Riley Exploration Permian (REPX) 10-Q 14 Nov 13 2013 Q3 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 08, 2013
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
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 $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Assets, Current [Abstract]	'	'
Cash and cash equivalents	$19	$31
Accounts receivable	1,319	1,608
Accounts receivable - related party, less allowance for doubtful accounts of $159 and $257	172	68
Inventory	1,258	1,402
Other current assets	125	194
Total current assets	2,893	3,303
Restricted cash	507	507
Loan fees, net	43	57
Oil and gas properties, net (full cost accounting method)	23,470	24,700
Methane project, net	4,347	4,445
Other property and equipment, net	146	321
Assets held for sale	'	1,400
Deferred tax asset-noncurrent	7,460	9,434
Total assets	38,866	44,167
Liabilities and Stockholders' Equity	'	'
Accounts payable - trade	466	648
Accounts payable - other	331	325
Accounts payable - related party	257	'
Accrued and other current liabilities	521	615
Current maturities of long-term debt	77	100
Total current liabilities	1,652	1,688
Asset retirement obligation	1,812	2,099
Long term debt, less current maturities	3,112	10,246
Total liabilities	6,576	14,033
Commitments and contingencies (Note 13)	'	'
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	55,665	55,699
Accumulated deficit	-23,436	-25,626
Total stockholders' equity	32,290	30,134
Total liabilities and stockholders' equity	$38,866	$44,167

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Condensed Consolidated Balance Sheets [Abstract]	'	'
Allowance for doubtful accounts, related party accounts receivable	$159,000	$257,000
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

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Condensed Consolidated Statements Of Operations [Abstract]	'	'	'	'
Revenues	$4,034	$5,806	$12,219	$15,990
Cost and expenses	'	'	'	'
Production costs and taxes	1,560	1,746	4,121	5,347
Depreciation, depletion, and amortization	673	942	2,210	2,511
General and administrative	461	887	1,440	2,246
Total cost and expenses	2,694	3,575	7,771	10,104
Net income from operations	1,340	2,231	4,448	5,886
Other income (expense)	'	'	'	'
Interest expense	-79	-191	-319	-585
Gain (loss) on derivatives	'	-35	'	-140
Gain (loss) on sale of assets	-13	16	49	83
Total other income (expenses)	-92	-210	-270	-642
Income from continuing operations before income tax	1,248	2,021	4,178	5,244
Income tax expense	-713	-742	-1,860	-1,859
Income from continuing operations	535	1,279	2,318	3,385
(Loss) from discontinued operations, net of income tax benefit	-54	-60	-128	-206
Net income	$481	$1,219	$2,190	$3,179
Net income (loss) per share - Basic and Diluted	'	'	'	'
Net income from continuing operations	$0.01	$0.02	$0.04	$0.06
Net (loss) from discontinued operations	$0	$0	$0	$0
Shares used in computing earnings per share	'	'	'	'
Basic	60,842,413	60,787,413	60,842,413	60,762,778
Diluted	60,854,655	61,114,850	60,945,588	61,195,751

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, 2012	$61	$55,699	($25,626)	$30,134
Balance, shares at Dec. 31, 2012	60,842,413	'	'	60,842,413
Net income	'	'	2,190	2,190
Option and compensation expense	'	-34	'	-34
Balance, value at Sep. 30, 2013	$61	$55,665	($23,436)	$32,290
Balance, shares at Sep. 30, 2013	60,842,413	'	'	60,842,413

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements Of Cash Flow (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Operating activities	'	'
Net income from continuing operations	$2,318	$3,385
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion, and amortization	2,210	2,511
Amortization of loan fees-interest expense	24	42
Accretion on asset retirement obligation	100	99
Gain on sale of assets	-49	-77
Compensation and services paid in stock options and stock	25	42
Deferred tax expense	1,860	1,792
Loss on derivatives	'	140
Allowance for doubtful accounts	-98	238
Changes in assets and liabilities:	'	'
Accounts receivable	283	-312
Inventory and other assets	213	-519
Accounts payable	24	254
Accrued and other current liabilities	-148	73
Settlement on asset retirement obligation	-46	-52
Net cash provided by operating activities - continuing operations	6,716	7,616
Net cash (used in) operating activities - discontinued operations	-142	-209
Net cash provided by operating activities	6,574	7,407
Investing activities	'	'
Net additions to oil and gas properties	-836	-7,700
Net additions to methane project	'	-459
Section 1603 payment- methane facilities	'	1,000
Net additions to other property and equipment	-8	-15
Proceeds from sale of other property and equipment	113	16
Net cash (used in) investing activities - continuing operations	-731	-7,158
Net cash provided by investing activities - discontinued operations	1,395	'
Net cash provided by (used in) investing activities	664	-7,158
Financing activities	'	'
Proceeds from exercise of options	'	28
Payment in lieu of exercise of options	-60	'
Repayments of borrowings	-11,249	-15,129
Proceeds from borrowings	5,322	14,665
Loan fees	-10	-30
Net cash (used in) financing activities - continuing operations	-5,997	-466
Net cash provided by (used in) financing activities - discontinued operations	-1,253	209
Net cash (used in) financing activities	-7,250	-257
Net change in cash and cash equivalents - continuing operations	-12	-8
Cash and cash equivalents, beginning of period	31	68
Cash and cash equivalents, end of period	19	60
Supplemental cash flow information:	'	'
Cash interest payments	295	543
Cash paid for taxes	'	67
Supplemental non-cash investing and financing activities:	'	'
Financed company vehicles	78	175
Asset retirement obligations incurred	7	92
Accrued capital expenditures included in accounts payable	$245	$206

Description_Of_Business_And_Si

Description Of Business And Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
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. is a Delaware corporation (the "Company"). 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 has been the Swan Creek Field in Tennessee. The Company closed a sale of all its oil and gas leases and producing assets in Tennessee on August 16, 2013.
	The Company's wholly-owned subsidiary, Tengasco Pipeline Corporation ("TPC"), owns and operates a 65 mile intrastate pipeline which it constructed to transport natural gas from the Company's Swan Creek Field to customers in Kingsport, Tennessee. As the Company had entered into an agreement to sell the pipeline asset, it has been classified as "Assets held for sale" in the Consolidated Balance Sheet as of December 31, 2012 and the related results of operations have been classified as "(Loss) from discontinued operations, net of income tax benefit" in the Consolidated Statement of Operations for the three months and nine months ended September 30, 2013. The Company closed a sale of all its pipeline related assets on August 16, 2013. (See Note 10. Assets Held for Sale and Discontinued Operations)
	The Company's wholly-owned subsidiary, Manufactured Methane Corporation ("MMC") operates treatment and delivery facilities for the extraction of methane gas from nonconventional sources for eventual sale to natural gas customers.
	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 nine months ended September 30, 2013 are not necessarily indicative of the results that may be expected for the year ended December 31, 2013. 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, 2012.
	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 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 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. Natural gas meters are placed at the customer's location and usage is billed each month. There were no material natural gas imbalances at September 30, 2013. Methane and electricity sales meters are located at the tailgate of the Company's Methane Facility and sales 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. The Company had entered into a sweep account arrangement allowing excess cash balance to be used to pay down the Company's credit facility with F&M Bank and Trust Company ("F&M Bank"), thereby reducing overall interest cost. In April 2013, F&M Bank discontinued offering the sweep account arrangement.
	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 September 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash". The Company closed on the sale its Tennessee wells on August 16, 2013 and is in the process of obtaining a release of this Certificate of Deposit.
	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 Ocean Energy Management ("BOEM") concerning one of the Hoactzin wells operated by the Company pursuant to the Management Agreement. (See Note 5. Related Party Transactions) At September 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash". (See Note 13. Commitments and Contingencies)
	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, and allocated interest cost. The market component is calculated using the average September 2013 and December 2012 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 September 30, 2013 and December 31, 2012. The following table sets forth information concerning the Company's inventory (in thousands):
			30-Sep-13		31-Dec-12
	Oil – carried at cost	$	609	$	650
	Equipment and materials – carried at cost		649		752
	Total inventory	$	1,258	$	1,402
	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 at December 31, 2012, 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 $344,000 and $457,000 in unevaluated properties as of September 30, 2013 and December 31, 2012, respectively. 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.
	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. No such allowance was considered necessary at September 30, 2013 or December 31, 2012. At September 30, 2013 and December 31, 2012, accounts receivable consisted of the following (in thousands):
			30-Sep-13		31-Dec-12
	Revenue	$	1,274	$	1,517
	Joint interest		25		65
	Other		20		26
	Total accounts receivable	$	1,319	$	1,608
	Discontinued Operations
	During 2012, the Company committed to a plan to sell the 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. Final closing of this transaction occurred on August 16, 2013. The Company elected to classify the Pipeline assets as "Assets held for sale" in the Consolidated Balance Sheets as of December 31, 2012. The related results of operations have been classified as "(Loss) from discontinued operations, net of income tax benefit" in the Consolidated Statements of Operations for the three months and nine months ended September 30, 2013 and 2012. The related cash flows have been 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 will remain in oil and gas properties and related operations and will continue to be classified in continuing operations. Unless otherwise indicated, the information in these notes relate to the Company's continuing operations. (See Note 10. Assets Held for Sale and Discontinued Operations)
	Reclassifications
	Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income.

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2013
Income Taxes [Abstract]	'
Income Taxes	'
	(2) Income Taxes
	The total deferred tax asset was $7.5 million and $9.4 million at September 30, 2013 and December 31, 2012, respectively. During the quarter ended September 30, 2013, the Company determined that, upon sale of the Swan Creek and pipeline assets, the Company would not be able to utilize the state of Tennessee net operating loss carryforwards associated with Tengasco, Inc. and Tennessee Land and Minerals. In addition, the Company will not be able to realize the state of Tennessee tax effect of the difference between book and tax basis of the Swan Creek and pipeline assets. As a result the Company increased the valuation allowance by $350,000 to a total of $950,000 at September 30, 2013. Although management considers our valuation allowance and loss contingency as of September 30, 2013 and December 31, 2012 adequate, material changes in these amounts may occur in the future based on tax audits and changes in legislation.

Earnings_Per_Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	(3) Earnings per Share
	We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share which include the effect of all potentially dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators of our basic and diluted earnings per share, (in thousands except for share and per share amounts):
		For the Three Months Ended						For the Nine Months Ended
		30-Sep-13			30-Sep-12			30-Sep-13			30-Sep-12
	Income (numerator):
	Net income from continuing operations	$	535		$	1,279		$	2,318		$	3,385
	Net loss from discontinued operations	$	(54	)	$	(60	)	$	(128	)	$	(206	)
	Weighted average shares (denominator):
	Weighted average shares – basic		60,842,413			60,787,413			60,842,413			60,762,778
	Dilution effect of share-based		12,242			327,437			103,175			432,973
	compensation, treasury method
	Weighted average shares – dilutive		60,854,655			61,114,850			60,945,588			61,195,751
	Earnings (loss) per share – Basic and
	Dilutive:
	Continuing Operations	$	0.01		$	0.02		$	0.04		$	0.06
	Discontinued Operations	$	(0.00	)	$	(0.00	)	$	(0.00	)	$	(0.00	)

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2013
Recent Accounting Pronouncements [Abstract]	'
Recent Accounting Pronouncements	'
	(4) Recent Accounting Pronouncements
	In July 2013, the FASB issued ASU 2013-11 Income Taxes (Topic 740), Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists. This guidance provides that an unrecognized tax benefit, or a portion thereof, should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward, except to the extent that a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date to settle any additional income taxes that would result from disallowance of a tax position, or the tax law does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purpose, then the unrecognized tax benefit should be presented as a liability. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Early adoption and retrospective application is permitted. The Company does not expect this to impact its operating results, financial position or cash flows.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	5) Related Party Transactions
	On September 17, 2007, the Company entered into a drilling program with Hoactzin Partners, L.P. ("Hoactzin") for ten 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 is also the sole shareholder and controlling person of Dolphin Energy MGMT, Inc., the general partner of Dolphin Offshore Partners, L.P., and a member of SSB Ventures LLC which is the Company's largest shareholder. The terms of the Ten Well Program provided that Hoactzin would receive all the working interest in the ten wells in the Program, but will 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 will increase to 85% when and if net revenues received by Hoactzin reach an agreed payout point of approximately 1.35 times Hoactzin's purchase price (the "Payout Point") for its interest 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. As of September 30, 2013, net revenues received by Hoactzin from the Ten Well Program totaled $5.0 million which leaves a balance of approximately $193,000 until the Payout Point is reached.
	On December 18, 2007, the Company entered into a Management Agreement with Hoactzin. On the same date, the Company entered into an agreement with C. Patrick McInturff employing him as a Vice President of the Company. Pursuant to the Management Agreement with Hoactzin, Mr. McInturff's duties were to include the management on behalf of Hoactzin of its working interest in oil and gas properties owned by Hoactzin and located in the onshore Texas Gulf Coast, and offshore Texas and offshore Louisiana. The Management Agreement terminated on December 18, 2012.
	During the course of the Management Agreement, the Company became the operator of certain managed properties under the agreement. The Company obtained from IndemCo, over time, bonds in the face amount of approximately $9.6 million for the purpose of covering plugging and abandonment obligations for Hoactzin's operated properties located in federal offshore waters in favor of the Bureau of Ocean Energy Management ("BOEM"), as well as certain private parties. In connection with the issuance of these bonds, a Payment and Indemnity Agreement with IndemCo was executed by Dolphin Direct Equity Partners, LP ("Dolphin Direct") guaranteeing payment of any bonding liabilities incurred by IndemCo. Dolphin Direct is a private equity fund controlled by Peter E. Salas that has a significant economic interest in Hoactzin. The Company co-signed the Payment and Indemnity Agreement, thereby becoming jointly and severally liable with Dolphin Direct for the obligations to IndemCo under the Payment and Indemnity Agreement. Hoactzin has provided $6.6 million in cash to IndemCo as collateral for these potential obligations. The Company has not provided any cash or other collateral for these potential obligations.
	As operator of the managed Hoactzin properties, 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. Hoactzin currently has past due balances to several vendors, a portion of which are included on the Company's balance sheet. Payables related to these past due vendors as well as ongoing operations remained outstanding at September 30, 2013 and December 31, 2012 in the amounts of $331,000 and $325,000, respectively. The Company has recorded the Hoactzin-related payables and the corresponding receivable from Hoactzin as of September 30, 2013 and December 31, 2012 in its Consolidated Balance Sheets under "Accounts payable – other" and "Accounts receivable – related party". The amounts recorded in accounts receivable are net of an allowance for doubtful accounts of $159,000 and $257,000 for September 30, 2013 and December 31, 2012, respectively.
	As of the date of this Report, the Company is assisting Hoactzin with becoming operator of record of these wells and transferring the corresponding bonding liability from the Company to Hoactzin. In order to facilitate this transition, the Company has entered into an agreement with Hoactzin whereby Hoactzin and Dolphin Direct are indemnifying Tengasco for any costs or liabilities incurred by Tengasco resulting from such assistance, or the fact that Tengasco 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 September 30, 2013, the Company has suspended $257,000 in payments. This balance in recorded in the Consolidated Balance Sheet under Accounts payable – related party.
	No Tengasco funds have been advanced by Tengasco to pay any obligations of Hoactzin. No borrowing capability of Tengasco 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. (See Note 13. Commitments and Contingencies)

Oil_And_Gas_Properties

Oil And Gas Properties	9 Months Ended
	Sep. 30, 2013
Oil And Gas Properties [Abstract]	'
Oil And Gas Properties	'
	(6) Oil and Gas Properties
	The following table sets forth information concerning the Company's oil and gas properties (in thousands):
			30-Sep-13			31-Dec-12
	Oil and gas properties, at cost	$	44,203		$	43,351
	Unevaluated properties		344			457
	Accumulated depletion		(21,077	)		(19,108	)
	Oil and gas properties, net	$	23,470		$	24,700
	The Company recorded depletion expense of $1,969,000 and $2,237,000 for the nine months ended September 30, 2013 and 2012, respectively.
	.

Asset_Retirement_Obligation

Asset Retirement Obligation	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligation	'
	(7) Asset Retirement Obligation
	Our asset retirement obligations represent the estimated present value of the amount we will incur to plug, abandon, and remediate our producing properties at the end of their productive lives in accordance with applicable laws. The following table summarizes the Company's Asset Retirement Obligation transactions for the nine months ended September 30, 2013 (in thousands):
	Balance December 31, 2012	$	2,099
	Accretion expense		100
	Liabilities incurred		7
	Liabilities settled		(46	)
	Assets sold		(348	)
	Balance September 30, 2013	$	1,812
	Assets sold during the first nine months of 2013 represents asset retirement obligations related to the Swan Creek wells which were sold on August 16, 2013.

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Long-Term Debt [Abstract]	'
Long-Term Debt	'
	(8) Long-Term Debt
	Long-term debt to unrelated entities consisted of the following (in thousands):
			30-Sep-13			31-Dec-12
	Note payable to a financial institution, with interest only
	payment until maturity.	$	3,032		$	10,138
	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
	$ 20,000		157			208
	Total long-term debt		3,189			10,346
	Less current maturities		(77	)		(100	)
	Long-term debt, less current maturities	$	3,112		$	10,246
	At September 30, 2013, the Company had a revolving credit facility with F&M Bank & Trust Company ("F&M Bank"). 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 September 30, 2013, the Company's borrowing base was $20.5 million and the interest rate is the greater of prime plus 0.25% or 5.25% per annum. The Company's interest rate at September 30, 2013 was 5.25%. 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 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.
	On October 24, 2013, the Company's senior credit facility with F&M Bank after F&M Bank's semiannual review of the Company's currently owned producing properties was amended to decrease the Company's borrowing base from $20.5 million to $17.5 million. The borrowing base remains subject to the existing periodic redetermination provision in the credit facility. The interest rate was modified from the greater of prime plus 0.25% or 5.25% per annum, to prime plus 0.50%. The maximum line of credit of the Company under the F&M Bank credit facility remained $40 million.
	The total borrowing by the Company under the credit facility at September 30, 2013 and December 31, 2012 was $3.0 million and $10.1 million, respectively. The next borrowing base review will take place in March 2014.

Methane_Project

Methane Project	9 Months Ended
	Sep. 30, 2013
Methane Project [Abstract]	'
Methane Project	'
	(9) 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 $98,000 and $79,000 for the nine months ended September 30, 2013 and 2012, respectively.

Assets_Held_For_Sale_And_Disco

Assets Held For Sale And Discontinued Operations	9 Months Ended
	Sep. 30, 2013
Assets Held For Sale And Discontinued Operations [Abstract]	'
Assets Held For Sale And Discontinued Operations	'
	10) Assets Held For Sale and Discontinued Operations
	Assets held for sale represent the carrying value of the pipeline asset of $1.4 million as of December 31, 2102. Since the sale closed on August 16, 2013, no value is included at September 30, 2013. The determination of the pipeline value was based on discussions and negotiations with a third party regarding the sale of the Pipeline asset.
	The following table summarizes the 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 months and nine months ended September 30, 2013 and 2012: (in thousands)
			For the three months ended						For the nine months ended
		30-Sep-13			30-Sep-12			30-Sep-13			30-Sep-12
	Revenues	$	5		$	7		$	22		$	19
	Production costs and taxes		(25	)		(62	)		(164	)		(228	)
	Depreciation, depletion, and		-			(44	)		-			(132	)
	amortization
	Gain on sale of assets		128			-			128			-
	Income tax benefit (expense)		(162	)		39			(114	)		135
	Income (loss) from discontinued	$	(54	)	$	(60	)	$	(128	)	$	(206	)
	operations, net of income tax benefit

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	(11) Fair Value Measurements
	The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, account payables, accrued liabilities and long term debt in our balance sheet approximates fair value as of September 30, 2013 and December 31, 2012.

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2013
Derivatives [Abstract]	'
Derivatives	'
	(12) Derivatives
	The Company records changes in the unrealized derivative asset or liability as a "Gain or loss on derivatives" in the Consolidated Statements of Operations. During the three months and nine months ended September 30, 2012, the Company recorded a loss on derivatives of $35,000 and $140,000, respectively. As of September 30, 2013 and December 31, 2012, the Company did not have any open forward positions.

Commitments_And_Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	(13) Commitments and Contingencies
	The Company as designated operator of the Hoactzin properties was administratively issued an "Incidence of Non-Compliance" by BOEM during the quarter ended September 30, 2012 concerning one of Hoactzin's operated wells. This action calls for payment of a civil penalty of $386,000 for the late filing of certain reports in 2011 by a contractor on the facility. The Company has filed an appeal 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 is determined. The Company has posted and collateralized this bond with RLI Insurance Company. If the bond was not posted, the appeal would have been administratively denied and the $386,000 penalty would have become final and no longer subject to appeal. While the Company believes it will ultimately prevail in the appeal process, it is reasonably possible to expect that the civil penalty may not be substantially reduced. The Company estimates the range of this possible payment to be between zero and $386,000. During the quarter ended September 30, 2013 there have been no new developments in this appeal process.

Description_Of_Business_And_Si1

Description Of Business And Significant Accounting Policies (Policy)	9 Months Ended
	Sep. 30, 2013
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 nine months ended September 30, 2013 are not necessarily indicative of the results that may be expected for the year ended December 31, 2013. 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, 2012.
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 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 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. Natural gas meters are placed at the customer's location and usage is billed each month. There were no material natural gas imbalances at September 30, 2013. Methane and electricity sales meters are located at the tailgate of the Company's Methane Facility and sales 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. The Company had entered into a sweep account arrangement allowing excess cash balance to be used to pay down the Company's credit facility with F&M Bank and Trust Company ("F&M Bank"), thereby reducing overall interest cost. In April 2013, F&M Bank discontinued offering the sweep account arrangement.
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 September 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash". The Company closed on the sale its Tennessee wells on August 16, 2013 and is in the process of obtaining a release of this Certificate of Deposit.
	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 Ocean Energy Management ("BOEM") concerning one of the Hoactzin wells operated by the Company pursuant to the Management Agreement. (See Note 5. Related Party Transactions) At September 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash". (See Note 13. Commitments and Contingencies)
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, and allocated interest cost. The market component is calculated using the average September 2013 and December 2012 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 September 30, 2013 and December 31, 2012. The following table sets forth information concerning the Company's inventory (in thousands):
			30-Sep-13		31-Dec-12
	Oil – carried at cost	$	609	$	650
	Equipment and materials – carried at cost		649		752
	Total inventory	$	1,258	$	1,402
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 at December 31, 2012, 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 $344,000 and $457,000 in unevaluated properties as of September 30, 2013 and December 31, 2012, respectively. 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.
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. No such allowance was considered necessary at September 30, 2013 or December 31, 2012. At September 30, 2013 and December 31, 2012, accounts receivable consisted of the following (in thousands):
			30-Sep-13		31-Dec-12
	Revenue	$	1,274	$	1,517
	Joint interest		25		65
	Other		20		26
	Total accounts receivable	$	1,319	$	1,608
Discontinued Operations	'
	Discontinued Operations
	During 2012, the Company committed to a plan to sell the 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. Final closing of this transaction occurred on August 16, 2013. The Company elected to classify the Pipeline assets as "Assets held for sale" in the Consolidated Balance Sheets as of December 31, 2012. The related results of operations have been classified as "(Loss) from discontinued operations, net of income tax benefit" in the Consolidated Statements of Operations for the three months and nine months ended September 30, 2013 and 2012. The related cash flows have been 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 will remain in oil and gas properties and related operations and will continue to be classified in continuing operations. Unless otherwise indicated, the information in these notes relate to the Company's continuing operations. (See Note 10. Assets Held for Sale and Discontinued Operations)
Reclassifications	'
	Reclassifications
	Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income.

Description_Of_Business_And_Si2

Description Of Business And Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2013
Description Of Business And Significant Accounting Policies [Abstract]	'
Inventory	'
			30-Sep-13		31-Dec-12
	Oil – carried at cost	$	609	$	650
	Equipment and materials – carried at cost		649		752
	Total inventory	$	1,258	$	1,402
Accounts Receivable	'
			30-Sep-13		31-Dec-12
	Revenue	$	1,274	$	1,517
	Joint interest		25		65
	Other		20		26
	Total accounts receivable	$	1,319	$	1,608

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Reconciliations Of The Numerators And Denominators Of Basic And Diluted Earnings Per Share	'
		For the Three Months Ended						For the Nine Months Ended
		30-Sep-13			30-Sep-12			30-Sep-13			30-Sep-12
	Income (numerator):
	Net income from continuing operations	$	535		$	1,279		$	2,318		$	3,385
	Net loss from discontinued operations	$	(54	)	$	(60	)	$	(128	)	$	(206	)
	Weighted average shares (denominator):
	Weighted average shares – basic		60,842,413			60,787,413			60,842,413			60,762,778
	Dilution effect of share-based		12,242			327,437			103,175			432,973
	compensation, treasury method
	Weighted average shares – dilutive		60,854,655			61,114,850			60,945,588			61,195,751
	Earnings (loss) per share – Basic and
	Dilutive:
	Continuing Operations	$	0.01		$	0.02		$	0.04		$	0.06
	Discontinued Operations	$	(0.00	)	$	(0.00	)	$	(0.00	)	$	(0.00	)

Oil_And_Gas_Properties_Tables

Oil And Gas Properties (Tables)	9 Months Ended
	Sep. 30, 2013
Oil And Gas Properties [Abstract]	'
Schedule Of Oil And Gas Properties	'
			30-Sep-13			31-Dec-12
	Oil and gas properties, at cost	$	44,203		$	43,351
	Unevaluated properties		344			457
	Accumulated depletion		(21,077	)		(19,108	)
	Oil and gas properties, net	$	23,470		$	24,700

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligation Transactions	'
	Balance December 31, 2012	$	2,099
	Accretion expense		100
	Liabilities incurred		7
	Liabilities settled		(46	)
	Assets sold		(348	)
	Balance September 30, 2013	$	1,812

LongTerm_Debt_Tables

Long-Term Debt (Tables)	21 Months Ended
	Sep. 30, 2013
Long-Term Debt [Abstract]	'
Schedule Of Long-Term Debt To Unrelated Entities	'
			30-Sep-13			31-Dec-12
	Note payable to a financial institution, with interest only
	payment until maturity.	$	3,032		$	10,138
	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
	$ 20,000		157			208
	Total long-term debt		3,189			10,346
	Less current maturities		(77	)		(100	)
	Long-term debt, less current maturities	$	3,112		$	10,246

Assets_Held_For_Sale_And_Disco1

Assets Held For Sale And Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2013
Assets Held For Sale And Discontinued Operations [Abstract]	'
Schedule Of The Amounts In Net Loss From Discontinued Operations	'
			For the three months ended						For the nine months ended
		30-Sep-13			30-Sep-12			30-Sep-13			30-Sep-12
	Revenues	$	5		$	7		$	22		$	19
	Production costs and taxes		(25	)		(62	)		(164	)		(228	)
	Depreciation, depletion, and		-			(44	)		-			(132	)
	amortization
	Gain on sale of assets		128			-			128			-
	Income tax benefit (expense)		(162	)		39			(114	)		135
	Income (loss) from discontinued	$	(54	)	$	(60	)	$	(128	)	$	(206	)
	operations, net of income tax benefit

Description_Of_Business_And_Si3

Description Of Business And Significant Accounting Policies (Narrative) (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
	mi
Length of pipeline, miles	65	'
material natural gas imbalances	$0	'
Restricted cash	507,000	507,000
Unevaluated properties	344,000	457,000
Current cost discount	10.00%	'
Agreement to sell the Company's Swan Creek and Pipeline assets	1,500,000	'
Allowance	0	0
Certificates of Deposit [Member]	'	'
Restricted cash	120,500	120,500
Collateralized Bond [Member]	'	'
Restricted cash	'	$386,000

Description_Of_Business_And_Si4

Description Of Business And Significant Accounting Policies (Inventory) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Description Of Business And Significant Accounting Policies [Abstract]	'	'
Oil - carried at cost	$609	$650
Equipment and materials - carried at cost	649	752
Total inventory	$1,258	$1,402

Description_Of_Business_And_Si5

Description Of Business And Significant Accounting Policies (Accounts Receivable) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	$1,319	$1,608
Revenue [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	1,274	1,517
Joint Interest [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	25	65
Other [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable	$20	$26

Income_Taxes_Details

Income Taxes (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Income Taxes [Abstract]	'	'
Deferred tax asset	$7,500,000	$9,400,000
Increase in valuation allowance	350,000	'
Valuation allowance	$950,000	'

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Earnings Per Share [Abstract]	'	'	'	'
Net income from continuing operations	$535	$1,279	$2,318	$3,385
Net loss from discontinued operations	($54)	($60)	($128)	($206)
Weighted average shares - basic	60,842,413	60,787,413	60,842,413	60,762,778
Dilution effect of share-based compensation, treasury method	12,242	327,437	103,175	432,973
Weighted average shares - dilutive	60,854,655	61,114,850	60,945,588	61,195,751
Continuing Operations	$0.01	$0.02	$0.04	$0.06
Discontinued Operations	$0	$0	$0	$0

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

3 Months Ended

9 Months Ended

69 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Dec. 18, 2007

Jun. 30, 2013

Sep. 30, 2013

Dec. 18, 2007

Mar. 31, 2008

Sep. 17, 2007

Sep. 17, 2007

Sep. 17, 2007

Hoactzin Partners, L.P. [Member]

Hoactzin Partners, L.P. [Member]

Hoactzin Partners, L.P. [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

Ten Well Program [Member]

item

At Or Above Revenue Threshold [Member]

Up To Revenue Threshold [Member]

Productive Wells [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Wells in process of drilling

'

'

'

'

'

'

'

'

'

'

10

'

'

Percent of working interest revenue, as a fee

'

'

'

'

'

'

'

'

'

'

'

85.00%

25.00%

Payout point multiplier

'

'

'

'

'

'

'

'

'

'

1.35

'

'

Related party transaction

'

'

'

'

'

'

'

'

'

$3,850,000

'

'

'

Payout point value

193,000

'

193,000

'

'

'

'

'

'

5,200,000

'

'

'

Revenues

4,034,000

5,806,000

12,219,000

15,990,000

'

'

5,000,000

'

'

'

'

'

'

Bond, face value

'

'

'

'

'

9,600,000

'

'

'

'

'

'

'

Cash collateral

'

'

'

'

'

'

'

'

6,600,000

'

'

'

'

Related parties accounts payable

331,000

'

331,000

'

325,000

'

'

'

'

'

'

'

'

Related party allowance for doubtful accounts receivable

159,000

'

159,000

'

257,000

'

'

'

'

'

'

'

'

Suspended portion of accounts payable

257,000

'

257,000

'

'

'

'

'

'

'

'

'

'

Funds advanced

'

'

'

'

'

'

'

0

'

'

'

'

'

Borrowing capability used

'

'

'

'

'

'

'

$0

'

'

'

'

'

Oil_And_Gas_Properties_Details

Oil And Gas Properties (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Oil And Gas Properties [Abstract]	'	'	'
Oil and gas properties, at cost	$44,203,000	'	$43,351,000
Unevaluated properties	344,000	'	457,000
Accumulated depletion	-21,077,000	'	-19,108,000
Oil and gas properties, net	23,470,000	'	24,700,000
Depletion expense	$1,969,000	$2,237,000	'

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Asset Retirement Obligation [Abstract]	'	'
Balance	$2,099	'
Accretion expense	100	99
Liabilities incurred	7	'
Liabilities settled	-46	-52
Assets sold	-348	'
Balance	$1,812	'

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)	Oct. 24, 2013	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
F&M Bank [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Credit facility maximum borrowing capacity	'	$40	'
Credit facility current borrowing capacity	'	20.5	'
Decreased borrowing base	17.5	'	'
Interest rate per annum	'	5.25%	'
Rate above prime	0.50%	0.25%	'
Loans and letters of credit amount outstanding	'	$3	$10.10
Maximum [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Interest rate per annum	'	8.25%	8.25%
Minimum [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Interest rate per annum	'	5.50%	5.50%
Minimum [Member] | F&M Bank [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Interest rate per annum	'	5.25%	'

LongTerm_Debt_Schedule_Of_Long

Long-Term Debt (Schedule Of Long-Term Debt To Unrelated Entities) (Details) (USD $)	9 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Note payable to financial institution, with interest only payment until maturity	$3,032	$10,138
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 $20,000	157	208
Total long-term debt	3,189	10,346
Less current maturities	-77	-100
Long-term debt, less current maturities	3,112	10,246
Periodic payments including interest, insurance and maintenance	$20,000	$20,000
Maximum [Member]	'	'
Debt Instrument [Line Items]	'	'
Interest rate per annum	8.25%	8.25%
Minimum [Member]	'	'
Debt Instrument [Line Items]	'	'
Interest rate per annum	5.50%	5.50%

Methane_Project_Details

Methane Project (Details) (Methane Project [Member], USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
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	$98,000	$79,000

Assets_Held_For_Sale_And_Disco2

Assets Held For Sale And Discontinued Operations (Narrative) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Assets Held For Sale And Discontinued Operations [Abstract]	'	'
Assets held for sale	'	$1,400

Assets_Held_For_Sale_And_Disco3

Assets Held For Sale And Discontinued Operations (Schedule Of The Amounts In Net Loss From Discontinued Operations) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Assets Held For Sale And Discontinued Operations [Abstract]	'	'	'	'
Revenues	$5	$7	$22	$19
Production costs and taxes	-25	-62	-164	-228
Depreciation, depletion, and amortization	'	-44	'	-132
Gain on sale of assets	128	'	128	'
Income tax benefit (expense)	-162	39	-114	135
Income (loss) from discontinued operations, net of income tax benefit	($54)	($60)	($128)	($206)

Derivatives_Narrative_Details

Derivatives (Narrative) (Details) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2013	Dec. 31, 2012
Derivatives [Abstract]	'	'	'	'
Unrealized gain (loss) on derivatives	$35,000	$140,000	'	'
Open forward positions	'	'	$0	$0

Commitments_And_Contingencies_

Commitments And Contingencies (Details) (USD $)	3 Months Ended
	Sep. 30, 2012	Sep. 30, 2013
	item
Commitments And Contingencies [Abstract]	'	'
Wells issued incidence of non-compliance	1	'
Minimum potential loss	'	$0
Maximum potential loss	'	$386,000