Riley Exploration Permian, Inc. - Quarter Report: 2019 September (Form 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 September 30, 2019

Commission File No. 1-15555

Tengasco, Inc.

(Exact name of registrant as specified in its charter)

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

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

(Address of principal executive offices)

720-420-4460

(Registrant’s telephone number, including area code)

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

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

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

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

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

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

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 10,658,775 common shares at November 4, 2019.

TABLE OF CONTENTS

		PAGE
PART I.	FINANCIAL INFORMATION
	ITEM 1. FINANCIAL STATEMENTS
	* Unaudited Condensed Consolidated Balance Sheets as of September 30, 2019 and December 31, 2018	3
	* Unaudited Condensed Consolidated Statements of Operations for the three months and nine months ended September 30, 2019 and 2018	5
	* Unaudited Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2019 and 2018	6
	* Notes to Unaudited Condensed Consolidated Financial Statements	8
	ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	19
	ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	21
	ITEM 4. CONTROLS AND PROCEDURES	23
PART II.	OTHER INFORMATION	23
	ITEM 1. LEGAL PROCEEDINGS	23
	ITEM 1A. RISK FACTORS	23
	ITEM 2. UNREGISTERD SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	23
	ITEM 3. DEFAULTS UPON SENIOR SECURITIES	23
	ITEM 4. MINE SAFTY DISCLOSURES	23
	ITEM 5. OTHER INFORMATION	23
	ITEM 6. EXHIBITS	24
	* SIGNATURES	25
	* CERTIFICATIONS

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Tengasco, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(unaudited)

(in thousands, except share data)

	September 30, 2019		December 31, 2018
Assets

Current
Cash and cash equivalents	$	3,482	$	3,115
Accounts receivable		511		533
Inventory		325		464
Prepaid expenses		192		235
Total current assets		4,510		4,347
Loan fees, net		5		9
Right of use asset - operating leases		55		—
Oil and gas properties, net (full cost accounting method)		4,344		4,804
Other property and equipment, net		134		190
Accounts receivable - noncurrent		130		130
Other noncurrent assets		4		4
Total assets	$	9,182	$	9,484

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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Tengasco, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(unaudited)

(in thousands, except share data)

	September 30, 2019			December 31, 2018
Liabilities and Stockholders’ Equity

Current liabilities
Accounts payable – trade	$	127		$	132
Accrued liabilities		231			282
Lease liabilities - operating leases - current		56			—
Lease liabilities - finance leases - current		59			—
Current maturities of long-term debt		—			51
Asset retirement obligation - current		83			83
Total current liabilities		556			548
Lease liabilities - operating leases - noncurrent		—			—
Lease liabilities - finance leases - noncurrent		29			—
Long term debt, less current maturities		—			73
Asset retirement obligation - noncurrent		2,085			2,096
Total liabilities		2,670			2,717
Commitments and contingencies (Note 12)
Stockholders’ equity
Preferred stock, 25,000,000 shares authorized:
Series A Preferred stock, $0.0001 par value, 10,000 shares designated; 0 shares issued and outstanding		—			—
Common stock, $0.001 par value, authorized 100,000,000 shares, 10,653,550 and 10,639,290 shares issued and outstanding		11			11
Additional paid–in capital		58,290			58,276
Accumulated deficit		(51,789	)		(51,520	)
Total stockholders’ equity		6,512			6,767
Total liabilities and stockholders’ equity	$	9,182		$	9,484

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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Tengasco, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(unaudited)

(in thousands, except share and per share data)

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2019			2018			2019			2018
Revenues
Oil and gas properties	$	1,215		$	1,654		$	3,777		$	4,497
Total revenues		1,215			1,654			3,777			4,497
Cost and expenses
Production costs and taxes		913			862			2,604			2,502
Depreciation, depletion, and amortization		186			219			566			599
General and administrative		297			288			913			896
Total cost and expenses		1,396			1,369			4,083			3,997
Net income (loss) from operations		(181	)		285			(306	)		500
Other income (expense)
Interest expense		(2	)		(1	)		(8	)		(4	)
Gain on sale of assets		1			14			45			34
Total other income (expense)		(1	)		13			37			30
Net income (loss) from operations before income tax		(182	)		298			(269	)		530
Deferred income tax benefit		—			—			—			—
Net income (loss) from continuing operations		(182	)		298			(269	)		530
Net income from discontinued operations		—			—			—			1,120
Net income (loss)	$	(182	)	$	298		$	(269	)	$	1,650
Net income (loss) per share - basic and fully diluted
Continuing operations	$	(0.02	)	$	0.03		$	(0.03	)	$	0.05
Discontinued operations	$	—		$	—		$	—		$	0.11
Shares used in computing earnings per share
Basic and fully diluted		10,653,550			10,624,493			10,648,838			10,624,476

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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Tengasco, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(unaudited)

(in thousands)

	For the Nine Months Ended September 30,
	2019			2018
Operating activities
Net income (loss) from continuing operations	$	(269	)	$	530
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, and amortization		566			599
Amortization of loan fees-interest expense		4			3
Accretion on asset retirement obligation		100			106
Gain on asset sales		(45	)		(34	)
Stock based compensation		14			4
Changes in assets and liabilities:
Accounts receivable		22			(57	)
Inventory and other assets		78			(144	)
Accounts payable		4			(14	)
Accrued and other current liabilities		(51	)		30
Settlement on asset retirement obligation		(52	)		(5	)
Net cash provided by operating activities - continuing operations		371			1,018
Net cash provided by operating activities - discontinued operations		—			45
Net cash provided by operating activities		371			1,063
Investing activities
Additions to oil and gas properties		(153	)		(453	)
Proceeds from sale of oil and gas properties		41			7
Additions to other property and equipment		(2	)		(28	)
Proceeds from sale of other property and equipment		—			8
Proceeds from sale of materials inventory		150			—
Net cash provided by (used in) investing activities - continuing operations		36			(466	)
Net cash provided by investing activities - discontinued operations		—			2,650
Net cash provided by investing activities		36			2,184
Financing activities
Repayments of borrowings		(40	)		(130	)
Proceeds from borrowings		—			100
Net cash used in financing activities - continuing operations		(40	)		(30	)
Net cash provided by (used in) financing activities - discontinued operations		—			—
Net cash used in financing activities		(40	)		(30	)
Net change in cash and cash equivalents		367			3,217
Cash and cash equivalents, beginning of period		3,115			185
Cash and cash equivalents, end of period	$	3,482		$	3,402
Supplemental cash flow information:
Cash interest payments	$	4		$	—
Supplemental non-cash investing and financing activities:
Financed company vehicles	$	30		$	76
Capital expenditures included in accounts payable and accrued liabilities	$	—		$	227

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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Tengasco, Inc. and Subsidiaries

Changes in Stockholders' Equity

(unaudited)

(In thousands, except per share and share data)

Nine Months Ended September 30, 2019:

	Common Stock				Paid-in Capital		Accumulated Deficit			Total
	Shares		Amount		Paid-in Capital		Accumulated Deficit			Total
Balance, December 31, 2018		10,639,290	$	11	$	58,276	$	(51,520	)	$	6,767

Net loss		—		—		—		(96	)		(96	)
Compensation expense related to stock issued		4,962		—		4		—			4

Balance, March 31, 2019		10,644,252	$	11	$	58,280	$	(51,616	)	$	6,675

Net income		—		—		—		9			9
Compensation expense related to stock issued		4,411		—		6		—			6

Balance, June 30, 2019		10,648,663	$	11	$	58,286	$	(51,607	)	$	6,690

Net loss		—		—		—		(182	)		(182	)
Compensation expense related to stock issued		4,887		—		4		—			4

Balance, September 30, 2019		10,653,550	$	11	$	58,290	$	(51,789	)	$	6,512

Nine Months Ended September 30, 2018:

	Common Stock				Paid-in Capital		Accumulated Deficit			Total
	Shares		Amount		Paid-in Capital		Accumulated Deficit			Total
Balance, December 31, 2017		10,619,924	$	11	$	58,253	$	(53,089	)	$	5,175

Net income		—		—		—		1,243			1,243
Compensation expense related to stock issued		4,569		—		4		—			4

Balance, March 31, 2018		10,624,493	$	11	$	58,257	$	(51,846	)	$	6,422

Net income		—		—		—		109			109
Compensation expense related to stock issued		—		—		—		—			—

Balance, June 30, 2018		10,624,493	$	11	$	58,257	$	(51,737	)	$	6,531

Net income		—		—		—		298			298
Compensation expense related to stock issued		—		—		—		—			—

Balance, September 30, 2018		10,624,493	$	11	$	58,257	$	(51,439	)	$	6,829

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

(1)	Description of Business and Significant Accounting Policies

Tengasco, Inc. (the “Company”) is a Delaware corporation. The Company is in the business of exploration for and production of oil and natural gas. The Company’s primary area of exploration and production is in Kansas.

The Company’s wholly-owned subsidiary, Manufactured Methane Corporation (“MMC”) operated treatment and delivery facilities in Church Hill, Tennessee for the extraction of methane gas from a landfill for eventual sale as natural gas and for the generation of electricity. The Company sold all its methane facility assets, except the applicable U.S. patent, on January 26, 2018 for $2.65 million. (See Note 10. Discontinued Operations)

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements as of September 30, 2019 and September 30, 2018 have been prepared in accordance with generally accepted accounting principles in the United States of America (“U.S. GAAP”) for interim financial information and with the instructions to Form 10-Q and Item 210 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements. The condensed consolidated balance sheet as of December 31, 2018 is derived from the audited financial statements, but does not include all disclosures required by U.S. GAAP. The Company believes that the disclosures made are adequate to make the information not misleading. In the opinion of management, all adjustments (consisting of only normal recurring accruals) considered necessary for a fair presentation for the periods presented have been included as required by Regulation S-X, Rule 10-01. Operating results for the nine months ended September 30, 2019 are not necessarily indicative of the results that may be expected for the year ended December 31, 2019. It is suggested that these condensed consolidated financial statements be read in conjunction with the Company’s consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018.

Principles of Consolidation

The accompanying condensed consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries after elimination of all significant intercompany transactions and balances.

Use of Estimates

The accompanying condensed consolidated financial statements are prepared in conformity with U.S. GAAP which require management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the dates of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Significant estimates include reserve quantities and estimated future cash flows associated with proved reserves, which significantly impact depletion expense and potential impairments of oil and natural gas properties, income taxes and the valuation of deferred tax assets, stock-based compensation, and commitments and contingencies. We analyze our estimates based on historical experience and various other assumptions that we believe to be reasonable. While we believe that our estimates and assumptions used in preparation of the condensed consolidated financial statements are appropriate, actual results could differ from those estimates and assumptions.

Revenue Recognition

The Company identifies the contracts with each of its customers and the separate performance obligations associated with each of these contracts. Revenues are recognized when the performance obligations are satisfied and when control of goods or services are transferred to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services.

Crude oil is sold on a month-to-month contract at a price based on an index price from the purchaser, net of differentials. Crude oil that is produced is stored in storage tanks. The Company will contact the purchaser and request it to pick up the crude oil from the storage tanks. When the purchaser picks up the crude from the storage tanks, control of the crude transfers to the purchaser, the Company’s contractual obligation is satisfied, and revenues are recognized. The sales of oil represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling oil on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports revenues on a net basis to the Company. Fees and other deductions incurred prior to transfer of control are recorded as production costs. Revenues are reported net of fees and other deductions incurred after transfer of control.

Electricity from the Company’s methane facility was sold on a long term contract. There was no specific quantity of electricity that was required to be delivered under this contract. Electricity passed through sales meters located at the Carter Valley landfill site, at which time control of the electricity transferred to the purchaser, the Company’s contractual obligation was satisfied, and revenues were recognized. The Company sold its methane facility and generation assets on January 26, 2018 and therefore has not recognized revenues associated with any sales volumes after that date. Revenues associated with the methane facility are included in Discontinued Operations. (See Note 10. Discontinued Operations)

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

The Company operates certain salt water disposal wells, some of which accept water from third parties. The contracts with the third parties primarily require a flat monthly fee for the third parties to dispose water into the wells. In some cases, the contract is based on a per barrel charge to dispose water into the wells. There is no requirement under the contracts for these third parties to use these wells for their water disposal. If the third parties do dispose water into the Company operated wells during a given month, the Company has met its contractual obligations and revenues are recognized for that month.

The following table presents the disaggregated revenue by commodity for the three months and nine months ended September 30, 2019 and 2018 (in thousands):

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2019		2018		2019		2018

Crude oil	$	1,208	$	1,647	$	3,757	$	4,472
Saltwater disposal fees		7		7		20		25
Total	$	1,215	$	1,654	$	3,777	$	4,497

There were no natural gas imbalances at September 30, 2019 or December 31, 2018.

Cash and Cash Equivalents

Cash and cash equivalents include temporary cash investments with a maturity of ninety days or less at date of purchase.

Inventory

Inventory consists of crude oil in tanks and is carried at lower of cost or market value. The cost component of the oil inventory is calculated using the average cost per barrel for the three months ended September 30, 2019 and December 31, 2018. These costs include production costs and taxes. The market value component is calculated using the average September 2019 and December 2018 oil sales prices received from the Company’s Kansas properties. In addition, at December 31, 2018, the Company recorded equipment and materials to be used in its Kansas operation as inventory and was carried at the lower of cost or market value. The equipment inventory was sold to a third party during the three months ended March 31, 2019. The cost component of the equipment and materials inventory represented the original cost paid for the equipment and materials. The market component is based on estimated sales value for similar equipment and materials at the end of each period. At September 30, 2019 and December 31, 2018, inventory consisted of the following (in thousands):

	September 30, 2019		December 31, 2018
Oil – carried at cost	$	325	$	359
Equipment and materials – carried at market		—		105
Total inventory	$	325	$	464

Full Cost Method of Accounting

The Company follows the full cost method of accounting for oil and gas property acquisition, exploration, and development activities. Under this method, all costs incurred in connection with acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs include lease acquisitions, seismic related costs, certain internal exploration costs, drilling, completion, and estimated asset retirement costs. The capitalized costs of oil and gas properties, plus estimated future development costs relating to proved reserves and estimated asset retirement costs which are not already included, net of estimated salvage value, are amortized on the unit-of-production method based on total proved reserves. The Company has determined its reserves based upon reserve reports provided by LaRoche Petroleum Consultants Ltd. since 2009. The costs of unproved properties are excluded from amortization until the properties are evaluated, subject to an annual assessment of whether impairment has occurred. The Company had $0 in unevaluated properties as of September 30, 2019 and $23,000 at December 31, 2018. Proceeds from the sale of oil and gas properties are accounted for as reductions to capitalized costs unless such sales cause a significant change in the relationship between costs and the estimated value of proved reserves, in which case a gain or loss is recognized.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

At the end of each reporting period, the Company performs a “ceiling test” on the value of the net capitalized cost of oil and gas properties. This test compares the net capitalized cost (capitalized cost of oil and gas properties, net of accumulated depreciation, depletion and amortization and related deferred income taxes) to the present value of estimated future net revenues from oil and gas properties using an average price (arithmetic average of the beginning of month prices for the prior 12 months) and current cost discounted at 10% plus cost of properties not being amortized and the lower of cost or estimated fair value of unproven properties included in the cost being amortized (ceiling). If the net capitalized cost is greater than the ceiling, a write-down or impairment is required. A write-down of the carrying value of the asset is a non-cash charge that reduces earnings in the current period. Once incurred, a write-down may not be reversed in a later period. The Company did not record any impairment of its oil and gas properties during the nine months ended September 30, 2019 and 2018.

Accounts Receivable

Accounts receivable consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date, uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days of sales of oil and gas production, and other miscellaneous receivables. No interest is charged on past-due balances. Payments made on accounts receivable are applied first to the earliest unpaid items. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. There was no allowance recorded at September 30, 2019 or December 31, 2018.

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

	September 30, 2019		December 31, 2018
Revenue	$	378	$	396
Tax		129		129
Joint interest		4		8
Accounts receivable - current	$	511	$	533

Tax - noncurrent	$	130	$	130

At September 30, 2019 and December 31, 2018, the Company recorded a tax related current receivable of $129,000 and a tax related non-current receivable of $130,000. (See Note 2. Income Taxes)

Reclassifications

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

(2)	Income Taxes

Income taxes are reported in accordance with U.S. GAAP, which requires the establishment of deferred tax accounts for all temporary differences between the financial reporting and tax bases of assets and liabilities, using currently enacted federal and state income tax rates. In addition, deferred tax accounts must be adjusted to reflect new rates if enacted into law.

The deferred income tax assets or liabilities for an oil and gas exploration and development company are dependent on many variables such as estimates of the economic lives of depleting oil and gas reserves and commodity prices. Accordingly, the asset or liability is subject to continuous recalculation and revision of the numerous estimates required, and may change significantly in the event of occurrences such as major acquisitions, divestitures, commodity price changes, changes in reserve estimates, changes in reserve lives, and changes in tax rates or tax laws.

The estimated annual effective tax rate of 0% differs from the statutory rate of 21% due primarily to adjustments to the valuation allowance on the deferred tax assets.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

At December 31, 2018, federal net operating loss carryforwards amounted to approximately $35.8 million, of which $34.8 million expires between 2019 and 2037, which can offset 100% of taxable income and $1 million that has an indefinite carryforward period which can offset 80% of taxable income per year. The Company has approximately $260,000 in refundable credits, and it expects that a substantial portion will be refunded between 2018 and 2021. As 50% of the credit will be refunded when we file the 2018 tax return, this amount is recorded as a current accounts receivable on the Balance Sheet at September 30, 2019 and December 31, 2018, with balance of this refund recorded as a non-current accounts receivable. The Company recorded a valuation allowance on the remaining deferred tax assets at September 30, 2019 and December 31, 2018 as such amounts were not considered to be more-likely-than-not realizable. There were no recorded unrecognized tax benefits at September 30, 2019 and December 31, 2018.

(3)	Capital Stock

Common Stock

On July 1, 2019, the Company issued 4,887 shares of common stock in the aggregate to the Company’s three directors and CFO and interim CEO.

On October 1, 2019, the Company issued 5,225 shares of common stock in the aggregate to the Company’s three directors and CFO and interim CEO.

Rights Agreement

Effective March 17, 2017 the Board of Directors declared a dividend of one right (a “Right”) for each of the Company’s issued and outstanding shares of common stock, $0.001 par value per share (“Common Stock”). The dividend was paid to the stockholders of record at the close of business on March 27, 2017 (the “Record Date”). Each Right entitles the registered holder, subject to the terms of the Rights Agreement dated as of March 16, 2017 (the “Rights Agreement”) between the Company and the Rights Agent, Continental Stock Transfer & Trust Company, to purchase from the Company one one-thousandth of a share of the Company’s Series A Preferred Stock at a price of $1.10 (the “Exercise Price”), subject to certain adjustments.

The purpose of the Rights Agreement is to reduce the risk that the Company’s ability to use its net operating losses to reduce potential future federal income tax obligations would be limited if the Company’s experiences an “ownership change,” as defined in Section 382 of the Internal Revenue Code. A company generally experiences an ownership change if the percentage of its stock owned by its “5-percent shareholders,” as defined in Section 382 of the Tax Code, increases by more than 50 percentage points over a rolling three-year period. The Rights Agreement is designed to reduce the likelihood that the Company will experience an ownership change under Section 382 of the Tax Code by discouraging any person or group from becoming a 4.95% shareholder and also discouraging any existing 4.95% (or more) shareholder from acquiring additional shares of the Company’s stock.

The Rights will not be exercisable until the “Distribution Date”, which is generally defined as the earlier to occur of:(i) a public announcement or filing that a person or group has, become an “Acquiring Person” which is defined as a person or group of affiliated or associated persons or persons acting in concert who, at any time after the date of the Rights Agreement, have acquired, or obtained the right to acquire, beneficial ownership of 4.95% or more of the Company’s outstanding shares of Common Stock; or a person or group currently owning 4.95% (or more) of the Company’s outstanding shares acquires additional shares of the Company’s stock; subject to certain exceptions; or (ii) the commencement of, or announcement of an intention to commence, a tender offer or exchange offer the consummation of which would result in any person becoming an Acquiring Person.

The Rights, unless extended by the Board of Directors will expire prior to the earlier of March 16, 2020; or a date the Board of Directors determines by resolution in its business judgment that the Agreement is no longer necessary or appropriate; or in certain other specified circumstances.

At any time after any person or group of affiliated or associated persons becomes an Acquiring Person, the Board, at its option, may exchange each Right (other than Rights owned by such person or group of affiliated or associated persons which will have become void), in whole or in part, at an exchange ratio of two shares of Common Stock per outstanding Right (subject to adjustment).

For further information on the Rights Agreement, please refer to the Rights Agreement that was attached in full as an exhibit to the Company’s Form 8-K filed with SEC on March 17, 2017.

Preferred Stock

Series A Preferred Stock has a par value of $0.0001 and 10,000 shares have been designated. No shares of Series A Preferred Stock have been issued by the Company pursuant to the Rights Agreement described above or otherwise.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

(4)	Earnings per Common Share

We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share which include the effect of all potentially dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators of our basic and diluted earnings per share, (in thousands except for share and per share amounts):

	For the Three Months Ended September 30,					For the Nine Months Ended September 30,
	2019			2018		2019			2018
Income (numerator):
Net income (loss) from continuing operations	$	(182	)	$	298	$	(269	)	$	530
Net income from discontinued operations	$	—		$	—	$	—		$	1,120
Weighted average shares (denominator):
Weighted average shares – basic		10,653,550			10,624,493		10,648,838			10,624,476
Dilution effect of share-based compensation, treasury method		—			—		—			—
Weighted average shares – dilutive		10,653,550			10,624,493		10,648,838			10,624,476
Income (loss) per share – basic and dilutive:
Continuing operations	$	(0.02	)	$	0.03	$	(0.03	)	$	0.05
Discontinued operations	$	—		$	—	$	—		$	0.11

Options issued to the Company’s directors in which the exercise price was higher than the average market price each quarter were excluded from diluted shares as they would have been anti-dilutive. In addition, the shares that would be issued to employees and Company directors if the thirty day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $85 per barrel have also been excluded from this calculation. (See Note 12. Commitments and Contingencies)

(5)	Recent Accounting Pronouncements

In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842). This guidance was issued to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. This guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application of the amendments was permitted for all entities. The Company has identified each of its leases and determined the impact of this new guidance on each of the identified leases. The Company implemented ASU 2016-02 Leases (Topic 842) as of January 1, 2019 using the modified retrospective approach. As a result of this implementation, the Company recorded right-of-use assets and liabilities associated with operating leases of approximately $98,000. There was no transition adjustment related to finance leases.

The Company elected the package of practical expedients within ASU 2016-02 Leases (Topic 842) that allows an entity to not reassess, prior to the effective date, (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification of any expired or existing leases, or (iii) initial direct costs for any existing leases. Additionally, the Company elected the practical expedient to not evaluate existing or expired land easements not previously accounted for as leases prior to the effective date. The Company also made an account policy election not to apply the lease recognition requirements to leases with an initial term of 12 months or less.

(6)	Related Party Transactions

On September 17, 2007, Hoactzin Partners, L.P. (“Hoactzin”) subscribed to a drilling program offered by the Company consisting of wells to be drilled on the Company’s Kansas Properties (the “Program”). Peter E. Salas, the Chairman of the Board of Directors of the Company, is the controlling person of Hoactzin and of Dolphin Offshore Partners, L.P., the Company’s largest shareholder. Hoactzin was also conveyed a net profits interest in the MMC facility at the Carter Valley municipal solid waste landfill owned and operated by Republic Services, Inc. in Church Hill, Tennessee where the Company installed a propriety combination of advanced gas treatment technology to extract the methane component of the purchased gas stream (the “Methane Project”). As a result of the startup costs, monthly operating expenses, and gas production levels experienced, no net profits as defined were realized during the period from startup in April, 2009 through January 26, 2018 (the date the Company sold the Methane Project to a third party, and the net profits interest of Hoactzin terminated). Consequently, no payment to Hoactzin were made under the net profits interest at any time. In addition, during the fourth quarter of 2018, the Company acquired all of Hoactzin’s working interest in the drilling program wells for $134,690.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

On December 18, 2007, the Company entered into a Management Agreement with Hoactzin to manage on behalf of Hoactzin all of its working interest in certain oil and gas properties owned by Hoactzin and located in the onshore Texas Gulf Coast, and offshore Texas and offshore Louisiana. As part of the consideration for the Company’s agreement to enter into the Management Agreement, Hoactzin granted to the Company an option to participate in up to a 15% working interest on a dollar for dollar cost basis in any new drilling or workover activities undertaken on Hoactzin’s managed properties during the term of the Management Agreement. The Management Agreement expired on December 18, 2012.

The Company entered into a transition agreement with Hoactzin effective December 18, 2012 whereby the Company no longer performs operations, but administratively assists Hoactzin in becoming operator of record of these wells and transferring all bonds from the Company to Hoactzin. This assistance is primarily related to signing the necessary documents to effectuate this transition. Hoactzin and its controlling member are indemnifying the Company for any costs or liabilities incurred by the Company resulting from such assistance or the fact that the Company is the operator of record on certain of these wells. As of the date of this Report, the Company continues to administratively assist Hoactzin with this transition process.

(7)	Oil and Gas Properties

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

	September 30, 2019			December 31, 2018
Oil and gas properties	$	6,574		$	6,503
Unevaluated properties		—			23
Accumulated depreciation, depletion, and amortization		(2,230	)		(1,722	)
Oil and gas properties, net	$	4,344		$	4,804

The Company recorded depletion expense of $504,000 and $546,000 for the nine months ended September 30, 2019 and 2018, respectively. During the nine months ended September 30, 2019 and 2018, the Company also recorded in “Accumulated depreciation, depletion, and amortization” a $4,000 gain on asset retirement obligations and an $8,000 gain on asset retirement obligations, respectively.

(8)	Asset Retirement Obligation

Our asset retirement obligations represent the estimated present value of the amount we will incur to plug, abandon, and remediate our producing properties at the end of their productive lives in accordance with applicable laws. The following table summarizes the Company’s Asset Retirement Obligation transactions for the nine months ended September 30, 2019 (in thousands):

Balance December 31, 2018	$	2,179
Accretion expense		100
Liabilities incurred		—
Liabilities settled		(56	)
Liabilities relieved - sold properties		(55	)
Balance September 30, 2019	$	2,168

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

(9)	Long-Term Debt and Lease Liabilities

Long Term Debt

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

	September 30, 2019		December 31, 2018
Note payable to a financial institution, with interest only payment until maturity.	$	—	$	—
Installment notes bearing interest at the rate of 5.0% to 6.5% per annum collateralized by vehicles with monthly payments including interest, insurance and maintenance of approximately $5		—		124
Total long-term debt		—		124
Less current maturities		—		(51	)
Long-term debt, less current maturities	$	—	$	73

At September 30, 2019, installment notes are recorded to Lease liabilities – finance leases.

At September 30, 2019, the Company had a revolving credit facility with Prosperity Bank. This has historically been the Company’s primary source to fund working capital and capital spending. Under the credit facility, loans and letters of credit are available to the Company on a revolving basis in an amount outstanding not to exceed the lesser of $50 million or the Company’s borrowing base in effect from time to time. As of September 30, 2019, the Company’s borrowing base was $4 million, subject to a credit limit based on current covenants of $3.8 million. The credit facility is secured by substantially all of the Company’s producing and non-producing oil and gas properties. The credit facility includes certain covenants with which the Company is required to comply. At September 30, 2019, these covenants include the following: (a) Current Ratio > 1:1; (b) Funded Debt to EBITDA < 3.5x; and (c) Interest Coverage > 3.0x. At September 30, 2019, the interest rate on this credit facility was 5.50%. The Company was in compliance with all covenants during the quarter ended September 30, 2019. The Company had no outstanding borrowing under the facility as of September 30, 2019 or December 31, 2018.

During July 2019, the Company’s senior credit facility with Prosperity Bank after Prosperity Bank’s most recent review of the Company’s currently owned producing properties was amended to increase the borrowing base to $4 million, subject to a credit limit based on current covenants of $3.8 million, and the maturity date was extended to July 31, 2021. The borrowing base remains subject to the existing periodic redetermination provisions in the credit facility. The interest rate remained prime plus 0.50% per annum. This rate was 6.00% at the date of the amendment. The maximum line of credit of the Company under the Prosperity Bank credit facility remained $50 million. The next borrowing base review will take place in November 2019.

Lease Liabilities

Effective January 1, 2018, the Company adopted ASU 2016-02 Leases (Topic 842). We first determine if a contract is a lease at inception of the arrangement. To the extent that we determine an arrangement represents a lease, we then classify that lease as an operating lease or a finance lease. As of January 1, 2019, the Company capitalizes its operating leases on the Consolidated Balance Sheet as a right of use asset and a corresponding lease liability. The Company also capitalizes its finance leases on the Consolidated Balance Sheet as other property and equipment and a corresponding lease liability. The right of use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Short term leases that have an initial term of one year or less are not capitalized unless the Company intends to renew the lease to extend the initial term past one year.

We lease certain office space, a storage yard, and field vehicles to support our operations. A more detailed description of the Company’s lease types is included below.

Office and Storage Yard

The Company maintains an office to support its corporate operations. This office agreement is with a third party and was structured with a 39 month initial term. The Company can renew the lease for 36 additional months by providing to the Landlord written notice of intent to exercise the renewal not less than nine months prior to expiration of the initial term. The Company’s corporate office lease is classified as an operating lease.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

The Company maintains an office to support its field operations. This office is with a third party and is on a month-to-month lease. However, the Company intends to continue to renew this lease for the foreseeable future. Based on the Company’s intent to renew the lease, the Company is assuming the same lease term as its corporate office lease for calculation of its right of use asset and lease liability. The Company’s field office lease is classified as an operating lease.

The Company maintains a yard to store certain equipment used in its field operations. This storage yard agreement is with a third party and is on a month-to-month lease. However, the Company intends to continue to renew this lease for the foreseeable future. Based on the Company’s intent to renew the lease, the Company is assuming the same lease term as its corporate office lease for calculation of its right of use asset and lease liability. The Company’s storage yard is classified as an operating lease.

Field Vehicles

The Company leases certain vehicles from a third party for use in its field operations. The lease term for each vehicle is based on expected daily use of the vehicles by the field personnel, typically between 18 and 36 months. The Company also pays an upfront fee at the commencement of the lease term. The Company can continue to lease the vehicles past the initial lease term on a month-to-month basis. In addition, each vehicle has a residual value guarantee at the end of the lease term. The Company’s field vehicle leases are classified as finance leases.

Significant Judgment

In order to determine whether the Company’s contracts contain a lease component, the Company is required to exercise significant judgment. The Company will review each contract to determine if: an asset is specified in the contract; the asset is physically distinct; the supplier does not have substantive substitution rights; the Company obtains substantially all economic benefit from use of the asset; and the Company can direct the use of the asset. The Company also determines the appropriate discount rate to use on each lease. If there is a stated rate in the contract, the Company will use the stated rate as its discount rate. The contract associated with the field vehicles includes a stated rate typically between 5% and 6.5%. These stated rates for the field vehicle agreements were used as the discount rates. If there is no stated rate, the Company will use its borrowing rate as the discount rate. The contracts associated with the offices and yard do not include a stated rate. The Company used its borrowing rate of 6% as the discounts rate for these agreements.

Components of lease costs for the three months and nine months ended September 30, 2019 (in thousands):

		Period Ended
	Income Statement Account	Three Months September 30, 2019		Nine Months September 30, 2019

Operating lease cost:
	Production costs and taxes	$	3	$	10
	General and administrative		12		37
Total operating lease cost		$	15	$	47

Finance lease cost:
Amortization of right of use assets	Depreciation, depletion, and amortization	$	21	$	62
Interest on lease liabilities	Net interest expense		1		4
Total finance lease cost		$	22	$	66

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

Supplemental lease related cash flow information for the three months and nine months ended September 30, 2019 (in thousands):

	Period Ended
	Three Months September 30, 2019		Nine Months September 30, 2019

Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	15	$	45
Operating cash flows from finance leases		1		4
Finance cash flows from finance leases		9		40

Right of use assets obtained in exchange for lease obligations:
Operating leases		—		98

Supplemental lease related balance sheet information as of September 30, 2019 and December 31, 2018 (in thousands):

	Balance Sheet as of
	September 30, 2019			December 31, 2018

Operating Leases:

Right of use asset - operating leases	$	55		$	—

Lease liabilities - current	$	56		$	—
Lease liabilities - noncurrent		—			—
Total operating lease liabilities	$	56		$	—


Finance Leases:

Other property and equipment, gross	$	263		$	—
Accumulated depreciation		(129	)		—
Other property and equipment, net	$	134		$	—

Lease liabilities - current	$	59		$	—
Lease liabilities - noncurrent		29			—
Total finance lease liabilities	$	88		$	—

Weighted average remaining lease term and discount rate as of September 30, 2019:

	Operating Leases			Finance Leases

Weighted average remaining lease term	0.9 years			0.9 years
Weighted average discount rate		6.0	%		5.7	%

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

Maturity of lease liabilities as of September 30, 2019 (in thousands):

	Operating Leases			Finance Leases

2019 (October 2019 - December 2019)	$	16		$	27
2020		42			43
2021		—			20
Total lease payments		58			90
Less imputed interest		(2	)		(2	)
Total	$	56		$	88

(10)	Discontinued Operations

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

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2019		2018		2019		2018

Revenues	$	—	$	—	$	—	$	6
Production costs and taxes		—		—		—		(40	)
Depreciation, depletion, and amortization		—		—		—		(4	)
Interest income		—		—		—		1
Gain on sale of assets		—		—		—		1,157
Deferred income tax benefit		—		—		—		—
Net income from discontinued operations	$	—	$	—	$	—	$	1,120

Discontinued operations are related to the Manufactured Methane facilities. The Company sold all its methane facility assets, except the applicable U.S. patent, on January 26, 2018 for $2.65 million.

(11)	Fair Value Measurements

FASB ASC 820, “Fair Value Measurements and Disclosures”, establishes a framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under FASB ASC 820 are described as follows:

Level 1 – Observable inputs, such as unadjusted quoted prices in active markets, for substantially identical assets and liabilities.

Level 2 – Observable inputs other than quoted prices within Level 1 for similar assets and liabilities. These include quoted prices for similar assets and liabilities in active markets, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data. If the asset or liability has a specified or contractual term, the input must be observable for substantially the full term of the asset or liability.

Level 3 – Unobservable inputs that are supported by little or no market activity, generally requiring a significant amount of judgment by management. The assets or liabilities fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Valuation techniques used need to maximize the use of observable inputs and minimize the use of unobservable inputs.

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Tengasco, Inc. and Subsidiaries

Notes to Unaudited Condensed Consolidated Financial Statements

The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Further, although the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.

Upon completion of wells, the Company records an asset retirement obligation at fair value using Level 3 assumptions.

Nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis upon impairment. The carrying amounts of other financial instruments including cash and cash equivalents, accounts receivable, account payables, accrued liabilities and long-term debt in our balance sheet approximates fair value as of September 30, 2019 and December 31, 2018.

(12)	Commitments and Contingencies

The Company as designated operator of the Hoactzin properties was administratively issued an “Incident of Non-Compliance” by the Bureau of Safety and Environmental Enforcement (“BSEE”) during the quarter ended September 30, 2012 concerning one of Hoactzin’s operated properties. This action called for payment of a civil penalty of $386,000 for failure to provide, upon request, documentation to the BSEE evidencing that certain safety inspections and tests had been conducted in 2011. On July 14, 2015, the federal district court in the Eastern District of Louisiana affirmed the civil penalty without reduction. The Company did not further appeal. In the third quarter of 2015, the Company paid the civil penalty and statutory interest thereon from funds borrowed under its credit facility. In the fourth quarter of 2015, the Company received a return of the cash collateral previously provided to RLI Insurance Company. The Company has not advanced any funds to pay any obligations of Hoactzin and no borrowing capability of the Company has been used in connection with its obligations under the Management Agreement, except for those funds used to pay the civil penalty and interest thereon.

During the second quarter of 2015, the Company received from Hoactzin a copy of an internal analysis prepared by Hoactzin setting out certain issues that Hoactzin may consider to form the basis of operational and other claims against the Company primarily under the Management Agreement. This analysis raised issues other than the “Incident of Non-Compliance” discussed above. The Company is discussing this analysis, as well as the civil penalty discussed above, with Hoactzin in an effort to determine whether there is possibility of a reasonable resolution of some or all of these matters on a negotiated basis.

In the normal course of business, the Company enters into commitments to spend capital on oil and gas properties. Since September 30, 2019, the Company has entered into a drilling commitment in the amount of approximately $293,000. In addition, the Company was in the process of drilling a well at September 30, 2019. Drilling commitments by the Company in excess of costs incurred through September 30, 2019 were approximately $73,000.

Cost Reduction Measures

Commencing in the quarter ended March 31, 2015 and continuing into the quarter ended June 30, 2018, the Company implemented cost reduction measures including compensation reductions for each employee as well as members of the Board of Directors. These compensation reductions were to remain in place until such time, if any, that the market price of crude oil, calculated as a thirty-day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $70 per barrel. In May 2018, oil prices as so calculated exceeded $70 and compensation reverted to the levels in place before the reductions became effective. At such time, if any, that the market price of crude oil, calculated as a thirty-day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $85 per barrel, all previous reductions made will be reimbursed, a portion which may be paid in stock, to each employee and members of the Board of Directors if is still employed by the Company or still a member of the Board of Directors. For the period January 1, 2015 through September 30, 2019, the reductions were approximately $389,000. Of the $389,000, approximately $61,000 would be paid in the Company’s common stock. The $61,000 value represents approximately 100,000 common shares valued at $0.61 per share which represents the closing price on September 30, 2019. The Company has not accrued any liabilities associated with these compensation reductions.

Legal Proceedings

The Company is not a party to any pending material legal proceeding. To the knowledge of management, no federal, state, or local governmental agency is presently contemplating any proceeding against the Company which would have a result materially adverse to the Company. To the knowledge of management, no director, executive officer or affiliate of the Company or owner of record or beneficial owner of more than 5% of the Company’s common stock is a party adverse to the Company or has a material interest adverse to the Company in any proceeding.

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ITEM 2.

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

Results of Operations and Financial Condition

During the first nine months of 2019, 92.5 MBbl gross of oil were sold from the Company’s properties. Of the 92.5 MBbl sold, 72.1 MBbl were net to the Company after required payments to all of the royalty interests and the one remaining drilling program participant. The Company’s net sales from its properties during the first nine months of 2019 of 72.1 MBbl of oil compares to net sales of 73.0 MBbl of oil during the first nine months of 2018. The Company’s net revenue from its oil and gas properties was $3.8 million during the first nine months of 2019 compared to $4.5 million during the first nine months of 2018. This decrease in net revenue was primarily due to a $662,000 reduction related to an $9.18 per barrel decrease in the average oil price from $61.27 per barrel during the first nine months of 2018 to $52.09 per barrel during the first nine months of 2019, and a $53,000 reduction related to the 860 Bbl decrease in sales volumes. The 860 Bbl decrease was primarily due to lower sales volumes on the Veverka D lease due to polymer work performed in June 2018, and natural declines on various other properties, partially offset by higher sales volumes attributed to the BSU #1-30 well that was completed in October 2018.

Comparison of the Quarters Ended September 30, 2019 and 2018

The Company reported a net loss from continuing operations of $(182,000) or $(0.02) per share of common stock during the third quarter of 2019 compared to net income from continuing operations of $298,000 or $0.03 per share of common stock during the third quarter of 2018. The $480,000 decrease in net income was primarily due to an $439,000 decrease in revenues and a $51,000 increase in production costs and taxes.

The Company recognized $1.21 million in revenues during the third quarter of 2019 compared to $1.65 million during the third quarter of 2018. The $439,000 decrease in net revenues was primarily due to a $311,000 reduction related to a $13.16 per barrel decrease in the average oil price from $64.34 per barrel during the third quarter of 2018 to $51.18 per barrel during the third quarter of 2019, and a $128,000 decrease related to the 2.0 MBbl decrease in sales volumes. The 2.0 MBbl decrease was primarily due to lower sales volumes on the Veverka D lease as a result of expected declines from higher volumes realized immediately after the polymer work performed in June 2018 and natural declines on various other properties, partially offset by higher sales volumes attributed to the BSU #1-30 well that was completed in October 2018.

Production costs and taxes increased $51,000 from $862,000 during the third quarter of 2018 to $913,000 during the third quarter of 2019. This increase was primarily due to a change in the oil inventory adjustment.

Comparison of the Nine Months Ended September 30, 2019 and 2018

The Company reported a net loss from continuing operations of $(269,000) or $(0.03) per share of common stock during the first nine months of 2019 compared to a net income from continuing operations of $530,000 or $0.05 per share of common stock during the first nine months of 2018. The $799,000 decrease in net income was primarily due to a $720,000 decrease in revenues, and a $102,000 increase in production cost and taxes.

The Company recognized $3.8 million in revenues during the first nine months of 2019 compared to $4.5 million during the first nine months of 2018. The revenue decrease from 2018 levels was primarily due to a $662,000 reduction related to an $9.18 per barrel decrease in the average oil price from $61.27 per barrel during the first nine months of 2018 to $52.09 per barrel during the first nine months of 2019, and a $53,000 reduction related to the 860 Bbl decrease in sales volumes. The 860 Bbl decrease was primarily due to lower sales volumes on the Veverka D lease as a result of expected declines from higher volumes realized immediately after the polymer work performed in June 2018 and natural declines on various other properties, partially offset by higher sales volumes attributed to the BSU #1-30 well that was completed in October 2018.

Production costs and taxes increased $102,000 from $2.5 million during the first nine months of 2018 to $2.6 million during the first nine months of 2019. This increase was primarily due to a change in the oil inventory adjustment.

Liquidity and Capital Resources

At September 30, 2019, the Company had a revolving credit facility with Prosperity Bank. This has historically been the Company’s primary source to fund working capital and capital spending. Under the credit facility, loans and letters of credit are available to the Company on a revolving basis in an amount outstanding not to exceed the lesser of $50 million or the Company’s borrowing base in effect from time to time. As of September 30, 2019, the Company’s borrowing base was $4 million, subject to a credit limit based on current covenants of approximately $3.8 million. The credit facility is secured by substantially all of the Company’s producing and non-producing oil and gas properties. The credit facility includes certain covenants with which the Company is required to comply. At September 30, 2019, these covenants include the following: (a) Current Ratio > 1:1; (b) Funded Debt to EBITDA < 3.5x; and (c) Interest Coverage > 3.0x. At September 30, 2019, the interest rate on this credit facility was 5.50%. The Company was in compliance with all covenants during the quarter ended September 30, 2019. The Company had no outstanding borrowing under the facility as of September 30, 2019 or December 31, 2018.

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During July 2019, the Company’s senior credit facility with Prosperity Bank after Prosperity Bank’s most recent review of the Company’s currently owned producing properties was amended to increase the borrowing base to $4 million, subject to a credit limit based on current covenants of approximately $3.8 million, and the maturity date was extended to July 31, 2021. The borrowing base remains subject to the existing periodic redetermination provisions in the credit facility. The interest rate remained prime plus 0.50% per annum. This rate was 6.00% at the date of the amendment. The maximum line of credit of the Company under the Prosperity Bank credit facility remained $50 million. The next borrowing base review will take place in November 2019.

Net cash provided operating activities from continuing operations was $371,000 during the first nine months of 2019 compared to $1.0 million provided by operating activities from continuing operations during the first nine months of 2018. Cash flow provided by working capital was $1,000 during the first nine months of 2019 compared to $190,000 used in working capital during the first nine months of 2018. The $191,000 increase in cash flow provided by working capital was primarily due to changes in inventory, and changes in accounts receivable, partially offset by changes in accrued liabilities, and increases in settlements on asset retirement obligations. The $647,000 decrease in cash provided by operating activities was primarily due to a $720,000 decrease in revenues, and a $102,000 increase in production cost and taxes, partially offset by the $191,000 increase in cash flow provided by working capital. Net cash provided by investing activities from continuing operations was $36,000 during the first nine months of 2019 compared to $466,000 used in investing activities from continuing operations during the first nine months of 2018. This increase in cash flow provided by investing activities was primarily due to a decrease in drilling and polymer project costs and the sale of materials inventory to a third party during the first nine months of 2019. Cash flow used in financing activities from continuing operations during the first nine months of 2019 was $40,000 compared to $30,000 used in financing activities during the first nine months of 2018.

Critical Accounting Policies

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

Commitments and Contingencies

Cost Reduction Measures

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Legal Proceedings

ITEM 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

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

As of September 30, 2019, the Company’s borrowing base was $4 million, subject to a credit limit based on current covenants of approximately $3.8 million, of which zero had been drawn down by the Company. The Company’s next periodic borrowing base review will take place in November 2019.

Commodity Risk

The Company's major market risk exposure is in the pricing applicable to its oil production. Realized pricing is primarily driven by the prevailing worldwide price for crude oil. Historically, prices received for oil and gas production have been volatile and unpredictable and price volatility is expected to continue. The average monthly Kansas oil prices received during the first nine months of 2019 ranged from a low of $46.39 per barrel to a high of $58.60 per barrel.

As of September 30, 2019, the Company has no open positions related to derivative agreements relating to commodities.

Interest Rate Risk

At September 30, 2019, the Company had balances on financing leases outstanding of approximately $88,000, and no balance owed on its credit facility with Prosperity Bank. As of September 30, 2019, the interest rate on the credit facility was variable at a rate equal to prime plus 0.50% per annum. The Company’s credit facility interest rate at September 30, 2019 was 5.50%. The Company’s financing leases of $88,000 have fixed interest rates ranging from 5.0% to 6.5%.

The annual impact on interest expense and the Company’s cash flows of a 10% increase in the interest rate on the credit facility would be approximately zero assuming borrowed amounts under the credit facility remained at the same amount owed as of September 30, 2019. The Company did not have any open derivative contracts relating to interest rates at September 30, 2019 or December 31, 2018.

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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.

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ITEM 4.

CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

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

Changes in Internal Controls

During the three months and nine months ended September 30, 2019, there have been no changes to the Company’s system of internal controls over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company’s system of controls over financial reporting. As part of a continuing effort to improve the Company’s business processes, management is evaluating its internal controls and may update certain controls to accommodate any modifications to its business processes or accounting procedures.

PART II OTHER INFORMATION

ITEM 1.

LEGAL PROCEEDINGS

None.

ITEM 1A.

RISK FACTORS

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

ITEM 2.

UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3.

DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4.

MINE SAFETY DISCLOSURES

Not Applicable

ITEM 5.

OTHER INFORMATION

None.

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ITEM 6.

EXHIBITS

The following exhibits are filed with this report:

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

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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: November 13, 2019

TENGASCO, INC.

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