Microsoft Word 11.0.5604;

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, 2005

Commission File No. 0-20975

Tengasco, Inc. and Subsidiaries
(Exact name of small business issuer as specified in its charter)

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

10215 Technology Drive N.W. Suite 301
Knoxville, TN 37932
(Address of principal executive offices)

(865-675-1554)
(Issuer’s telephone number, including area code)

Indicate by check mark whether the issuer (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__ Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act). Yes____ No X

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 48,677,828 common shares at June 30, 2005.

TENGASCO, INC. AND SUBSIDIARIES

TABLE OF CONTENTS


PART I.	FINANCIAL INFORMATION	PAGE
	ITEM 1. FINANCIAL STATEMENTS
	* Condensed Consolidated Balance Sheets as of June 30, 2005 and December 31, 2004	3-4
	* Condensed Consolidated Statements of Loss for the three and six months ended June 30, 2005 and 2004	5
	* Condensed Consolidated Statements of Stockholders' Equity for the six months ended June 30, 2005	6
	* Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2005 and 2004	7
	* Notes to Condensed Consolidated Financial Statements	8-14
	ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	14-19
	ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK	19-20
	ITEM 4. CONTROLS AND PROCEDURES	20
PART II.	OTHER INFORMATION
	ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	20
	ITEM 5. OTHER INFORMATION	21
	ITEM 6. EXHIBITS	22
	* SIGNATURES * CERTIFICATIONS	22 23-26

TENGASCO, INC AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

ASSETS

	June 30, 2005 (Unaudited)		December 31,2004

Assets
Current
Cash and cash equivalents	$	102,100	$	267,735
Accounts receivable		734,316		706,752
Participant receivables		18,819		73,016
Inventory		425,423		341,745
Other current assets		26,447		67,526

Total current assets		1,307,105		1,456,774
Oil and gas properties, net (on the basis
of full cost accounting)		10,096,837		12,826,903
Pipeline facilities, net		14,237,243		14,602,639
Other property and equipment, net		304,331		323,433

	$	25,945,516	$	29,209,749

See accompanying notes to condensed consolidated financial statements

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALNCE SHEETS

LIABILITIES AND STOCKHOLDERS EQUITY

	June 30, 2005 (Unaudited)			December 31,2004

Current liabilities
Current maturities of long-term debt	$	63,661		$	26,672
Accounts payable		430,111			319,820
Accrued interest payable		7,000			25,367
Other accrued liabilities		231,472			211,622
Notes payable to related parties (Note 5)		700,000			3,050,000
Drilling program (Note 6)		658,351			1,316,702
Current shares subject to mandatory redemption (Note 6)		3,429,552			3,260,312

Total current liabilities		5,520,147			8,210,495
Shares subject to mandatory redemption (Note 6)		1,464,068			1,395,301
Drilling program (Note 6)		438,901			438,901
Asset retirement obligations (Note 7)		596,283			708,677
Long term debt, less current maturities		127,321			106,688

Total liabilities		8,146,720			10,860,062

Stockholders' equity
Common stock, $.001 par value; authorized 100,000,000 shares;
48,677,828 and 48,927,828 shares issued and outstanding		48,678			48,928
Additional paid-in capital		51,686,533			51,686,283
Accumulated deficit		(33,936,415	)		(33,385,524	)

Total stockholders' equity		17,798,796			18,349,687

	$	25,945,516		$	29,209,749

See accompanying notes to condensed consolidated financial statements

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF LOSS

(Unaudited)

	For the Three Months Ended June 30,						For the Six Months Ended June 30,
	2005			2004			2005			2004
Revenues and other income
Oil and gas revenues	$	1,589,693		$	1,380,289		$	2,997,342		$	2,712,639
Pipeline transportation revenues		21,973			24,676			44,655			47,917
Interest income		431			1,695			1,118			2,446

Total revenues and other income		1,612,097			1,406,660			3,043,115			2,763,002
Cost and other deductions
Production costs and taxes		696,361			667,851			1,481,483			1,539,432
Depletion, depreciation and amortization		477,846			564,984			957,154			1,173,148
Interest expense		196,918			274,854			352,990			779,239
General and administrative cost		315,740			282,266			606,850			570,626
Public Relations		546			1,750			1,181			4,032
Professional fees		57,226			233,403			194,348			531,278

Total cost and other deductions		1,744,637			2,025,108			3,594,006			4,597,755
Gain from extinguishment of debt		0			336,820			0			336,820

Net loss attributable to commom shareholders	$	(132,540	)	$	(281,628	)	$	(550,891	)	$	(1,497,933	)

Net loss attributable to common shareholders
per share basic and diluted:
Operations	$	(0.00	)	$	(0.01	)	$	(0.01	)	$	(0.05	)

Total	$	(0.00	)	$	(0.01	)	$	(0.01	)	$	(0.05	)

Weighted average share outstanding		48,677,828			48,506,977			48,677,828			33,115,395

See accompanying notes to condensed consolidated financial statements

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS EQUITY

(Unaudited)

	Common Stock
	Shares			Amount			Additional Paid in Capital		Accumulated Deficit			Total
Balance at December 31,
2004		48,927,828		$	48,928		$	51,686,283	$	(33,385,524	)	$	18,349,687
Rescinded Shares		(250,000	)		(250	)		250		--			0
Net Loss		--			--			--		(550,891	)		(550,891	)

Balance June 30, 2005
(Unaudited)		48,677,828		$	48,678		$	51,686,533	$	(33,936,415	)	$	17,798,796

See accompanying notes to condensed consolidated financial statements

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Six Months Ended June 30, 2005 (unaudited)			For the Six Months Ended June 30, 2004 (unaudited)

Operating activities
Net loss	$	(550,891	)	$	(1,497,933	)
Adjustments to reconcile net loss to net cash
used in operating activities:
Depreciation, depletion and amortization		957,154			1,173,148
Accretion of redeemable shares		246,007			404,292
Accretion on Asset Retirement Obligation		39,007			36,684
Gain on extinguishment of Asset Retirement Obligation		(72,399	)		--
Loss on sale of vehicles/equipment		12,670			(7,500	)
Gain on sale of pipeline facilities		(17,605	)		--
Changes in assets and liabilities:
Accounts receivable		(27,564	)		(81,109	)
Participant receivables		54,197			(4,730	)
Other current assets		41,079			223,003
Inventory		(83,678	)		--
Other assets		--			(115,247	)
Investments		--			60,000
Accounts payable		110,291			(758,598	)
Accrued interest payable		(18,367	)		(209,322	)
Other accrued liabilities		19,850			129,304
Settlement on Asset Retirement Obligations		(18,004	)		--

Net cash provided by (used in) operating activities		691,747			(648,008	)

Investing activities
Increase/decrease to other property & equipment		(86,583	)		14,834
Net additions to oil and gas properties		(219,934	)		(720,397	)
Sale of Kansas gas field (See Note 8)		2,350,000			--
Increase/decrease in pipeline facilities		97,395			(8,511	)

Net cash provided by (used in) investing activities		2,140,878			(714,074	)

Financing activities
Proceeds from exercise of options		--			71,000
Proceeds from borrowings		106,721			2,725,000
Repayments of borrowings		(2,438,630	)		(10,088,254	)
Decrease in Drilling Program liability		(658,351	)		--
Dividends paid on redeemable liabilities		(8,000	)		(319,750	)
Loan fee amortization		--			107,955
Net proceeds from rights offering		--			8,858,827

Net cash (used in) provided by financing activities		(2,998,260	)		1,354,778

Net change in cash and cash equivalents		(165,635	)		(7,304	)
Cash and cash equivalents, beginning of period		267,735			312,666

Cash and cash equivalents, end of period	$	102,100		$	305,362

See accompanying notes to condensed consolidated financial statements

Tengasco, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

(Unaudited)

(1)Basis of Presentation

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with generally accepted accounting principles 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 generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments (consisting of only normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the six months ended June 30, 2005 are not necessarily indicative of the results that may be expected for the year ended December 31, 2005. Additionally, deferred income taxes and income tax expense is not reflected in the Company’s financial statements due to the fact that the Company has had recurring losses and deferred tax assets arising from net operating gross carry-forwards have been fully reserved. Certain prior year amounts have been reclassified to conform with current year presentation. For further information, refer to the Company’s consolidated financial statements and footnotes thereto for the year ended December 31, 2004 included in the Company’s annual report on Form 10-K.

(2) Going Concern

The accompanying consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate continuation of the Company as a going concern and assume realization of assets and the satisfaction of liabilities in the normal course of business. The Company has incurred continuous losses through operations and has an accumulated deficit of $33,936,415 and a working capital deficit of $4,213,042 as of June 30, 2005. During 2002, the Company was informed by its primary lender (Bank One) that the entire amount of its outstanding credit facility was immediately due and payable, as provided for in the Credit Agreement. The Company disputed its obligation to make this payment and has resolved the dispute by settlement of the debt in May 2004. As a result, the Company continues to pursue other long-term financing. The Company also has significant redemption amounts due to be satisfied in 2005 related to its Mandatorily Redeemable Series B Preferred Shares (see Note 6). These circumstances raise substantial doubt about the Company’s ability to continue as a going concern.

On March 4, 2005, the Company sold its gas producing properties in Rush County, Kansas for $2.4 million and used the net proceeds of the sale to pay down the $2.5 million debt to Dolphin Offshore Partners, L.P. (“Dolphin”), incurred by the Company to fund the settlement of the litigation with Bank One in May, 2004. This has the effect of reducing the payment of high interest on this note, and reducing the total secured debt owed by the Company to $700,000 as of the date of this Report, consisting of about $150,000 remaining principal of the $2.5 million note, and the principal of the $550,000 note used for the cash exchange to holders of the Company’s Series A 8% Cumulative Convertible Preferred Stock (“Series A Shares”). See Note 5 to the financial statements.

As a result of the payment of this secured and unsecured debt, and the exchange of most of its Series A Shares, management believes the Company is now better positioned to both establish a banking relationship with an institutional lender on acceptable terms to fund the Company’s activities. Although the Company is hopeful that as a result of the substantial reduction of its debt position that it will soon be able to establish such a relationship, there is no assurance it will be able to do so. Until the Company is able to establish such a relationship, it will be necessary to fund its operations, including capital expenditures for the acquisition, exploration and development of oil and gas reserves from other sources, such as equity investment, private loans or a joint venture with other companies, as to which there can be no assurances. In addition to its operational cash requirements, the Company also has a significant amount of loans and other obligations which will either become due or mature on August 20, 2005, including secured promissory notes due to Dolphin in the principal amount of $700,000 plus interest thereon, as well as the payment of the accrued distributions on the Company’s Series B 8% Cumulative Convertible Preferred Stock (“Series B Shares”) and the scheduled redemption of both the Series B shares and Series C 6% Cumulative Convertible Preferred Stock which become due on September 5, 2005 and April 30, 2007.

Management’s plans also include the continuation of its drilling efforts. The Company plans to drill wells in new locations it has identified in Kansas on its existing leases in response to drilling activity in the area establishing new areas of oil production. In September 2004, the Company drilled and completed the Lewis No. 3 well in Kansas using only funds from the proceeds of the Company’s ongoing operations. By using the Company’s own funds, it was not necessary to permit any third party to either participate in financing of drilling or to acquire any interest in the well. The Company receives all proceeds of production attributable to the working interest in the Lewis No. 3 well. The Company has also drilled three wells in the six months of 2005 as part of a drilling program in Kansas. See Part II, Item 5.

(3) Earnings per Share

In accordance with Statement of Financial Accounting Standards (SFAS) No. 128, “Earnings Per Share” (“SFAS 128”), basic and diluted loss per share are based on 48,677,828 and 48,506,977 weighted average shares outstanding for the quarters ended June 30, 2005 and June 30, 2004 respectively, and 48,677,828 and 33,115,395 for the six months ended June 30, 2005 and June 30, 2004 respectively.

For the three-month and six month periods ended June 30, 2005 and 2004, the Company had no vested, unexercised, in the money options. As the Company was in a net loss position, any potential common share equivalents would have been anti-dilutive.

The Company adopted the disclosure provision of the Statement of Financial Accounting Standards (SFAS or statement) No.148, “Accounting for Stock-Based Compensation-Transition and Disclosure” (“SFAS 148”), which amends SFAS No. 123 “Accounting for Stock-Based Compensation”, (“SFAS 123”). SFAS 148 provides alternative methods of transition for a voluntary change to the fair value based method of accounting for stock-based employee compensation, which was originally provided under SFAS 123. The Statement also improves the timeliness of disclosures by requiring the information be included in interim, as well as annual, financial statements. The adoption of

these disclosure provisions did not have an affect on the Company’s June 30, 2005 consolidated results of operations, financial position, or cash flows, as there were no options granted in 2004 or the first six months of 2005.

SFAS 123 encourages, but does not require, companies to record compensation cost for stock-based employee compensation plans at fair value. The Company has chosen to continue to account for stock-based compensation using the intrinsic value method prescribed in Accounting Principles Board Opinion No. 25, “Accounting for Stock Issued to Employees”, and related interpretations. Accordingly, compensation cost for stock options is measured as the excess, if any, of the quoted market price of the Company’s stock at the date of the grant over the amount an employee must pay to acquire the stock. The option price of all the Company’s stock options is equal to the market value of the stock at the grant date. As such, no compensation expense is recorded in the accompanying consolidated financial statements.

(4)Recent Accounting Pronouncements

In March 2004, The Emerging Issues Task Force (“EITF”) reached a consensus that mineral rights, as defined in EITF Issue No. 04-02, “Whether Mineral Rights are Tangible or Intangible Assets,”(“EITF 04-02”) are tangible assets and that they should be removed as examples of intangible assets in SFAS Nos. 141 and 142. The Financial Accounting Standards Board (“FASB”) has recently ratified this consensus and directed the FASB staff to amend SFAS Nos. 141 and 142 through the issuance of FASB Staff Positions FSP FAS 141-1 and FSP FAS 142-1. Historically the Company has included the cost of such mineral rights as tangible assets, which is consistent with the EITF’s consensus. As such, EITF 04-02 will not affect Tengasco’s consolidated condensed financial statements.

Staff Accounting Bulletin (“SAB”) No. 106, (“SAB 106”) regarding the application of SFAS No. 143, “Accounting for Asset Retirement Obligations” (“SFAS 143”), by oil and gas producing companies following the full cost accounting method was issued in September 2004. SAB 106 provided an interpretation of how a company, after adopting SFAS 143, should compute the full cost ceiling to avoid double-counting the expected future cash outflows associated with asset retirement costs. The provisions of this interpretation have been applied by the Company and adoption of this bulletin has no impact on the financial statements.

In December 2004, the FASB issued SFAS No. 123(R), “Share-Based Payment.” This statement revised SFAS No. 123, “Accounting for Stock-Based Compensation,” and superseded APB Opinion No. 25, “Accounting for Stock Issued to Employees,” and its related implementation guidance. SFAS No. 123(R) requires companies to recognize on the income statement the grant-date fair value of stock options and other equity-based compensation issued to employees. The SEC recently adopted a new rule that defers the effective date of SFAS No. 123(R) and allows companies to implement the provisions of the Statement at the beginning of their next fiscal year. As a result, the Company currently expects to adopt SFAS No. 123(R) as of January 1, 2006, using the modified prospective transition method. Under the modified prospective method, awards that are granted, modified or settled after January 1, 2006 will be measured in accordance with SFAS No. 123(R). Unvested equity-classified awards that were granted prior to January 1, 2006 will be accounted for in accordance with SFAS No. 123, except that the amounts will be recognized on the Company’s consolidated

statements of operations. The Company is currently evaluating the impact of SFAS No. 123(R) and expects that it will recognize additional compensation expense during first quarter 2006.

(5)Related Party Transactions

From December 2002 through December 9, 2003, Dolphin Offshore Partners, L.P. (“Dolphin”) acquired a total of an 85% undivided interest in the Company’s Tennessee and Kansas pipelines as collateral for a series of seven loans totaling $2,125,000. On December 24, 2003, Dolphin loaned the Company the sum of $1,000,000 which was used for working capital and to pay all interest and principal in full of convertible loans to the Company then being held by several persons. On February 2, 2004, Dolphin loaned the Company the sum of $225,000 which was used for making payment of principal and interest to the Company’s former lender, Bank One, for February, 2004. All of the aforementioned notes to Dolphin were repaid in full on March 30, 2004 from the proceeds received by the Company from its Rights Offering.

On May 18, 2004, Dolphin loaned the Company $2,500,000 bearing interest at 12% per annum with interest payable monthly beginning June 18, 2004 and principal payable on May 20, 2005, which loan is secured by a first lien on the Company’s Tennessee and Kansas producing properties and the Tennessee pipeline. The proceeds of the loan were used to fund in part the settlement with the Company’s former lender, Bank One. On December 30, 2004, Dolphin loaned the Company $550,000 bearing interest at 12% per annum with interest payable monthly and principal payable on May 20, 2005, which loan is secured by the first lien on the Company’s Tennessee and Kansas properties and the Tennessee pipeline. On March 4, 2005, Dolphin was paid $2,350,000 to reduce the principal of the promissory note dated May 18, 2004 in the original amount of $2,500,000, to $150,000 from the proceeds received from the sale of the Company’s Kansas gas fields (See Note 8). The balance owed on the two outstanding notes to Dolphin at March 31, 2005 was $700,000. These notes were replaced with a new note to Dolphin Offshore Partners for $700,000 payable on August 20, 2005, which is the balance due as of June 30, 2005.

(6) Cumulative Convertible Redeemable Preferred Stock and Drilling Program

The Company has issued three classes of convertible preferred stock (Series A, Series B and Series C). The Company is required to redeem one-twentieth of the maximum number of Series A Preferred Stock outstanding commencing on October 1, 2003 and at each quarterly date thereafter. The Company is required to redeem all outstanding Series B Preferred Stock on the fifth anniversary of the issuance of those shares which is September 2005. The Company is required to redeem any remaining Series C Preferred Stock together with any accrued and unpaid dividends in May 2007.

The Company adopted the provisions of SFAS No. 150 “Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Debt” (“SFAS 150”) on July 1, 2003. Under SFAS 150, mandatorily redeemable preferred stock shall be reclassified at fair value to a liability. The Company determined that each of the Series A, Series B and Series C preferred stock qualify as shares subject to mandatory redemption, and as such, were reclassified as liabilities upon adoption of SFAS 150. Accordingly, the difference between the carrying amount at the date of adoption and the fair value of the shares (discounted at rates between 12% and 12.5%) was recognized as a cumulative effect of a change in accounting principle of $365,675 effective July 1, 2003.

The difference between the carrying amount of shares subject to mandatory redemption and the face value amount of preferred stock is being accreted at rates between 12% and 12.5% into interest expense and the liability until conversion or redemption of the shares. Accretion associated with these shares subject to mandatory redemption was $224,722 in the first quarter of 2004 and $123,003 in the first quarter of 2005. The Company has dividends in arrears as of December 31, 2004 of $649,692 and $803,365 as of June 30, 2005.

In December, 2004, the Company completed an exchange offer to the thirteen holders of the Company’s Series A 8% Cumulative Convertible Preferred Stock in the amount of $2,867,900. Seven of the thirteen Series A holders elected the cash exchange option, and the face amount of $1,085,000 of Series A shares was exchanged on or before December 31, 2004 for cash payments of $723,370. A gain was recorded on this transaction in the amount of $458,310, the difference between the carrying amount and the cash settlement amount. The Company obtained funds for the exchange from cash on hand and the proceeds of a loan from Dolphin Offshore Partners, L.P. The loan from Dolphin was in the form of a note in principal amount of $550,000 bearing 12% interest per annum payable interest only until due on May 20, 2005 and secured by a lien on the Company’s Tennessee and Kansas assets. This note has been replaced and extended until August 20, 2005. Five of the thirteen Series A holders elected to participate in a drilling program in exchange for their Series A Shares, and on December 31, 2004 the amount of $1,582,900 of Series A Shares plus accrued dividends of $31,658 were exchanged for approximately 6.5 Units in an eight-well drilling program in Kansas (the “Drilling Program”). A liability was recorded for the Drilling Program in the amount of $1,755,603 and “Shares subject to mandatory redemption” was reduced by the same amount. The Drilling Program liability recorded represents the estimated fair value of the liability calculated upon adoption of SFAS 150 less accretion, from such date to the date of the exchange. The remaining 1.5 units in the Drilling Program continue to be owned by the Company.

Under the terms of the Drilling Program, the former Series A holders participating in the Drilling Program will receive all the cash flow from each of eight wells to be drilled in Kansas, until they have recovered 80% of the value of the Series A Shares exchanged. At that point, the Company will begin to receive 85% of the cash flow from these wells as a management fee, and the former Series A owners will continue to receive 15% of the cash flow for the productive life of the wells. In summary twelve of the 13 holders of Series A holders exchanged their Series A Shares. As a result, the Company has remaining only one Series A shareholder, holding Series A Shares, in the face amount of $200,000.

During the first six months of 2005 the Company completed three wells of the eight well Drilling Program. The Company reduced the Drilling Program liability by $658,351 and offset oil and gas properties by the corresponding amount. This represents 37.5% of the Drilling Program liability on December 31, 2004.

(7) Asset Retirement Obligation

In accordance with SFAS 143, the Company has recorded a liability and corresponding increase in long-lived assets for the present value of material obligations associated with the retirement of tangible long-lived assets. Over the passage of time, accretion of the liability is recognized as an operating expense and the capitalized cost is depleted over the estimated useful life of the related asset. The Company’s asset

retirement obligations relate primarily to the plugging, dismantling and removal of wells drilled to date.

Management determined that the following assumptions in estimating the initial recording of the Company’s Asset Retirement Obligation were appropriate using a credit-adjusted risk fee rate of 12%; an estimated useful life of wells ranging from 30-40 years and estimated plugging and abandonment cost ranging from $5,000 per well to $10,000 per well. Management continues to evaluate the appropriateness of these assumptions periodically.

For the first six months of 2005 and 2004, the Company recorded accretion expenses of $39,007 and $36,684 associated with this liability. These expenses are included in interest expense in the consolidated statements of loss.

On March 4, 2005 the Company sold the Kansas gas wells, therefore the asset and the corresponding liability relating to asset retirement obligations on these wells was extinguished. The asset account was credited for $60,998 and the liability was removed in the amount of $133,397, therefore creating a gain on the extinguishment of future obligations in the amount of $72,399, which was credited to interest expense.

(8) Sale of Gas Wells

On March 4, 2005 the Company sold the Kansas gas wells, oil and gas leases and the associated gathering system in place in Rush County, Kansas to Bear Petroleum, Inc. for $2.4 million. The Company’s gas producing properties in Kansas were physically separated from the oil properties, and were all located in Rush County, Kansas consisting of 51 producing wells and associated gathering system. All proceeds of this sale, being the sales price less a sales commission of $50,000, were immediately paid to Dolphin Offshore Partners, L.P. to reduce the principal of the promissory note to Dolphin in the amount of $2.5 million to $150,000. The Company recorded a credit to oil & gas properties of $2,350,000, the sale price net of commission.

(9) Rights Offering

The Rights Offering was a distribution to the holders of the Company’s common stock outstanding at the record date, February 27, 2004, at no charge, of nontransferable subscription rights at the rate of one right to purchase three shares of the Company’s common stock for each share of common stock owned at the subscription price of $0.75 in the aggregate, or $0.25 per each share purchased.

Each subscription right, in addition to the right to purchase three shares of common stock, carried with it an over-subscription privilege. The over-subscription privilege provided stockholders that exercise all of their basic subscription privileges with the opportunity to purchase those shares that were not purchased by other stockholders through the exercise of their basic subscription privileges, at the same subscription price per share. In no event could any subscriber purchase shares of the Company’s common stock in the offering that, when aggregated with all of the shares of the Company’s

common stock otherwise owned by the subscriber and his, her or its affiliates, would immediately following the closing represent more than 50% of the Company’s issued and outstanding shares.

As provided in the Rights Offering, 7,029,604 rights were exercised pursuant to the basic subscription privilege, resulting in the purchase of 21,088,812 shares at $0.25 per share for gross proceeds to the Company of $5,272,203 resulting from the basic subscription privilege. A total of 15,211,118 rights were exercised pursuant to the oversubscription privilege, resulting in additional gross proceeds to the Company of $3,802,797. Of the shares purchased pursuant to the Rights Offering 14,966,344 shares were purchased by Directors, Officers and owners of 10% of the Company’s outstanding common stock.

At the time the Rights Offering closed on March 18, 2004 all 36.3 million shares offered had been subscribed and, as a result, the Company raised approximately $9.1 million. The total number of shares subscribed actually exceeded the 36.3 million shares available for issuance under the offering. Consequently, all shares subscribed for under the basic privilege were issued and the number of shares issued under the over-subscription privilege was proportionately reduced to equal the number of remaining shares. The allocation and issuance of the oversubscribed shares was made by Mellon Investor Services, the Company’s subscription agent who also returned payments for those over-subscribed shares that were not available.

The net proceeds of the Rights Offering were used to pay non-bank indebtedness in the aggregate amount of approximately $6 million (including up to $3,850,000 in principal amount plus accrued interest owed by the Company to Dolphin) and to pay $1,157,000 as a portion of the Company’s settlement with Bank One. The balance of the net proceeds was used for working capital purposes, including the drilling of additional wells. Costs incurred in connection with the Rights Offering were $223,003.

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

Results of Operations and Financial Condition

Kansas

During the first six months of 2005, the Company produced and sold 59,042 barrels of oil and 20,729 Mcf of natural gas from its Kansas Properties comprised of 131 producing oil wells and 51 producing gas wells. The gas production was only for the month of January as the gas field was sold on March 4, 2005 with production retroactive to February of 2005. (See “Liquidity and Capital Resources”). The first six months production of 59,042 barrels of oil compares to 58,742 barrels produced in the first six months of 2004. In summary, the six months production reflected expected continued production levels from the Kansas Properties, which have been in production for many years. The Company has begun drilling in Kansas as discussed in Part II Item 5 of this report. The revenues from the Kansas properties were $2,331,567 in the first six months of 2005 compared to $1,958,859 in 2004. This increase was due to the higher prices for oil, but was partially offset by only one month of gas revenues.

Tennessee

During the first six months of 2005, the Company produced gas from 23 wells in the Swan Creek field, which it sold in Kingsport, Tennessee to Eastman Chemical Company .

Natural gas production from the Swan Creek field for the first six months of 2005 was an average of 483 Mcf per day during that period as compared to 635 Mcf per day in the first six months of 2004. The first six months production reflected expected natural decline in production from the existing Swan Creek gas wells which were first brought into production in mid-2001 upon completion of the Company’s pipeline. For the first six months of 2005 the Company produced 5,657 barrels of oil as compared to 7,211 in 2004. This natural decline is normal for any producing oil and gas well, and this decline as experienced on existing wells in Swan Creek was not unexpected.

Comparison of the Six Months Ended June 30, 2005 and 2004.

The Company recognized $2,997,342 in oil and gas revenues from its Kansas Properties and the Swan Creek Field during the first six months of 2005 compared to $2,712,639 in the first six months of 2004. The increase in revenues was due to an increase in oil prices in 2005. The revenue increase due to oil price increases were offset by Kansas gas production for only one month due to the sale of the gas field in Kansas. Kansas gas sales in 2005 were $72,471 (one month) as compared to $405,498 (six months) in 2004. Oil prices in the first six months of 2005 averaged $49.10 per barrel as compared to $34.72 per barrel in the first six months of 2004.

The Company realized a net loss attributable to common shareholders of $550,891 ($0.01) per share of common stock, during the first six months of 2005 compared to a net loss in the first six months of 2004 to common shareholders of $1,497,933 ($0.05) per share of common stock.

Production costs and taxes in the first six months of 2005 of $1,481,483 decreased from $1,539,432 in the first six months of 2004. The difference is due to management’s cost-controlling efforts and the sale of the Kansas gas field.

Depreciation, depletion, and amortization expense for the first six months of 2005 was $957,154 compared to $1,173,148 in the first six months of 2004. This is due to a reduction in depletion and depreciation taken due to the sale of the Kansas gas field and equipment becoming fully depreciated in late 2004.

During the first six months of 2005, general and administrative costs remained at 2004 levels.

Professional fees, in the first six months of 2005 were $194,348 compared to $531,278 in the same period in 2004. These fees have substantially decreased as a result of the settlement of the Bank One and Paul Miller lawsuits in 2004.

Interest expense for the first six months of 2005 decreased from the first six months of 2004 to $352,990 from $779,239. The substantial decrease is the result of the payoff of the Bank One loan and the Dolphin notes and the conversion of shares subject to mandatory redemption into a drilling program and cash payoff in 2004. Additionally

the Company recorded a gain of $72,399 in the first quarter of 2005 relating to the extinguishment of asset retirement obligation on the wells that were sold in Kansas that was offset to interest expense.

The Company recorded a gain from extinguishment of debt in the amount of $336,820 in the second quarter of 2004, which was the difference between the carrying amount of the Bank One loan less the settlement amount.

Comparison of the Quarters Ended June 30, 2005 and 2004.

The Company recognized $1,589,693 in oil and gas revenues from its Kansas Properties and the Swan Creek Field during the second quarter of 2005 compared to $1,380,289 in the second quarter of 2004. The increase in revenues was due to an increase in oil prices in 2005. The revenue increase due to oil price increases were offset by zero Kansas gas production. Kansas gas sales were $191,295 in 2004. Oil prices in the second quarter of 2005 averaged $50.29 per barrel as compared to $36.29 per barrel in the second quarter of 2004.

The Company realized a net loss attributable to common shareholders of $(132,540) ($0.00) per share of common stock, during the second quarter of 2005 compared to a net loss in the second quarter of 2004 to common shareholders of $(281,628) ($0.01) per share of common stock.

Production costs and taxes in the second quarter of 2005 of $696,361 remained stable from $667,851 in the second quarter of 2004.

Depreciation, depletion, and amortization expense for the second quarter of 2005 was $477,846 compared to $564,984 in the second quarter of 2004. This is due to a reduction in depletion and depreciation taken due to the sale of the Kansas gas field and equipment becoming fully depreciated in late 2004.

During the second quarter of 2005, general and administrative costs only slightly increased above 2004 levels.

Professional fees, in the second quarter of 2005 were $57,226 compared to $233,403 in the same period in 2004. These fees have substantially decreased as a result of the settlement of the Bank One and Paul Miller lawsuits in 2004.

Interest expense for the second quarter of 2005 decreased from the second quarter of 2004 to $196,918 from $274,854. The substantial decrease is the result of the payoff of the Bank One loan and the Dolphin notes and the conversion of shares subject to mandatory redemption into a drilling program and cash payoff in 2004.

Liquidity and Capital Resources

On November 8, 2001, the Company signed a credit facility agreement with the Energy Finance Division of Bank One, N.A. in Houston, Texas. The Company instituted litigation in May 2002 based on certain actions taken by Bank One. On May 13, 2004, the Company resolved its dispute with Bank One. The Company had anticipated that when its dispute with Bank One was resolved it would be able to obtain financing from other institutional lenders to allow the Company to continue to both develop existing properties and locate and purchase additional properties. To date, however, due to the financial status of the Company including debt obligations owed, the Company’s credit history, and the inability of the Company to pay accrued distributions on its preferred stock, the Company has not been able to establish a banking relationship with another institutional lender. Although management continues to attempt to locate a source or sources of institutional financing for Company operations, there can be no assurances that such relationships can be established or that bank financing will be obtained or of the terms of such relationship.

On March 4, 2005, the Company sold its gas producing properties in Rush County, Kansas for $2.4 million and used the net proceeds of the sale to pay down the $2.5 million debt to Dolphin, incurred by the Company to fund the settlement of the litigation with Bank One in May, 2004. This had the effect of reducing the payment of high interest on this note, and reducing the total secured debt owed by the Company to $700,000 as of the date of this report, consisting of about $150,000 remaining principal of the $2.5 million note, and the principal of the $550,000 note used for the cash exchange of Series A Shares. See Note 5 to the financial statements.

As a result of the payment of this secured and unsecured debt, and the exchange of most of its Series A Shares, management believes the Company is now better positioned to both establish a banking relationship with an institutional lender on acceptable terms to fund the Company’s activities. Although the Company is hopeful that as a result of the substantial reduction of its debt position that it will soon be able to establish such a relationship, there is no assurance it will be able to do so. Until the Company is able to establish such a relationship, it will be necessary to fund its operations, including capital expenditures for the acquisition, exploration and development of oil and gas reserves from other sources, such as the rights offering as well as equity investment, private loans or a joint venture with other companies, as to which there can be no assurances. In addition to its operational cash requirements, the Company also has a significant amount of loans and other obligations which will either become due or mature on August 20, 2005, including secured promissory notes due to Dolphin in the principal amount of $700,000 plus interest thereon, as well as the payment of the accrued distributions on the Company’s Series B 8% Cumulative Convertible Preferred Stock and the scheduled redemption of both the Series B and Series C 6% Cumulative Convertible Preferred Stock which become due on September 5, 2005 and April 30, 2007.

On October 17, 2003, the Company filed a Registration Statement on Form S-1 with the Securities and Exchange Commission (“SEC”). On February 13, 2004, the SEC deemed the Registration Statement on Form S-1 effective. The Rights Offering closed on March 18, 2004 all 36.3 million shares offered had been subscribed and, as a result, the Company raised approximately $9.1 million

Critical Accounting Policies

The Company prepares its Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America, which requires the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the year. Actual results could differ from those estimates. The Company considers the following policies to be the most critical in understanding the judgments that are involved in preparing the Company’s financial statements and the uncertainties that could impact the Company’s results of operations, financial condition and cash flows.

Revenue Recognition

The Company recognizes revenues based on actual volumes of oil and gas sold and delivered to its customers. Natural gas meters are placed at the customers’ location and usage is billed each month. Crude oil is stored and at the time of delivery to the customers, revenues are recognized.

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 productive and non-productive costs incurred in connection with the acquisition of, exploration for and development of oil and gas reserves for each cost center are capitalized. Capitalized costs include lease acquisitions, geological and geophysical work, daily rentals and the costs of drilling, completing and equipping oil and gas wells. Costs, however, associated with production and general corporate activities are expensed in the period incurred. Interest costs related to unproved properties and properties under development are also capitalized to oil and gas properties. Gains or losses are recognized only upon sales or dispositions of significant amounts of oil and gas reserves representing an entire cost center. Proceeds from all other sales or dispositions are treated as reductions to capitalized costs. The capitalized oil and gas property, less accumulated depreciation, depletion and amortization and related deferred income taxes, if any, are generally limited to an amount (the ceiling limitation) equal to the sum of: (a) the present value of estimated future net revenues computed by applying current prices in effect as of the balance sheet date (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves, less estimated future expenditures (based on current costs) to be incurred in developing and producing the reserves using a discount factor of 10% and assuming continuation of existing economic conditions; and (b) the cost of investments in unevaluated properties excluded from the costs being amortized. No ceiling write-downs were recorded in 2005 or 2004.

Oil and Gas Reserves/Depletion Depreciationand
Amortization of Oil and Gas Properties

The capitalized costs of oil and gas properties, plus estimated future development costs relating to proved reserves and estimated costs of plugging and abandonment, net of estimated salvage value, are amortized on the unit-of-production method based on total proved reserves. The costs of unproved properties are excluded

from amortization until the properties are evaluated, subject to an annual assessment of whether impairment has occurred. There are no unproved properties as of this report.

The Company’s proved oil and gas reserves as at December 31, 2004 were estimated by Ryder Scott, L.P., Petroleum Consultants. Projecting the effects of commodity prices on production, and timing of development expenditures include many factors beyond the Company’s control. The future estimates of net cash flows from the Company’s proved reserves and their present value are based upon various assumptions about future production levels, prices, and costs that may prove to be incorrect over time. Any significant variance from assumptions could result in the actual future net cash flows being materially different from the estimates.

ITEM 3 QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

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. Monthly oil price realizations ranged from a low of $29.77 per barrel to a high of $51.12 per barrel during 2004. Gas price realizations ranged from a monthly low of $4.11 per Mcf to a monthly high of $7.78 per Mcf during the same period. The Company did not enter into any hedging agreements in 2004 or in the first six months of 2005, to limit exposure to oil and gas price fluctuations.

Interest Rate Risk

At June 30, 2005, the Company had debt outstanding of approximately $700,000 at a fixed rate. The Company did not have any open derivative contracts relating to interest rates at June 30, 2005.

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 estimating quantities of oil and gas reserves and 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 reserves and production estimates. The drilling of exploratory or developmental 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

Controls and Procedures

The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed by the Company in reports that it files or submits under the Securities Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and that such information is accumulated and communicated to our management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosures. In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management necessarily is required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures. As of the end of the period covered by this Report, and under the supervision and with the participation of the management, including its Chief Executive Officer and Chief Financial Officer, management evaluated the effectiveness of the design and operation of these disclosure controls and procedures. Based on this evaluation and subject to the foregoing, the Company’s Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective in reaching a reasonable level of assurance of achieving management’s desired controls and procedures objectives.

Changes in Internal Controls

During the period covered by this Report, there have not been any changes in the Company’s internal controls that have materially affected or are reasonably likely to materially affect, the Company’s internal 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 2 UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

On July 19, 2005, the Company issued 100,000 shares of its common stock each to two of its Directors and 50,000 to another Director for their services as members of the Company’s Audit Committee to rectify a prior issuance to these Directors in April, 2005 for the same amount of shares that had been rescinded. The Company also issued 4,000 shares of its common stock as part of the consideration for settlement of a minor lawsuit brought by a landowner regarding the Company’s right-of-way with respect to its pipeline.

ITEM 5 OTHER INFORMATION

The Company currently owns approximately 19% of the working interest in an 8-well drilling program, with the remaining 81% working interest owned by certain of the former holders of the Company’s Series A preferred stock who exchanged that stock for their drilling program interests in December, 2004. Three of the eight wells in this drilling program wells in Kansas have been drilled and completed.

All three wells are currently producing oil from the Arbuckle formation. The third well, the Ridgway A No.4, began production on June 16, 2005 and has produced 1,954 barrels as of the end of July, 2005, a 44 barrel per day average with very little water being produced with the oil to date. As of July 31, 2005 the three wells drilled in this program have produced 3,780 barrels of oil. It is anticipated that the drilling of three additional wells in this eight-well program will begin late in August or September, 2005.

The three drilling program wells were located using a combination of three dimensional seismic analysis and the Company’s Kansas geologic database. The last five wells, including the three drilling program wells discussed above, drilled by the Company using these techniques have all been successful. The Company anticipates that it will continue to drill wells primarily targeting oil production in Kansas based on these recent drilling results and current economic conditions.

ITEM 6 EXHIBITS

(a) The following exhibits are filed with this report

31.1 Certification of the President, pursuant to Exchange Act Rule, Rule 13a-14a/15d-14a.

31.2 Certification of Chief Financial Officer, pursuant Exchange Act Rule, Rule 13a-14a/15d-14

32.1 Certification of the President, pursuant to 18 U.S.C Section 1350 as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002.

32.2 Certification of Chief Financial Officer pursuant to 18 U.S.C Section 1350 as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002

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 11, 2005

TENGASCO, INC.


By: s/ Jeffrey R. Bailey Jeffrey R. Bailey President/Director


By: s/ Mark A. Ruth Mark A. Ruth Chief Financial Officer

Exhibit 31.1 CERTIFICATION

I, Jeffrey R. Bailey

1. I have reviewed this Quarterly Report on Form 10-Q of Tengasco, Inc. for the quarter ended June 30, 2005.

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 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 other certifying officer(s) and I 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-15(f) for the registrant and 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 know 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 the 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 other certifying officers and I 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 11, 2005


By: s/ Jeffrey R. Bailey Jeffrey R. Bailey President/Director

Exhibit 31.2 CERTIFICATION

I, Mark A. Ruth, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Tengasco, Inc. for the quarter ended June 30, 2005.

3. Based on my knowledge, the financial statements, and other information included in this quarterly 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;

(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 11, 2005


By: s/ Mark A. Ruth Mark A. Ruth Chief Financial Officer

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, 2005. 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 11, 2005


By: s/ Jeffrey R. Bailey Jeffrey R. Bailey President/Director

Exhibit 32.2

CERTIFICATION

Dated: August 11, 2005


By: s/ Mark A. Ruth Mark A. Ruth Chief Financial Officer

Riley Exploration Permian - 10-Q quarterly report FY

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, 2005

Commission File No. 0-20975

TENGASCO, INC. AND SUBSIDIARIES

TENGASCO, INC AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

ASSETS

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALNCE SHEETS

LIABILITIES AND STOCKHOLDERS EQUITY

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF LOSS

(Unaudited)

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS EQUITY

(Unaudited)

TENGASCO, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

Tengasco, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

(Unaudited)

(2) Going Concern

(3) Earnings per Share

(6) Cumulative Convertible Redeemable Preferred Stock and Drilling Program

(7) Asset Retirement Obligation

(8) Sale of Gas Wells

(9) Rights Offering

Results of Operations and Financial Condition

Kansas

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