10-Q

U.S. Securities and Exchange Commission

Washington, D.C. 20549

Form 10-Q

QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2013

Commission File No. 1-15555

Tengasco, Inc.

(Exact name of registrant as specified in its charter)

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

11121 Kingston Pike, Suite E, Knoxville, TN 37934

(Address of principal executive offices)

(865-675-1554)

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No o

Indicate by checkmark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). x Yes o No.

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

Large accelerated filer o	Accelerated filer o
Non-accelerated filer  o	Smaller reporting company  þ
(Do not check if a smaller reporting company)

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 60,842,413 common shares at August 5, 2013.

TABLE OF CONTENTS

PART I.	FINANCIAL INFORMATION	PAGE
	ITEM 1. FINANCIAL STATEMENTS
	*    Unaudited Condensed Consolidated Balance Sheets as of June 30, 2013 and December 31, 2012	3
	*    Unaudited Condensed Consolidated Statements of Operations for the three months and six months ended June 30, 2013 and 2012	5
	*    Unaudited Condensed Consolidated Statement of Stockholders’ Equity for the six months ended June 30, 2013	6
	*    Unaudited Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2013 and 2012	7
	*    Notes to Unaudited Condensed Consolidated Financial Statements	8
	ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	18
	ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	21
	ITEM 4. CONTROLS AND PROCEDURES	23
PART II.	OTHER INFORMATION	24
	ITEM 1. LEGAL PROCEEDINGS	24
	ITEM 1A. RISK FACTORS	24
	ITEM 2. UNREGISTERD SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	24
	ITEM 3. DEFAULTS UPON SENIOR SECURITIES	24
	ITEM 4. MINE SAFTY DISCLOSURES	25
	ITEM 5. OTHER INFORMATION	25
	ITEM 6. EXHIBITS	25
	*    SIGNATURES	26
	*    CERTIFICATIONS

Tengasco, Inc. and SubsidiariesCondensed Consolidated Balance Sheets(unaudited)(in thousands, except share data)

	June 30, 2013		December 31, 2012
Assets
Current
Cash and cash equivalents	$	152	$	31
Accounts receivable		1,285		1,608
Accounts receivable – related party, less allowance for doubtful accounts of $159 and $257		212		68
Inventory		1,379		1,402
Other current assets		203		194
Total current assets		3,231		3,303
Restricted cash		507		507
Loan fees, net		51		57
Oil and gas properties, net (full cost accounting method)		23,779		24,700
Methane project, net		4,386		4,445
Other property and equipment, net		214		321
Assets held for sale		1,400		1,400
Deferred tax asset-noncurrent		8,335		9,434
Total assets	$	41,903	$	44,167

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

3

Tengasco, Inc. and SubsidiariesCondensed Consolidated Balance Sheets(unaudited)(in thousands, except share data)

	June 30, 2013			December 31, 2012
Liabilities and Stockholders’ Equity
Current liabilities
Accounts payable – trade	$	360		$	648
Accounts payable – other		371			325
Accrued and other current liabilities		571			615
Current maturities of long-term debt		84			100
Total current liabilities		1,386			1,688
Asset retirement obligation		2,160			2,099
Long term debt, less current maturities		6,555			10,246
Total liabilities		10,101			14,033
Commitments and contingencies (Note 13)
Stockholders’ equity
Common stock, $.001 par value, authorized 100,000,000 shares, 60,842,413 and 60,842,413 shares issued and outstanding		61			61
Additional paid–in capital		55,657			55,699
Accumulated deficit		(23,916	)		(25,626	)
Total stockholders’ equity		31,802			30,134
Total liabilities and stockholders’ equity	$	41,903		$	44,167

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

4

Tengasco, Inc. and SubsidiariesCondensed Consolidated Statements of Operations(unaudited)(in thousands, except share and per share data)

	For the Three Months Ended June 30,						For the Six Months Ended June 30,
	2013			2012			2013			2012
Revenues	$	3,871		$	5,222		$	8,185		$	10,184
Cost and expenses
Production costs and taxes		1,191			1,934			2,561			3.602
Depreciation, depletion, and amortization		742			860			1,537			1,569
General and administrative		466			600			979			1,359
Total cost and expenses		2,399			3,394			5,077			6,530
Net income from operations		1,472			1,828			3,108			3,654
Other income (expense)
Interest expense		(109	)		(206	)		(240	)		(394	)
Gain (loss) on derivatives		-			15			-			(105	)
Gain on sale of assets		63			33			63			67
Total other income (expenses)		(46	)		(158	)		(177	)		(432	)
Income from continuing operations before income tax		1,426			1,670			2,931			3,222
Income tax expense		(621	)		(518	)		(1,147	)		(1,116	)
Income from continuing operations		805			1,152			1,784			2,106
(Loss) from discontinued operations, net of income tax benefit		(33	)		(65	)		(74	)		(146	)
Net income	$	772		$	1,087		$	1,710		$	1,960
Net income (loss) per share – Basic and Diluted
Net income from continuing operations	$	0.01		$	0.02		$	0.03		$	0.03
Net (loss) from discontinued operations	$	(0.00	)	$	(0.00	)	$	(0.00	)	$	(0.00	)
Shares used in computing earnings per share
Basic		60,842,413			60,763,237			60,842,413			60,750,325
Diluted		60,928,397			61,214,257			60,991,055			61,236,066

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

5

Tengasco, Inc. and SubsidiariesCondensed Consolidated Statements of Stockholders’ Equity(unaudited)(in thousands, except share data)

	Common Stock
	Shares		Amount		Paid in Capital			Accumulated Deficit			Total
Balance, December 31, 2012		60,842,413	$	61	$	55,699		$	(25,626	)	$	30,134
Net income		-		-		-			1,710			1,710
Option and compensation expense		-		-		(42	)		-			(42	)
Balance, June 30, 2013		60,842,413	$	61	$	55,657		$	(23,916	)	$	31,802

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

6

Tengasco, Inc. and SubsidiariesCondensed Consolidated Statements of Cash Flow

(unaudited)

(in thousands)

	For the Six Months Ended June 30,
	2013			2012
Operating activities
Net income from continuing operations	$	1,784		$	2,106
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, and amortization		1,537			1,569
Amortization of loan fees-interest expense		16			29
Accretion on asset retirement obligation		70			67
Gain on sale of assets		(63	)		(67	)
Compensation and services paid in stock options and stock		18			27
Deferred tax expense		1,147			1,049
Loss on derivatives		-			105
Changes in assets and liabilities:
Accounts receivable		179			(276	)
Inventory and other assets		14			(529	)
Accounts payable		(242	)		144
Accrued and other current liabilities		(106	)		(118	)
Settlement on asset retirement obligation		(12	)		(41	)
Net cash provided by operating activities – continuing operations		4,342			4,065
Net cash (used in) operating activities – discontinued operations		(122	)		(154	)
Net cash provided by operating activities		4,220			3,911
Investing activities
Net additions to oil and gas properties		(385	)		(6,792	)
Net additions to methane project		-			(459	)
Section 1603 payment – methane facilities		-			1,000
Net additions to other property and equipment		-			(15	)
Proceeds from sale of other property and equipment		63			16
Net cash used in investing activities – continuing operations		(322	)		(6,250	)
Financing activities
Proceeds from exercise of options		-			28
Payment in lieu of exercise of options		(60	)		-
Repayments of borrowings		(8,029	)		(9,655	)
Proceeds from borrowings		4,200			11,834
Loan fees		(10	)		(30	)
Net cash provided by (used in) financing activities – continuing operations		(3,899	)		2,177
Net cash provided by financing activities – discontinued operations		122			154
Net cash provided by (used in) financing activities		(3,777	)		2,331
Net change in cash and cash equivalents – continuing operations		121			(8	)
Cash and cash equivalents, beginning of period		31			68
Cash and cash equivalents, end of period	$	152		$	60
Supplemental cash flow information:
Cash interest payments	$	224		$	365
Supplemental non-cash investing and financing activities:
Financed company vehicles	$	-		$	127
Asset retirement obligations incurred	$	3		$	92
Accrued capital expenditures included in accounts payable	$	62		$	480

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

7

Tengasco, Inc. and SubsidiariesNotes to Unaudited Condensed Consolidated Financial Statements

(1)    Description of Business and Significant Accounting Policies

Tengasco, Inc. is a Delaware corporation (the “Company”).  The Company is in the business of exploration 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 is the Swan Creek Field in Tennessee.

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 has entered into an agreement to sell the pipeline asset, it has been classified as “Assets held for sale” in the Consolidated Balance Sheets as of June 30, 2013 and 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 six months ended June 30, 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 six months ended June 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.

8

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

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 June 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 June 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under “Restricted cash”.

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 June 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under “Restricted cash”.  (See Note 13. Commitments and Contingencies)

9

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

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 June 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 June 30, 2013 and December 31, 2012.  The following table sets forth information concerning the Company’s inventory (in thousands):

	June 30, 2013		December 31, 2012
Oil – carried at cost	$	627	$	650
Equipment and materials – carried at cost		752		752
Total inventory	$	1,379	$	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 $457,000 in unevaluated properties as of June 30, 2013 and December 31, 2012.  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.

10

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

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 June 30, 2013 or December 31, 2012.  At June 30, 2013 and December 31, 2012, accounts receivable consisted of the following (in thousands):

	June 30, 2013		December 31, 2012
Revenue	$	1,253	$	1,517
Joint interest		32		65
Other		-		26
Total accounts receivable	$	1,285	$	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 is contingent upon customary due diligence as well as certain regulatory and easement holder approvals.  The Company has elected to classify the Pipeline assets as “Assets held for sale” in the Consolidated Balance Sheets as of June 30, 2013 and 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 six months ended June 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 represent 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)

11

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

Reclassifications

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

(2)    Income Taxes

The total deferred tax asset was $8.3 million and $9.4 million at June 30, 2013 and December 31, 2012, respectively.  Although management considers our valuation allowance and loss contingency as of June 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.

(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 Six Months Ended
	June 30, 2013			June 30, 2012			June 30, 2013			June 30, 2012
Income (numerator):
Net income from continuing operations	$	805		$	1,152		$	1,784		$	2,106
Net loss from discontinued operations	$	(33	)	$	(65	)	$	(74	)	$	(146	)
Weighted average shares (denominator):
Weighted average shares – basic		60,842,413			60,763,237			60,842,413			60,750,325
Dilution effect of share-based compensation, treasury method		85,984			451,020			148,642			485,741
Weighted average shares – dilutive		60,928,397			61,214,257			60,991,055			61,236,066
Earnings (loss) per share – Basic and Dilutive:
Continuing Operations	$	0.01		$	0.02		$	0.03		$	0.03
Discontinued Operations	$	(0.00	)	$	(0.00	)	$	(0.00	)	$	(0.00	)

(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.

12

Tengasco, Inc. and SubsidiariesNotes to Unaudited Condensed Consolidated Financial Statements

(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 June 30, 2013, net revenues received by Hoactzin from the Ten Well Program totaled $4.874 million which leaves a balance of approximately $326,000 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.

13

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

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 significant 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 June 30, 2013 and December 31, 2012 in the amounts of $371,000 and $325,000, respectively.  The Company has recorded the Hoactzin-related payables and the corresponding receivable from Hoactzin as of June 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 of $159,000 and $257,000 for June 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.

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)

(6)    Oil and Gas Properties

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

	June 30, 2013			December 31, 2012
Oil and gas properties, at cost	$	43,800		$	43,351
Unevaluated properties		457			457
Accumulated depletion		(20,478	)		(19,108	)
Oil and gas properties, net	$	23,779		$	24,700

14

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

The Company recorded depletion expense of $1,370,000 and $1,386,000 for the six months ended June 30, 2013 and 2012, respectively.

(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 six months ended June 30, 2013 (in thousands):

Balance December 31, 2012	$	2,099
Accretion expense		70
Liabilities incurred		3
Liabilities settled		(12	)
Balance June 30, 2013	$	2,160

(8)    Long-Term Debt

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

	June 30, 2013			December 31, 2012
Note payable to a financial institution, with interest only payment until maturity.	$	6,482		$	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		6,639			10,346
Less current maturities		(84	)		(100	)
Long-term debt, less current maturities	$	6,555		$	10,246

At June 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 June 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 June 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 pipeline 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.

15

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

The total borrowing by the Company under the credit facility at June 30, 2013 and December 31, 2012 was $6.5 million and $10.1 million, respectively.  The next borrowing base review will take place in August 2013.

(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 $59,000 and $54,000 for the six months ended June 30, 2013 and 2012, respectively.

(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 June 30, 2013 and December 31, 2102.  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 six months ended June 30, 2013 and 2012: (in thousands)

	For the three months ended						For the six months ended
	June 30, 2013			June 30, 2012			June 30, 2013			June 30, 2012
Revenues	$	8		$	8		$	17		$	12
Production costs and taxes		(67	)		(72	)		(139	)		(166	)
Depreciation, depletion, and amortization		-			(44	)		-			(88	)
Deferred income tax benefit		26			43			48			96
(Loss) from discontinued operations, net of income tax benefit	$	(33	)	$	(65	)	$	(74	)	$	(146	)

(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 June 30, 2013 and December 31, 2012.

16

Tengasco, Inc. and Subsidiaries Notes to Unaudited Condensed Consolidated Financial Statements

(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 six months ended June 30, 2012, the Company recorded a gain on derivatives of $15,000 and a loss on derivatives of $105,000, respectively.  As of June 30, 2013 and December 31, 2012, the Company did not have any open forward positions.

(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 be administratively denied and the order to the Company as operator to pay the $386,000 penalty would be final.  While the Company believes it will ultimately prevail in the appeal process, it is reasonably possible to expect that the Company may be required to pay a portion of this penalty.  The Company estimates the range of this possible payment to be between zero and $386,000.  During the quarter ended June 30, 2013 there have been no new developments in this appeal process.

17

Tengasco, Inc. and Subsidiaries

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

Results of Operations and Financial Condition

During the first six months of 2013, the Company sold 112 MBbl of oil from its Kansas wells. Of the 112 MBbl, 87 MBbl were net to the Company after required payments to all of the royalty interests and drilling program participants.  The Company’s net sales from its Kansas wells during the first six months of 2013 of 87 MBbl of oil compares to net sales of 106 MBbl during the first six months of 2012.  This 19 MBbl decrease was due primarily to decreased sales volumes from the Albers, DeYoung, and Veverka B leases due to drilling and polymers performed in the first six months of 2012, and the Liebenau lease due to declines from higher volumes realized in the first six months of 2012 as a result of polymers performed in late 2011. The Company’s net revenue from the Kansas properties was $7.6 million in the first six months of 2013 compared to $9.6 million for the first six months of 2012.  This decrease in net revenue was due primarily to a $1.7 million decrease related to the 19 MBbl decrease in sales volumes and a $273,000 decrease related to a $3.14 per barrel decrease in the average Kansas oil price from $90.57 per barrel in 2012 to $87.43 per barrel in 2013.  During the first six months of 2013 and 2012, Swan Creek sales were $287,000 and $180,000, respectively and MMC revenues were $258,000 and $382,000, respectively.

Comparison of the Quarters Ended June 30, 2013 and 2012

The Company recognized $3.9 million in revenues during the second quarter of 2013 and $5.2 million during the second quarter of 2012. The revenue decrease from 2012 levels was primarily due to a $1.4 million decrease related to a 16 MBbl decrease in Kansas oil sales volumes.  Kansas oil prices during the second quarter of 2013 averaged $87.32 per barrel compared to an average price of $85.90 per barrel during the second quarter of 2012. The Company reported net income from continuing operations of $805,000 or $0.01 per share of common stock during the second quarter of 2013 compared to net income from continuing operations of $1,152,000 or $0.02 per share of common stock during the second quarter of 2012.  Although revenues decreased $1.3 million, this decrease was partially offset by a $743,000 decrease in operating cost, a $134,000 decrease in general and administrative cost, and an $118,000 decrease in depreciation, depletion, and amortization.

Production costs and taxes decreased $743,000 from $1.9 million during the second quarter of 2012 to $1.2 million during the second quarter of 2013.  This decrease from 2012 levels was primarily due to a $285,000 decrease related to changes in Kansas oil inventories, a $93,000 net decrease in Kansas property taxes related primarily to a successful appeal of 2012 property taxes, a $67,000 decrease in production taxes, and a $65,000 decrease in MMC expense primarily related to repairs performed in 2012.

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Tengasco, Inc. and Subsidiaries

Depreciation, depletion, and amortization expense decreased $118,000 from $860,000 during the second quarter of 2012 to $742,000 during the second quarter of 2013.  This decrease was primarily due to lower oil and gas volumes in the second quarter of 2013 compared to the oil and gas volumes during the second quarter of 2012, partially offset by higher depletion rates during the second quarter of 2013.

General and administrative costs decreased $134,000 from $600,000 during the second quarter of 2012 to $466,000 during the second quarter of 2013.  This decrease was primarily due to a $98,000 reversal of bad debt expense associated with the related party receivable during the second quarter of 2013.

Interest expense decreased $97,000 from $206,000 during the second quarter of 2012 to $109,000 during the second quarter of 2013.  This decrease in interest expense was primarily due to a $6.6 million decrease in average bank borrowings from $14.0 million during the second quarter of 2012 to $7.4 million during the second quarter of 2013.  This decrease in average bank borrowings related to a significant decrease in capital spending since the second quarter of 2012.

Comparison of the Six Months Ended June 30, 2013 and 2012

The Company recognized $8.2 million in revenues during the first six months of 2013 compared to $10.2 million during the first six months of 2012. The revenue decrease from 2012 levels was primarily due to a $1.7 million decrease related to a 19 MBbl decrease in Kansas oil sales volumes, and a $273,000 decrease related to a $3.14 per barrel decrease in average Kansas oil prices. Kansas oil prices during the first six months of 2013 averaged $87.43 per barrel compared to an average price of $90.57 per barrel during the first six months of 2012. The Company reported net income from continuing operations of $1.8 million or $0.03 per share of common stock during the first six months of 2013 compared to net income from continuing operations of $2.1 million or $0.03 per share of common stock during the first six months of 2012.  Although revenues decreased $2.0 million, this decrease was offset by a $1.0 million decrease in operating cost, a $380,000 decrease in general and administrative cost, a $154,000 decrease in interest expense, and a $105,000 decrease in loss on derivatives.

Production costs and taxes decreased $1.0 million from $3.6 million during the first six months of 2012 to $2.6 million during the first six months of 2013.  This decrease from 2012 levels was primarily due to a $174,000 decrease related to changes in Kansas oil inventories, a $163,000 decrease in production taxes, a $149,000 decrease in MMC expense primarily related to repairs performed in 2012, a $143,000 decrease in Kansas property taxes related primarily to a successful appeal of 2012 property taxes, and $105,000 lower well repair cost incurred in 2013 compared to 2012 levels.

General and administrative costs decreased $380,000 from $1.4 million during the first six months of 2012 to $979,000 during the first six months of 2013.  This decrease was primarily due to a $159,000 decrease in personnel relocation and office related costs during the first six months of 2013 compared to the first six months of 2012, and a $98,000 reversal of bad debt expense associated with the related party receivable during the second quarter of 2013.

19

Tengasco, Inc. and Subsidiaries

During the first six months of 2012, the Company recorded a $105,000 non-cash unrealized loss on derivatives related to the change in fair value of an oil derivative contract.  No unrealized gains or losses were recorded during the first six months of 2013 as the oil derivative contract expired on December 31, 2012.

Interest expense decreased $154,000 from $394,000 during the first six months of 2012 to $240,000 during the first six months of 2013.  This decrease in interest expense was primarily due to a $5.1 million decrease in average bank borrowings from $13.4 million during the first six months of 2012 to $8.3 million during the first six months of 2013.  This decrease in average bank borrowings related to a significant decrease in capital spending since the second quarter of 2012.

Liquidity and Capital Resources

At June 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 June 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 June 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 pipeline 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.

The total borrowing by the Company under the credit facility at June 30, 2013 and December 31, 2012 was $6.5 million and $10.1 million, respectively.  This $3.6 million reduction resulted from use of cash flow from operations to pay down the credit facility.  The next borrowing base review will take place in August 2013.

Although the Company has not been required as of the date of this Report to make any payment of principal on the credit facility, the Company can make no assurance that in view of the conditions in the national and world economies, including the realistic possibility of low commodity prices being received for the Company’s oil and gas production for extended periods, that F&M Bank may in the future make a redetermination of the Company’s borrowing base to a point below the level of current borrowings.  In such event, F&M Bank may require installment or other payments in such amount in order to reduce the principal of the Company’s outstanding borrowing to a level not in excess of the borrowing base as it may be redetermined.  The Company can make no assurance that it can continue normal operations indefinitely or for any specific period of time in the event of extended periods of low commodity prices, or upon the occurrence of any significant downturn or losses in operations.  In such event, the Company may be required to reduce costs of operations by various means, including not undertaking certain maintenance or reworking operations that may be necessary to keep some of the Company’s properties in production or to seek additional working capital by additional means such as issuance of equity including preferred stock or such other means as may be considered and authorized by the Company’s Board of Directors from time to time.

20

Tengasco, Inc. and Subsidiaries

Net cash provided by operating activities increased $309,000 from $3.9 million in the first six months of 2012 to $4.2 million during the first six months of 2013.  Cash flow used in working capital was $820,000 during the first six months of 2012 compared to $167,000 used in working capital during the first six months of 2013. The $653,000 change in cash flow used in working capital from 2012 to 2013 was primarily due to a $700,000 increase in materials and equipment inventory during the first six months of 2012 compared to no change in materials and equipment inventory during the first six months of 2013.  The $309,000 increase in cash provided by operating activities was primarily due to the $700,000 increase in materials and equipment inventory during 2012 partially offset by a $322,000 decrease in 2013 net income from continuing operations compared to 2102 levels.  Net cash used in investing activities decreased $5.9 million from $6.25 million during the first six months of 2012 to $322,000 million during the first six months of 2013.  Drilling, polymer, leasehold, and seismic costs decreased $6.4 million from $6.8 million during the first six months of 2012 to $385,000 during the first six months of 2013.  In addition, Methane Plant capital spending decreased $459,000 from 2012 levels as no spending occurred during the first six months of 2013.  These capital spending reductions were partially offset by the $1.0 million Section 1603 payment received by the Company in the second quarter of 2012.  Cash flow used in financing activities during the first six months of 2013 was $3.8 million primarily from using cash flows from operations to pay down bank borrowings compared to $2.3 million of cash flow provided by financial activities during the first six months of 2012 primarily from additional bank borrowings used to fund the Company’s capital spending programs during the first six months of 2012.

Critical Accounting Policies

During the quarter ended June 30, 2013, there were no changes to the critical accounting policies included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

ITEM 3.     QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

The borrowing base under the Company’s revolving credit facility will be determined from time to time by the lender, consistent with its customary natural gas and crude oil lending practices.

21

Tengasco, Inc. and Subsidiaries

Reductions in estimates of the Company’s natural gas and crude oil reserves could result in a reduction in the Company’s borrowing base, which would reduce the amount of financial resources available under the Company’s revolving credit facility to meet its capital requirements. Such a reduction could be the result of lower commodity prices or production, inability to drill or unfavorable drilling results, changes in natural gas and crude oil reserve engineering, the lender’s inability to agree to an adequate borrowing base or adverse changes in the lenders’ practices regarding estimation of reserves.  If cash flow from operations or the Company’s borrowing base decreases for any reason, the Company’s ability to undertake exploration and development activities could be adversely affected.

As a result, the Company’s ability to replace production may be limited. In addition, if the borrowing base is reduced, the Company may be required to pay down its borrowings under the revolving credit facility so that outstanding borrowings do not exceed the reduced borrowing base. This requirement could further reduce the cash available to the Company for capital spending and, if the Company did not have sufficient capital to reduce its borrowing level, could cause the Company to default under its revolving credit facility.

As of June 30, 2013, the Company’s borrowing base was set at $20.5 million of which $6.5 million had been drawn down by the Company.  The Company’s next periodic borrowing base review will occur in August 2013.

Commodity Risk

The Company's major market risk exposure is in the pricing applicable to its oil and gas production.  Realized pricing is primarily driven by the prevailing worldwide price for crude oil and spot prices applicable to natural gas production.  Historically, prices received for oil and gas production have been volatile and unpredictable and price volatility is expected to continue.  Although not as volatile as in previous years, monthly Kansas oil prices received during the first six months of 2013 ranged from a low of $84.91 per barrel to a high of $88.68 per barrel.  Gas prices realized during the same period ranged from a low of $2.46 per Mcf to a high of $4.29 per Mcf.

In order to help mitigate commodity price risk, the Company has entered into a long term fixed price contract for MMC gas sales.  On August 27, 2009, the Company entered into a five-year fixed price gas sales contract with Atmos Energy Marketing, LLC, (“AEM”) in Houston, Texas, a nonregulated unit of Atmos Energy Corporation (NYSE: ATO) for the sale of the methane component of landfill gas produced by MMC at the Carter Valley Landfill.  The agreement provides for the sale of up to 600 MMBtu per day.  The contract is effective beginning with September 2009 gas production and ends July 31, 2014.  The agreed contract price of over $6 per MMBtu was a premium to the then current five-year strip price for natural gas on the NYMEX futures market.

As of June 30, 2013, the Company has no open positions related to derivative agreements.

22

Tengasco, Inc. and Subsidiaries

Interest Rate Risk

At June 30, 2013, the Company had debt outstanding of $6.6 million including, as of that date, $6.5 million owed on its credit facility with F&M Bank. The interest rate on the credit facility was variable at a rate equal to the greater of prime plus 0.25% or 5.25% per annum.  The Company’s remaining debt of $157,000 has fixed interest rates ranging from 5.5% to 8.25%.

The annual impact on interest expense and the Company’s cash flows of a 10% increase in the interest rate on the credit facility would be approximately $34,000 assuming borrowed amounts under the credit facility remained at the same amount owed as of June 30, 2013.  The Company did not have any open derivative contracts relating to interest rates at June 30, 2013 or December 31, 2012.

Forward-Looking Statements and Risk

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

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

ITEM 4.     CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The Company’s Chief Executive Officer and Chief Financial Officer, and other members of management have evaluated the effectiveness of the Company’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Based on such evaluation, the Company’s Chief Executive Officer and Chief Financial Officer have concluded that the Company’s disclosure controls and procedures, as of the end of the period covered by this Report, were adequate and effective to provide reasonable assurance that information required to be disclosed by the Company in reports that it files or submits under the Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms. As a result of the resignation of Jeffrey R. Bailey as the Company’s Chief Executive Officer on June 28, 2013 and the appointment by the Board of Michael J. Rugen, the Company’s Chief Financial Officer to also serve as Chief Executive Officer on an interim basis, Mr. Rugen is acting in both capacities and has executed the accompanying certifications as to both offices.  The effectiveness of a system of disclosure controls and procedures is subject to various inherent limitations, including cost limitations, judgments used in decision making, assumptions about the likelihood of future events, the soundness of internal controls, and fraud. Due to such inherent limitations, there can be no assurance that any system of disclosure controls and procedures will be successful in preventing all errors or fraud, or in making all material information known in a timely manner to the appropriate levels of management.

23

Tengasco, Inc. and Subsidiaries

Changes in Internal Controls

During the period covered by this Report, certain internal control procedures previously performed by the former Chief Executive Officer are now being performed by the Company’s General Counsel and Audit Committee.  There have been no other changes to the Company’s system of internal controls over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company’s system of controls over financial reporting.  As part of a continuing effort to improve the Company’s business processes, management is evaluating its internal controls and may update certain controls to accommodate any modifications to its business processes or accounting procedures.

PART II    OTHER INFORMATION

ITEM 1.     LEGAL PROCEEDINGS

None.

ITEM 1A.  RISK FACTORS

Refer to Item 1A Risk Factors in the Company’s Report on Form 10-K for the year ended December 31, 2012 filed on March 29, 2013 which is incorporated by this reference.

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

None.

ITEM 3.     DEFAULTS UPON SENIOR SECURITIES

None.

24

Tengasco, Inc. and Subsidiaries

ITEM 4.     MINE SAFETY DISCLOSURES

Not Applicable

ITEM 5.     OTHER INFORMATION

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 was contingent upon certain regulatory and easement holder approvals and customary due diligence.  As of the date of this report, the required regulatory and easement holder approvals have been obtained and customary due diligence has been completed.    According to the terms of the March 1, 2013 agreement, the purchaser would forfeit a $100,000 down payment previously paid to the Company if purchaser now elects to not proceed with the purchase of these assets.  However, the purchaser has not indicated any unwillingness to close and the Company anticipates closing this transaction by August 16, 2013.

The Board of Directors has fixed the date and time of the Annual Meeting of the Company’s holders of common stock as Thursday, October 17, 2013 at 1:00 P.M.  at the Homewood Suites by Hilton in Knoxville, Tennessee.  The Board of Directors has also fixed the close of business on August 20, 2013 as the record date for the determination of the stockholders entitled to receive notice and to vote at the Annual Meeting or any adjournments thereof.  It is anticipated that the Notice of Annual Meeting and Proxy Statement will be available to the Company’s stockholders on or before September 6, 2013. The list of stockholders entitled to vote at the Annual Meeting will be available for examination by any stockholder at the Company's offices at 11121 Kingston Pike, Suite E, Knoxville TN 37934 ten days before October 17, 2013.

ITEM 6.     EXHIBITS

The following exhibits are filed with this report:

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

25

Tengasco, Inc. and Subsidiaries

  SIGNATURES

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

Dated:  August 13, 2013

TENGASCO, INC.

By:  s/Michael J. Rugen

Michael J. Rugen

Chief Executive Officer and Chief Financial Officer

26

EX-31.1

Tengasco, Inc. and Subsidiaries

Exhibit 31.1   CERTIFICATION

I, Michael J. Rugen, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Tengasco, Inc. for the quarter June 30, 2013.

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

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

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

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

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

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

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

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

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

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

Dated: August 13, 2013

By:  s/Michael J. Rugen

Michael J. Rugen

Chief Executive Officer and Chief Financial Officer

EX-32.1

Tengasco, Inc. and Subsidiaries

Exhibit 32.1

CERTIFICATION

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

 I have reviewed the Quarterly Report on Form 10-Q for the quarter ended June 30, 2013.

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

      Dated:  August 13, 2013

By:  s/Michael J. Rugen

Michael J. Rugen

Chief Executive Officer and Chief Financial Officer

XML

Fair Value Measurements

6 Months Ended

Jun. 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 June 30, 2013 and December 31, 2012.

XML

Condensed Consolidated Statements Of Operations (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Condensed Consolidated Statements Of Operations [Abstract]
Revenues	$ 3,871	$ 5,222	$ 8,185	$ 10,184
Cost and expenses
Production costs and taxes	1,191	1,934	2,561	3,602
Depreciation, depletion, and amortization	742	860	1,537	1,569
General and administrative	466	600	979	1,359
Total cost and expenses	2,399	3,394	5,077	6,530
Net income from operations	1,472	1,828	3,108	3,654
Other income (expense)
Interest expense	(109)	(206)	(240)	(394)
Gain (loss) on derivatives		15		(105)
Gain on sale of assets	63	33	63	67
Total other income (expenses)	(46)	(158)	(177)	(432)
Income from continuing operations before income tax	1,426	1,670	2,931	3,222
Income tax expense	(621)	(518)	(1,147)	(1,116)
Income from continuing operations	805	1,152	1,784	2,106
(Loss) from discontinued operations, net of income tax benefit	(33)	(65)	(74)	(146)
Net income	$ 772	$ 1,087	$ 1,710	$ 1,960
Net income (loss) per share - Basic and Diluted
Net income from continuing operations	$ 0.01	$ 0.02	$ 0.03	$ 0.03
Net (loss) from discontinued operations	$ 0.00	$ 0.00	$ 0.00	$ 0.00
Shares used in computing earnings per share
Basic	60,842,413	60,763,237	60,842,413	60,750,325
Diluted	60,928,397	61,214,257	60,991,055	61,236,066

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Recent Accounting Pronouncements

6 Months Ended

Jun. 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.

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Asset Retirement Obligation (Tables)

6 Months Ended

Jun. 30, 2013

Asset Retirement Obligation [Abstract]

Asset Retirement Obligation Transactions

Balance December 31, 2012	$	2,099
Accretion expense		70
Liabilities incurred		3
Liabilities settled		(12	)
Balance June 30, 2013	$	2,160

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Derivatives

6 Months Ended

Jun. 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 six months ended June 30, 2012, the Company recorded a gain on derivatives of $15,000 and a loss on derivatives of $105,000, respectively. As of June 30, 2013 and December 31, 2012, the Company did not have any open forward positions.

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

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Description Of Business And Significant Accounting Policies (Narrative) (Details) (USD $)	6 Months Ended
	Jun. 30, 2013 mi	Dec. 31, 2012
Length of pipeline, miles	65
Restricted cash	$ 507,000	$ 507,000
Unevaluated properties	457,000	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	$ 386,000

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Assets Held For Sale And Discontinued Operations (Tables)

6 Months Ended

Jun. 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 six months ended
		June 30, 2013			June 30, 2012			June 30, 2013		June 30, 2012
Revenues	$	8		$	8		$	17		$	12
Production costs and taxes		(67	)		(72	)		(139	)		(166	)
Depreciation, depletion, and amortization		-			(44	)		-			(88	)
Deferred income tax benefit		26			43			48			96
(Loss) from discontinued operations, net	$	(33	)	$	(65	)	$	(74	)	$	(146	)
of income tax benefit

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Asset Retirement Obligation (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Asset Retirement Obligation [Abstract]
Balance	$ 2,099
Accretion expense	70	67
Liabilities incurred	3
Liabilities settled	(12)	(41)
Balance	$ 2,160

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Derivatives (Narrative) (Details) (USD $)	3 Months Ended	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2012
Derivatives [Abstract]
Unrealized gain (loss) on derivatives	$ 15,000	$ (105,000)

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Earnings Per Share (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Earnings Per Share [Abstract]
Net income from continuing operations	$ 805	$ 1,152	$ 1,784	$ 2,106
Net loss from discontinued operations	$ (33)	$ (65)	$ (74)	$ (146)
Weighted average shares - basic	60,842,413	60,763,237	60,842,413	60,750,325
Dilution effect of share-based compensation, treasury method	85,984	451,020	148,642	485,741
Weighted average shares - dilutive	60,928,397	61,214,257	60,991,055	61,236,066
Continuing Operations	$ 0.01	$ 0.02	$ 0.03	$ 0.03
Discontinued Operations	$ 0.00	$ 0.00	$ 0.00	$ 0.00

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2013

Long-Term Debt [Abstract]

Schedule Of Long-Term Debt To Unrelated Entities

		June 30, 2013			December 31, 2012
Note payable to a financial institution, with interest only
payment until maturity.	$	6,482		$	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		6,639			10,346
Less current maturities		(84	)		(100	)
Long-term debt, less current maturities	$	6,555		$	10,246

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Condensed Consolidated Statements Of Cash Flow (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Operating activities
Net income from continuing operations	$ 1,784	$ 2,106
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, and amortization	1,537	1,569
Amortization of loan fees-interest expense	16	29
Accretion on asset retirement obligation	70	67
Gain on sale of assets	(63)	(67)
Compensation and services paid in stock options and stock	18	27
Deferred tax expense	1,147	1,049
Loss on derivatives		105
Changes in assets and liabilities:
Accounts receivable	179	(276)
Inventory and other assets	14	(529)
Accounts payable	(242)	144
Accrued and other current liabilities	(106)	(118)
Settlement on asset retirement obligation	(12)	(41)
Net cash provided by operating activities - continuing operations	4,342	4,065
Net cash (used in) operating activities - discontinued operations	(122)	(154)
Net cash provided by operating activities	4,220	3,911
Investing activities
Net additions to oil and gas properties	(385)	(6,792)
Net additions to methane project		(459)
Section 1603 payment- methane facilities		1,000
Net additions to other property and equipment		(15)
Proceeds from sale of other property and equipment	63	16
Net cash used in investing activities - continuing operations	(322)	(6,250)
Financing activities
Proceeds from exercise of options		28
Payment in lieu of exercise of options	(60)
Repayments of borrowings	(8,029)	(9,655)
Proceeds from borrowings	4,200	11,834
Loan fees	(10)	(30)
Net cash provided by (used in) financing activities - continuing operations	(3,899)	2,177
Net cash provided by financing activities - discontinued operations	122	154
Net cash provided by (used in) financing activities	(3,777)	2,331
Net change in cash and cash equivalents - continuing operations	121	(8)
Cash and cash equivalents, beginning of period	31	68
Cash and cash equivalents, end of period	152	60
Supplemental cash flow information:
Cash interest payments	224	365
Supplemental non-cash investing and financing activities:
Financed company vehicles		127
Asset retirement obligations incurred	3	92
Accrued capital expenditures included in accounts payable	$ 62	$ 480

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Income Taxes

6 Months Ended

Jun. 30, 2013

Income Taxes [Abstract]

Income Taxes

(2) Income Taxes

     The total deferred tax asset was $8.3 million and $9.4 million at June 30, 2013 and December 31, 2012, respectively. Although management considers our valuation allowance and loss contingency as of June 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.

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Related Party Transactions

6 Months Ended

Jun. 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 June 30, 2013, net revenues received by Hoactzin from the Ten Well Program totaled $4.874 million which leaves a balance of approximately $326,000 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 significant 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 June 30, 2013 and December 31, 2012 in the amounts of $371,000 and $325,000, respectively. The Company has recorded the Hoactzin-related payables and the corresponding receivable from Hoactzin as of June 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 of $159,000 and $257,000 for June 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.

     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)

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Earnings Per Share

6 Months Ended

Jun. 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 Six Months Ended
		June 30, 2013		June 30, 2012				June 30, 2013		June 30, 2012
Income (numerator):
Net income from continuing operations	$	805		$	1,152		$	1,784		$	2,106
Net loss from discontinued operations	$	(33	)	$	(65	)	$	(74	)	$	(146	)
Weighted average shares (denominator):
Weighted average shares – basic		60,842,413			60,763,237			60,842,413		60,750,325
Dilution effect of share-based		85,984			451,020			148,642		485,741
compensation, treasury method
Weighted average shares – dilutive		60,928,397			61,214,257			60,991,055		61,236,066
Earnings (loss) per share – Basic and Dilutive:
Continuing Operations	$	0.01		$	0.02		$	0.03		$	0.03
Discontinued Operations	$	(0.00	)		(0.00	)	$	(0.00	)	$	(0.00	)

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Commitments And Contingencies (Details) (USD $)	Jun. 30, 2013
Commitments And Contingencies [Abstract]
Minimum potential loss	$ 0
Maximum potential loss	$ 386,000

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Description Of Business And Significant Accounting Policies (Inventory) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Description Of Business And Significant Accounting Policies [Abstract]
Oil - carried at cost	$ 627	$ 650
Equipment and materials - carried at cost	752	752
Total inventory	$ 1,379	$ 1,402

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Related Party Transactions (Details) (USD $)	0 Months Ended	3 Months Ended		6 Months Ended			69 Months Ended				0 Months Ended
	Dec. 18, 2007	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012	Jun. 30, 2013 Hoactzin Partners, L.P. [Member]	Dec. 18, 2007 Hoactzin Partners, L.P. [Member]	Mar. 31, 2008 Ten Well Program [Member]	Sep. 17, 2007 Ten Well Program [Member] item	Sep. 17, 2007 Ten Well Program [Member] At Or Above Revenue Threshold [Member]	Sep. 17, 2007 Ten Well Program [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		326,000		326,000					5,200,000
Revenues		3,871,000	5,222,000	8,185,000	10,184,000		4,874,000
Percent of executive salary	50.00%
Bond, face value	9,600,000
Cash collateral								6,600,000
Related parties accounts payable		371,000		371,000		325,000
Related party allowance for doubtful accounts receivable		159,000		159,000		257,000
Funds advanced							0
Borrowing capability used							$ 0

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Methane Project (Details) (Methane Project [Member], USD $)	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Methane Project [Member]
Methane Project [Line Items]
Date methane facilities were placed into service	Apr. 01, 2009
Landfill closure date	Dec. 31, 2041
Methane facilities estimated useful life	33 years
Depreciation expense	$ 59,000	$ 54,000

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Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 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	$ 0.001	$ 0.001
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

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Long-Term Debt

6 Months Ended

Jun. 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):

		June 30, 2013			December 31, 2012
Note payable to a financial institution, with interest only
payment until maturity.	$	6,482		$	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		6,639			10,346
Less current maturities		(84	)		(100	)
Long-term debt, less current maturities	$	6,555		$	10,246

     At June 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 June 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 June 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 pipeline 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.

     The total borrowing by the Company under the credit facility at June 30, 2013 and December 31, 2012 was $6.5 million and $10.1 million, respectively. The next borrowing base review will take place in August 2013.

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Condensed Consolidated Statements Of Stockholders' Equity (USD $) In Thousands, except Share data	Common Stock [Member]	Paid In Capital [Member]	Accumulated Deficit [Member]	Total
Balance, value at Dec. 31, 2012	$ 61	$ 55,699	$ (25,626)	$ 30,134
Balance, shares at Dec. 31, 2012	60,842,413
Net income			1,710	1,710
Option and compensation expense		(42)		(42)
Balance, value at Jun. 30, 2013	$ 61	$ 55,657	$ (23,916)	$ 31,802
Balance, shares at Jun. 30, 2013	60,842,413

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Condensed Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Assets
Cash and cash equivalents	$ 152	$ 31
Accounts receivable	1,285	1,608
Accounts receivable - related party, less allowance for doubtful accounts of $159 and $257	212	68
Inventory	1,379	1,402
Other current assets	203	194
Total current assets	3,231	3,303
Restricted cash	507	507
Loan fees, net	51	57
Oil and gas properties, net (full cost accounting method)	23,779	24,700
Methane project, net	4,386	4,445
Other property and equipment, net	214	321
Assets held for sale	1,400	1,400
Deferred tax asset-noncurrent	8,335	9,434
Total assets	41,903	44,167
Liabilities and Stockholders' Equity
Accounts payable - trade	360	648
Accounts payable - other	371	325
Accrued and other current liabilities	571	615
Current maturities of long-term debt	84	100
Total current liabilities	1,386	1,688
Asset retirement obligation	2,160	2,099
Long term debt, less current maturities	6,555	10,246
Total liabilities	10,101	14,033
Commitments and contingencies (Note 13)
Stockholders' equity
Common stock, $.001 par value, authorized 100,000,000 shares, 60,842,413 and 60,842,413 shares issued and outstanding	61	61
Additional paid-in capital	55,657	55,699
Accumulated deficit	(23,916)	(25,626)
Total stockholders' equity	31,802	30,134
Total liabilities and stockholders' equity	$ 41,903	$ 44,167

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Description Of Business And Significant Accounting Policies (Accounts Receivable) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Accounts, Notes, Loans and Financing Receivable [Line Items]
accounts receivable	$ 1,285	$ 1,608
Revenue [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
accounts receivable	1,253	1,517
Joint Interest [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
accounts receivable	32	65
Other [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
accounts receivable		$ 26

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Oil And Gas Properties (Tables)

6 Months Ended

Jun. 30, 2013

Oil And Gas Properties [Abstract]

Schedule Of Oil And Gas Properties

		June 30, 2013			December 31, 2012
Oil and gas properties, at cost	$	43,800		$	43,351
Unevaluated properties		457			457
Accumulated depletion		(20,478	)		(19,108	)
Oil and gas properties, net	$	23,779		$	24,700

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Assets Held For Sale And Discontinued Operations (Schedule Of The Amounts In Net Loss From Discontinued Operations) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Assets Held For Sale And Discontinued Operations [Abstract]
Revenues	$ 8	$ 8	$ 17	$ 12
Production costs and taxes	(67)	(72)	(139)	(166)
Depreciation, depletion, and amortization		(44)		(88)
Deferred income tax benefit	26	43	48	96
(Loss) from discontinued operations, net of income tax benefit	$ (33)	$ (65)	$ (74)	$ (146)

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Long-Term Debt (Narrative) (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2013 F&M Bank [Member]	Dec. 31, 2012 F&M Bank [Member]	Jun. 30, 2013 Maximum [Member]	Mar. 04, 2013 Maximum [Member] F&M Bank [Member]	Jun. 30, 2013 Minimum [Member]	Mar. 04, 2013 Minimum [Member] F&M Bank [Member]
Line of Credit Facility [Line Items]
Credit facility maximum borrowing capacity		$ 40
Credit facility current borrowing capacity	20.5
Interest rate per annum		5.25%		8.25%		5.50%	5.25%
Rate above prime					0.25%
Loans and letters of credit amount outstanding		$ 6.5	$ 10.1

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Long-Term Debt (Schedule Of Long-Term Debt To Unrelated Entities) (Details) (USD $)	6 Months Ended
	Jun. 30, 2013	Dec. 31, 2012
Line of Credit Facility [Line Items]
Note payable to financial institution, with interest only payment until maturity	$ 6,482,000	$ 10,138,000
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	157,000	208,000
Total long-term debt	6,639,000	10,346,000
Less current maturities	(84,000)	(100,000)
Long-term debt, less current maturities	6,555,000	10,246,000
Periodic payments including interest, insurance and maintenance	$ 20,000
Maximum [Member]
Line of Credit Facility [Line Items]
Interest rate per annum	8.25%
Minimum [Member]
Line of Credit Facility [Line Items]
Interest rate per annum	5.50%

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Asset Retirement Obligation

6 Months Ended

Jun. 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 six months ended June 30, 2013 (in thousands):

Balance December 31, 2012	$	2,099
Accretion expense		70
Liabilities incurred		3
Liabilities settled		(12	)
Balance June 30, 2013	$	2,160

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Income Taxes (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Deferred tax asset	$ 8.3	$ 9.4

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Assets Held For Sale And Discontinued Operations

6 Months Ended

Jun. 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 June 30, 2013 and December 31, 2102. 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 six months ended June 30, 2013 and 2012: (in thousands)

		For the three months ended						For the six months ended
		June 30, 2013			June 30, 2012			June 30, 2013		June 30, 2012
Revenues	$	8		$	8		$	17		$	12
Production costs and taxes		(67	)		(72	)		(139	)		(166	)
Depreciation, depletion, and amortization		-			(44	)		-			(88	)
Deferred income tax benefit		26			43			48			96
(Loss) from discontinued operations, net	$	(33	)	$	(65	)	$	(74	)	$	(146	)
of income tax benefit

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Oil And Gas Properties

6 Months Ended

Jun. 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):

		June 30, 2013			December 31, 2012
Oil and gas properties, at cost	$	43,800		$	43,351
Unevaluated properties		457			457
Accumulated depletion		(20,478	)		(19,108	)
Oil and gas properties, net	$	23,779		$	24,700

     The Company recorded depletion expense of $1,370,000 and $1,386,000 for the six months ended June 30, 2013 and 2012, respectively.

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Description Of Business And Significant Accounting Policies

6 Months Ended

Jun. 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 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 is the Swan Creek Field in Tennessee.

     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 has entered into an agreement to sell the pipeline asset, it has been classified as "Assets held for sale" in the Consolidated Balance Sheets as of June 30, 2013 and 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 six months ended June 30, 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 six months ended June 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 June 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 June 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash".

     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 June 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 June 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 June 30, 2013 and December 31, 2012. The following table sets forth information concerning the Company's inventory (in thousands):

		June 30, 2013		December 31, 2012
Oil – carried at cost	$	627	$	650
Equipment and materials – carried at cost		752		752
Total inventory	$	1,379	$	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 $457,000 in unevaluated properties as of June 30, 2013 and December 31, 2012. 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 June 30, 2013 or December 31, 2012. At June 30, 2013 and December 31, 2012, accounts receivable consisted of the following (in thousands):

		June 30, 2013		December 31, 2012
Revenue	$	1,253	$	1,517
Joint interest		32		65
Other		-		26
Total accounts receivable	$	1,285	$	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 is contingent upon customary due diligence as well as certain regulatory and easement holder approvals. The Company has elected to classify the Pipeline assets as "Assets held for sale" in the Consolidated Balance Sheets as of June 30, 2013 and 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 six months ended June 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 represent 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.

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Oil And Gas Properties (Details) (USD $)	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Oil And Gas Properties [Abstract]
Oil and gas properties, at cost	$ 43,800,000		$ 43,351,000
Unevaluated properties	457,000		457,000
Accumulated depletion	(20,478,000)		(19,108,000)
Oil and gas properties, net	23,779,000		24,700,000
Depletion expense	$ 1,370,000	$ 1,386,000

XML

Commitments And Contingencies

6 Months Ended

Jun. 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 be administratively denied and the order to the Company as operator to pay the $386,000 penalty would be final. While the Company believes it will ultimately prevail in the appeal process, it is reasonably possible to expect that the Company may be required to pay a portion of this penalty. The Company estimates the range of this possible payment to be between zero and $386,000. During the quarter ended June 30, 2013 there have been no new developments in this appeal process.

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Methane Project

6 Months Ended

Jun. 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 $59,000 and $54,000 for the six months ended June 30, 2013 and 2012, respectively.

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Earnings Per Share (Tables)

6 Months Ended

Jun. 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 Six Months Ended
		June 30, 2013		June 30, 2012				June 30, 2013		June 30, 2012
Income (numerator):
Net income from continuing operations	$	805		$	1,152		$	1,784		$	2,106
Net loss from discontinued operations	$	(33	)	$	(65	)	$	(74	)	$	(146	)
Weighted average shares (denominator):
Weighted average shares – basic		60,842,413			60,763,237			60,842,413		60,750,325
Dilution effect of share-based		85,984			451,020			148,642		485,741
compensation, treasury method
Weighted average shares – dilutive		60,928,397			61,214,257			60,991,055		61,236,066
Earnings (loss) per share – Basic and Dilutive:
Continuing Operations	$	0.01		$	0.02		$	0.03		$	0.03
Discontinued Operations	$	(0.00	)		(0.00	)	$	(0.00	)	$	(0.00	)

XML

Description Of Business And Significant Accounting Policies (Policy)

6 Months Ended

Jun. 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 six months ended June 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 June 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 June 30, 2013 and December 31, 2012, this amount was recorded in the Consolidated Balance Sheets under "Restricted cash".

     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 June 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 June 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 June 30, 2013 and December 31, 2012. The following table sets forth information concerning the Company's inventory (in thousands):

		June 30, 2013		December 31, 2012
Oil – carried at cost	$	627	$	650
Equipment and materials – carried at cost		752		752
Total inventory	$	1,379	$	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 $457,000 in unevaluated properties as of June 30, 2013 and December 31, 2012. 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 June 30, 2013 or December 31, 2012. At June 30, 2013 and December 31, 2012, accounts receivable consisted of the following (in thousands):

		June 30, 2013		December 31, 2012
Revenue	$	1,253	$	1,517
Joint interest		32		65
Other		-		26
Total accounts receivable	$	1,285	$	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 is contingent upon customary due diligence as well as certain regulatory and easement holder approvals. The Company has elected to classify the Pipeline assets as "Assets held for sale" in the Consolidated Balance Sheets as of June 30, 2013 and 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 six months ended June 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 represent 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.

XML

Document And Entity Information	6 Months Ended
	Jun. 30, 2013	Aug. 05, 2013
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2013
Document Fiscal Year Focus	2013
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

XML

Description Of Business And Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2013

Description Of Business And Significant Accounting Policies [Abstract]

Inventory

		June 30, 2013		December 31, 2012
Oil – carried at cost	$	627	$	650
Equipment and materials – carried at cost		752		752
Total inventory	$	1,379	$	1,402

Accounts Receivable

		June 30, 2013		December 31, 2012
Revenue	$	1,253	$	1,517
Joint interest		32		65
Other		-		26
Total accounts receivable	$	1,285	$	1,608