as "Net cash (used in) operating activities – discontinued operations", "Net cash (used in) investing activities –discontinued operations", and Net cash (used in) financing activities – discontinued operations". As the Swan Creek assets represented only a small portion of the Company's full cost pool, these assets were classified in continuing operations for the three and six months ended June 30, 2013.

Description_Of_Business_And_Si2

Description Of Business And Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Description Of Business And Significant Accounting Policies [Abstract]	'
Inventory	'
			30-Jun-14		31-Dec-13
	Oil – carried at cost	$	774	$	765
	Equipment and materials – carried at cost		268		488
	Total inventory	$	1,042	$	1,253
Accounts Receivable	'
			30-Jun-14			31-Dec-13
	Revenue	$	1,354		$	1,214
	Joint interest		27			35
	Other		23			50
	Allowance for doubtful accounts		(14	)		(14	)
	Total accounts receivable	$	1,390		$	1,285

Earnings_Per_Common_Share_Tabl

Earnings Per Common Share (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Common Share [Abstract]	'
Reconciliations Of The Numerators And Denominators Of Basic And Diluted Earnings Per Share	'
			For the Three Months Ended					For the Six Months Ended
			30-Jun-14		30-Jun-13			30-Jun-14		30-Jun-13
	Income (numerator):
	Net income from continuing operations	$	377	$	805		$	802	$	1,784
	Net loss from discontinued operations			$	(33	)			$	(74	)
	Weighted average shares (denominator):
	Weighted average shares – basic		60,842,413		60,842,413			60,842,413		60,842,413
	Dilution effect of share-based compensation,
	treasury method		15,810		85,984			10,588		148,642
	Weighted average shares – dilutive		60,858,223		60,928,397			60,853,001		60,991,055
	Earnings (loss) per share – Basic and Dilutive:
	Continuing Operations	$	0.01	$	0.01		$	0.01	$	0.03
	Discontinued Operations			$	(0.00	)			$	(0.00	)

Oil_And_Gas_Properties_Tables

Oil And Gas Properties (Tables)	6 Months Ended
	Jun. 30, 2014
Oil And Gas Properties [Abstract]	'
Schedule Of Oil And Gas Properties	'
			30-Jun-14			31-Dec-13
	Oil and gas properties, at cost	$	46,835		$	45,101
	Unevaluated properties		736			736
	Accumulated depletion		(23,000	)		(21,714	)
	Oil and gas properties, net	$	24,571		$	24,123

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligation Transactions	'
	Balance December 31, 2013	$	1,780
	Accretion expense		57
	Liabilities incurred		26
	Liabilities settled		(47	)
	Balance June 30, 2014	$	1,816

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Long-Term Debt [Abstract]	'
Schedule Of Long-Term Debt To Unrelated Entities	'
			30-Jun-14			31-Dec-13
	Note payable to a financial institution, with interest only
	payment until maturity.	$	1,865		$	3,257
	Installment notes bearing interest at the rate of 5.5% to
	8.25% per annum collateralized by vehicles with monthly
	payments including interest, insurance and maintenance of
	approximately $10		169			200
	Total long-term debt		2,034			3,457
	Less current maturities		(74	)		(82	)
	Long-term debt, less current maturities	$	1,960		$	3,375

Discontinued_Operations_Tables

Discontinued Operations (Tables)	6 Months Ended
	Jun. 30, 2014
Discontinued Operations [Abstract]	'
Schedule Of The Amounts In Net Loss From Discontinued Operations	'
			For the Three Months			For the Six Months
			Ended			Ended
			30-Jun-13			30-Jun-13
	Revenues	$	8		$	17
	Production costs and taxes		(67	)		(139	)
	Depreciation, depletion, and amortization		-			-
	Income tax benefit		26			48
	(Loss) from discontinued operations, net of
	income tax benefit	$	(33	)	$	(74	)

Description_Of_Business_And_Si3

Description Of Business And Significant Accounting Policies (Narrative) (Details) (USD $)	6 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Aug. 16, 2013	Jun. 30, 2014	Dec. 31, 2012
	mi			Certificates of Deposit [Member]	Collateralized Bond [Member]
Description Of Business And Significant Accounting Policies [Line Items]	'	'	'	'	'
Length of pipeline, miles	65	'	'	'	'
Restricted cash	$507,000	$507,000	'	$120,500	$386,000
Unevaluated properties	736,000	736,000	'	'	'
Current cost discount	10.00%	'	'	'	'
Impairment	0	0	'	'	'
Agreement to sell the Company's Swan Creek and Pipeline assets	'	'	$1,500,000	'	'

Description_Of_Business_And_Si4

Description Of Business And Significant Accounting Policies (Inventory) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Description Of Business And Significant Accounting Policies [Abstract]	'	'
Oil - carried at cost	$774	$765
Equipment and materials - carried at cost	268	488
Total inventory	$1,042	$1,253

Description_Of_Business_And_Si5

Description Of Business And Significant Accounting Policies (Accounts Receivable) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	$1,390	$1,285
Allowance for doubtful accounts	-14	-14
Revenue [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	1,354	1,214
Joint Interest [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	27	35
Other [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	$23	$50

Income_Taxes_Details

Income Taxes (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Income Taxes [Abstract]	'	'
Deferred tax asset	$6,800,000	$7,300,000
Valuation allowance	$790,000	$790,000

Earnings_Per_Common_Share_Deta

Earnings Per Common Share (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Earnings Per Common Share [Abstract]	'	'	'	'
Net income from continuing operations	$377	$805	$802	$1,784
Net loss from discontinued operations	'	($33)	'	($74)
Weighted average shares - basic	60,842,413	60,842,413	60,842,413	60,842,413
Dilution effect of share-based compensation, treasury method	15,810	85,984	10,588	148,642
Weighted average shares - dilutive	60,858,223	60,928,397	60,853,001	60,991,055
Continuing Operations	$0.01	$0.01	$0.01	$0.03
Discontinued Operations	'	$0	'	$0

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

0 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

6 Months Ended

Dec. 18, 2007

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Sep. 17, 2007

Sep. 17, 2007

Sep. 17, 2007

Jun. 30, 2014

Mar. 31, 2008

Sep. 17, 2007

Sep. 17, 2007

Sep. 17, 2007

Jun. 30, 2014

Sep. 17, 2007

Jun. 30, 2014

Jun. 30, 2014

Jul. 15, 2015

Jun. 30, 2014

Dec. 31, 2013

Dec. 18, 2007

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Right-Of-Use And Easement Bonds [Member]

At Or Above Revenue Threshold [Member]

Up To Revenue Threshold [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Hoactzin Partners, L.P. [Member]

Hoactzin Partners, L.P. [Member]

Hoactzin Partners, L.P. [Member]

Hoactzin Partners, L.P. [Member]

Hoactzin Partners, L.P. [Member]

Indem Co [Member]

Related Party [Member]

Related Party [Member]

item

Producing Well [Member]

Non-Productive Well [Member]

At Or Above Revenue Threshold [Member]

At Or Above Revenue Threshold [Member]

Up To Revenue Threshold [Member]

Up To Revenue Threshold [Member]

Minimum [Member]

Methane Project [Member]

Productive Wells [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Wells in process of drilling

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of wildcat wells

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of developmental wells

'

'

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost incurred, development costs

'

'

'

'

'

'

'

'

'

$400,000

$250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of working interest revenue, as a fee

'

'

'

'

'

'

'

'

'

'

'

85.00%

85.00%

25.00%

25.00%

'

'

'

'

'

'

'

'

'

Payout point multiplier

'

'

'

'

'

'

1.35

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payout point value

'

'

'

'

'

'

'

'

5,200,000

'

'

'

'

'

'

5,200,000

'

'

'

'

'

'

'

'

Related party transaction

'

'

'

'

'

'

'

'

3,850,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of net profits, interest

'

'

'

'

7.50%

75.00%

'

7.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Working interest percent

15.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Bond, face value

10,700,000

'

'

1,550,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash collateral

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,600,000

'

'

'

'

Percentage of cash collateral

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

Related parties accounts payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

290,000

449,000

327,000

'

'

'

'

'

Past due related parties accounts payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

159,000

'

'

'

'

'

'

'

Related party allowance for doubtful accounts receivable

'

14,000

14,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

159,000

159,000

Net profits

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

Accounts payable - related party

'

539,000

412,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Suspended portion of accounts payable

'

539,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability to related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

'

'

'

$0

'

'

Oil_And_Gas_Properties_Details

Oil And Gas Properties (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Oil And Gas Properties [Abstract]	'	'	'
Oil and gas properties, at cost	$46,835,000	'	$45,101,000
Unevaluated properties	736,000	'	736,000
Accumulated depletion	-23,000,000	'	-21,714,000
Oil and gas properties, net	24,571,000	'	24,123,000
Depletion expense	$1,325,000	$1,370,000	'

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Asset Retirement Obligation [Abstract]	'	'
Balance	$1,780	'
Accretion expense	57	70
Liabilities incurred	26	'
Liabilities settled	-47	'
Balance	$1,816	'

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (F&M Bank [Member], USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
F&M Bank [Member]	'	'
Debt Instrument [Line Items]	'	'
Credit facility maximum borrowing capacity	$40	'
Credit facility current borrowing capacity	14.3	'
Interest rate per annum	3.75%	'
Rate above prime	0.50%	'
Credit facility maturity date	27-Jan-16	'
Loans and letters of credit amount outstanding	$1.90	$3.30

LongTerm_Debt_Schedule_Of_Long

Long-Term Debt (Schedule Of Long-Term Debt To Unrelated Entities) (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Debt Instrument [Line Items]	'	'
Note payable to financial institution, with interest only payment until maturity	$1,865	$3,257
Installment notes bearing interest at the rate of 5.5% to 8.25% per annum collateralized by vehicles with monthly payments including interest, insurance and maintenance of approximately $10	169	200
Total long-term debt	2,034	3,457
Less current maturities	-74	-82
Long-term debt, less current maturities	1,960	3,375
Periodic payments including interest, insurance and maintenance	$10	'
Maximum [Member]	'	'
Debt Instrument [Line Items]	'	'
Interest rate per annum	8.25%	'
Minimum [Member]	'	'
Debt Instrument [Line Items]	'	'
Interest rate per annum	5.50%	'

Methane_Project_Details

Methane Project (Details) (Methane Project [Member], USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Methane Project [Member]	'	'
Methane Project [Line Items]	'	'
Date methane facilities were placed into service	1-Apr-09	'
Landfill closure date	31-Dec-41	'
Methane facilities estimated useful life	'33 years	'
Depreciation expense	$82,000	$59,000

Discontinued_Operations_Schedu

Discontinued Operations (Schedule Of The Amounts In Net Loss From Discontinued Operations) (Details) (USD $)	3 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2013
Discontinued Operations [Abstract]	'	'
Revenues	$8	$17
Production costs and taxes	-67	-139
Income tax benefit (expense)	26	48
Income (loss) from discontinued operations, net of income tax benefit	($33)	($74)

Commitments_And_Contingencies_

Commitments And Contingencies (Details) (USD $)	3 Months Ended		6 Months Ended			3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2014
						Incidence Of Non-Compliance [Member]	Incidence Of Non-Compliance [Member]	Incidence Of Non-Compliance [Member]
							item
Loss Contingencies [Line Items]	'	'	'	'	'	'	'	'
Wells issued incidence of non-compliance	'	'	'	'	'	'	1	'
Accrued and other current liabilities	$797,000	'	$797,000	'	$444,000	$386,000	'	$386,000
Production costs and taxes	$1,906,000	$1,191,000	$3,305,000	$2,561,000	'	$386,000	'	$386,000