10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

(Mark One)

Form 10-Q

[√] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2015

or

[ ] TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from __________________ to __________________________

Commission file number: 0-27828

TN-K ENERGY GROUP INC.

(Name of registrant as specified in its charter)

Delaware	13-3779546
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

649 Sparta Highway, Suite 102, Crossville, TN	38571
(Address of principal executive offices)	(Zip Code)

(931) 707-9599

(Registrant's telephone number, including area code)

not applicable

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 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 check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 (or for such shorter period that the registrant was required to submit and post such files).

Yes ☒ No 

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

Large accelerated filer	☐	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☒

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act)

Yes ☐ No ☒

Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date. 38,176,085 shares of common stock are issued and outstanding as of August 7, 2015.

1

TABLE OF CONTENTS

		Page No.
PART I. - FINANCIAL INFORMATION
Item 1.	Financial Statements.	4
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations.	17
Item 3.	Quantative and Qualitative Disclosures About Market Risk.	19
Item 4.	Controls and Procedures.	19
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings.	19
Item 1A.	Risk Factors.	19
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds.	19
Item 3.	Defaults Upon Senior Securities.	20
Item 4.	Mine Safety Disclosures.	20
Item 5.	Other Information.	20
Item 6.	Exhibits.	20

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This report contains forward-looking statements. These forward-looking statements are subject to known and unknown risks, uncertainties and other factors which may cause actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These forward-looking statements include, among others, the following:

• our ability to continue as a going concern,

• our business and growth strategies,

• risks associated with the external factors that impact our operations,

• our ability to satisfy our debt obligations which predate our existing business,

• volatility in oil prices,

• risks associates in general with oil and gas operations,

• our ability to find additional reserves, and

• the impact of government regulation and the impact of possible changes in tax laws.

Forward-looking statements are typically identified by use of terms such as “may”, “could”, “should”, “expect”, “plan”, “project”, “intend”, “anticipate”, “believe”, “estimate”, “predict”, “potential”, “pursue”, “target” or “continue”, the negative of such terms or other comparable terminology, although some forward-looking statements may be expressed differently. The forward-looking statements contained in this report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management’s assumptions about future events may prove to be inaccurate. Management cautions all readers that the forward-looking statements contained in this report are not guarantees of future performance, and we cannot assure any reader that such statements will be realized or the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to a number of factors, including:

• significant unforeseen events that have global or national impact such as major political disruptions, extended economic depression, and technological breakthroughs in producing oil and natural gas or in producing alternative forms of energy,

• unanticipated future changes in oil or natural gas prices, and

• other uncertainties inherent in the production of oil and natural gas.

You should consider the areas of risk described in connection with any forward-looking statements that may be made herein. You should also consider carefully the statements under Item 1A. Risk Factors appearing in our Annual Report on Form 10-K for the year ended December 31, 2014 and other sections of this report, which address additional factors that could cause our actual results to differ from those set forth in the forward-looking statements. Except for our ongoing obligations to disclose material information under the Federal securities laws, we undertake no obligation to release publicly any revisions to any forward-looking statements, to report events or to report the occurrence of unanticipated events. These forward-looking statements speak only as of the date of this report, and you should not rely on these statements without also considering the risks and uncertainties associated with these statements and our business.

2

OTHER PERTINENT INFORMATION

Unless specifically set forth to the contrary, when used in this report the terms “TN-K", "we"", "our", the "Company" and similar terms refer to TN-K Energy Group Inc., a Delaware corporation. In addition, when used herein and unless specifically set forth to the contrary, “First Quarter 2015” refers to the three months ended March 31, 2015, “First Quarter 2014” refers to the three months ended March 31, 2014, “2015” refers to the year ending December 31, 2015, and “2014” refers to the year ended December 31, 2014.

3

PART 1 - FINANCIAL INFORMATION

Item 1. Financial Statements.

TN-K Energy Group Inc

Condensed Balance Sheets

	March 31,			December 31,
	2015			2014
	(unaudited)
ASSETS:
CURRENT ASSETS:
Cash and cash equivalents	$	111,366		$	157,830
Accounts receivable		52,688			17,572
TOTAL CURRENT ASSETS		164,054			175,402
OIL AND GAS PROPERTY (Successful efforts method), at cost		1,583,583			1,546,885
EQUIPMENT, net of depreciation		89,282			95,846
OTHER ASSETS		42,000			42,000
TOTAL ASSETS	$	1,878,919		$	1,860,133
LIABILITIES AND STOCKHOLDERS' DEFICIT:
CURRENT LIABILITIES:
Accounts payable	$	2,931,105		$	2,888,728
Accrued expenses		565,195			550,655
Convertible note payable - related party		170,000			170,000
TOTAL CURRENT LIABILITIES		3,666,300			3,609,383
LONG TERM LIABILITIES:
Asset retirement obligation		33,640			33,240
Deferred income taxes payable		285,097			285,097
TOTAL LONG TERM LIABILITIES		318,737			318,337
STOCKHOLDERS' DEFICIT:
Preferred stock, $.01 par value, 5,000,000 shares authorized, none issued, and outstanding		-			-
Common stock, $.03 par value, 100,000,000 shares authorized, 38,176,085 and 38,176,085 issued and outstanding, respectively		1,145,282			1,145,282
Additional Paid - In Capital		13,640,113			13,601,316
Accumulated deficit		(16,891,514	)		(16,814,185	)
TOTAL STOCKHOLDERS' DEFICIT		(2,106,119	)		(2,067,587	)
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT	$	1,878,919		$	1,860,133

See accompanying notes to financial statements.

4

TN-K Energy Group, Inc.

Condensed Statement of Operations

(Unaudited)

	For the Three Months Ended March 31,
	2015			2014
Revenue:
Oil sales		2,775			12,886
Well Equipment Rental		20,300			-
Sale of oil and gas leases		94,500			-
Total Revenue		117,575			12,886
Expense:
Oil lease operating expense		39,266			50,038
Cost of oil and gas leases sold		29,258			-
Sales, general and administrative		122,836			58,082
Total Operating Expenses		191,360			108,120
Loss From Operations		(73,785	)		(95,234	)
Other Income (Expense):
Interest expense		(3,544	)		(3,618	)
Total Other Income (Expense)		(3,544	)		(3,618	)
Net loss before taxes	$	(77,329	)		(98,852	)
Income taxes		-			-
Net Loss	$	(77,329	)	$	(98,852	)
Basic Loss per common share	$	-		$	-
Diluted Loss per common share	$	-		$	-
Weighted average number of common shares outstanding -
Basic		38,176,085			38,176,085
Diluted		38,176,085			38,176,085

See accompanying notes to financial statements.

5

TN-K Energy Group Inc

Condensed Statement of Cash Flows

(Unaudited)

	For the Three Months Ended March 31,
	2015			2014
Cash Flow From Operating Activities:
Net Loss	$	(77,329	)	$	(98,852	)
Adjustments to reconcile Net Loss to Net Cash (Used by) Provided by Operating Activities:
Depreciation and depletion		44,999			54,987
Change in fair fair of asset retirement obligation		400			400
Equity based compensation		38,797			-
Changes in operating assets and liabilities:
Accounts receivable		(35,116	)		(3,751	)
Sale of oil and gas rights		27,426			-
Accounts payable and accrued expenses		56,917			(11,854	)
Net Cash Provided by (Used by) Operating Activities		56,094			(59,070	)
Cash Flow From Investing Activities:
Purchase and development of oil and gas rights		(102,558	)		(58,713	)
Net Cash Used by Investing Activities		(102,558	)		(58,713	)
Cash Flow From Financing Activities:
Repayment of notes payable		-			(10,000	)
Net Cash Used by Financing Activities		-			(10,000	)
Net (Decrease) In Cash and Cash Equivalents		(46,464	)		(127,783	)
Cash and cash equivalents at beginning of period		157,830			514,003
Cash and cash equivalents at end of period	$	111,366		$	386,220
Cash paid for income taxes	$	-		$	-
Cash paid for interest	$	-		$	-

See accompanying notes to financial statements.

6

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION.

Organization

TN-K Energy Group Inc. is an independent energy company engaged in the acquisition and development of crude oil reserves and production in the Appalachian Basin and to conduct directly and indirectly through third parties, operations on the properties.  In these Notes, the terms “Company”, “TN-K”, “we”, “us”, “our” and terms of similar import refer to TN-K Energy Group Inc.

Basis of Presentation

The accompanying unaudited consolidated financial statements have been prepared in accordance with generally accepted accounting principles for interim financial information. Accordingly, they do not include all of the information and the footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments, consisting only of normal recurring accruals, considered necessary for a fair presentation have been included. Operating results for the three months ended March 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2015. The accompanying consolidated financial statements should be read in conjunction with the Company’s form 10-K for the fiscal year ended December 31, 2014 which was filed on June 15, 2015.

Going Concern

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern.  Going concern contemplates the realization of assets and the satisfaction of liabilities in the normal course of business over a reasonable length of time. The Company has incurred losses since inception and has negative cash flows from operations and a substantial portion of the debt is in default and has a stockholders’ deficit of $(2,106,119) as of March 31, 2015. The future of the Company is dependent upon its ability to obtain additional equity and/or debt financing and upon the continued development of commercially viable producing wells at levels which significantly increase the Company’s revenues and net income. Management cannot assure that the Company will be able to secure such financing or obtain financing on terms beneficial to the Company or that the Company will be able to significantly increase its revenues and net income. Failure to achieve these goals may result in the Company’s inability to continue as a going concern and the impairment of the recorded long-lived assets.

These financial statements do not include any adjustments relating to the recoverability and classifications of recorded assets, or the amounts and classification of liabilities that might be necessary in the event the Company cannot continue in existence.

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES.

Cash and Cash Equivalents — For purposes of reporting cash flows, we consider cash equivalents to be all highly liquid investments with a maturity of three months or less at the time of purchase. The Company typically has cash in banks in excess of federally insured amounts.

Use of Estimates - Our financial statements are prepared in accordance with GAAP.  Preparation in accordance with GAAP requires us to (1) adopt accounting policies within accounting rules set by the Financial Accounting Standards Board (“FASB”) and by the United States Securities and Exchange Commission (“SEC”) and (2) make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and other disclosed amounts.  This Note describes our significant accounting policies.  Our management believes the major estimates and assumptions impacting our financial statements are the following:

• estimates of proven (i.e., reasonably certain) oil and gas reserve quantities, which affect the calculations of amortization and impairment of capitalized costs of oil and gas properties;

 

• estimates of the fair value of oil and gas properties we own, particularly properties that we have not yet explored, or fully explored, by drilling and completing wells;

 

• estimates of the fair value of stock options at date of grant;

 

• estimates as to the future realization of deferred income tax assets; and

 

• the assumption required by GAAP that proved reserves and generally proved reserve value for measuring capitalized cost impairment be based on the prices of oil and gas at the end of the reporting period.

7

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued).

The estimated fair values of our unevaluated oil and gas properties affect the calculation of gain on the sale of material properties and affect our assessment as to whether portions of unevaluated capitalized costs are impaired, which also affects the calculation of recorded amortization and impairment expense with regards to our capitalized costs of oil and gas properties.

The fair value of stock options at the date of grant to employees and members of our Board of Directors is based on judgment as to expected future volatility of our common stock and expected future choices by option holders as to when options are exercised.

Actual results may differ from estimates and assumptions of future events.  Future production may vary materially from estimated oil and gas proved reserves.  Actual future prices may vary significantly from price assumptions used for determining proved reserves and for financial reporting.

Fair Value — The carrying amounts reported in the balance sheets for cash, and accounts receivable approximate fair value because of the immediate or short-term maturity of these financial instruments. Predominately most of the payables are the results of operations and financings of our prior business which ceased operations in 2005, as a result of the undercapitalized nature of our Company and the age of these delinquent payables, we are unable to determine the fair value of these payables.

Accounts Receivable and Credit Policies — We have certain trade receivables consisting of oil and gas sales obligations due under normal trade terms. Our management regularly reviews trade receivables and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible.  At December 31, 2014 and March 31, 2015, management had determined no allowance for uncollectible receivables was necessary. At March 31, 2015 and December 31, 2014, we had accounts receivable and receivables from the production of oil sale of $52,688, of which $0 was accounts receivable-related party, and $17,572, of which $0 was accounts receivable-related party, respectively.

Asset Retirement Obligations — When we incur an obligation for future asset retirement costs, we record as a liability and as a cost of the acquired asset the present value of the estimated future asset retirement obligation.  For example, when we drill a well, we record a liability and an asset cost for the present value of estimated costs we will incur at the end of the well’s life to plug the well, remove surface equipment and provide restoration of the well site’s surface.  Over time, accretion of the liability is recognized as an operating expense, and the capitalized cost is amortized over the expected useful life of the related asset.  Our asset retirement obligations (“ARO”) relate primarily to the plugging, dismantlement, removal, site reclamation and similar activities of our oil and gas properties.

The following table reflects the change in ARO at:  

	March 31, 2015		December 31, 2014
Asset retirement obligation beginning of period	$	33,240	$	31,640
Liabilities incurred		-		-
Liabilities settled		-		-
Accretion		400		1,600
Revisions in estimated liabilities		-		-
Asset retirement obligation end of period	$	33,640	$	33,240
Current portion of obligation end of period	$	-	$	-

Oil and Gas Properties — We use the successful efforts method of accounting for oil and gas activities.  Under this method, subject to a limitation based on estimated value, all costs are capitalized directly associated with property acquisition, exploration and development.  Internal costs that are capitalized at March 31, 2015 and December 31, 2014, were nil as such costs have been limited to costs directly identifiable with acquisition, exploration and development activities for the Company’s account and exclude indirect costs and costs related to production or general corporate overhead.

The Company follows the successful efforts method of accounting for its oil and gas activities. Accordingly, costs associated with the acquisition, drilling and equipping of successful exploratory wells are capitalized. Geological and geophysical costs, delay and surface rentals and drilling costs of unsuccessful exploratory wells are charged to expense as incurred. Costs of drilling development wells are capitalized. Upon the sale or retirement of oil and gas properties, the cost and accumulated depreciation or depletion are removed from the accounts and any gain or loss is credited or charged to operations.

8

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued).

Capitalized costs of oil and gas properties evaluated as having, or not having, proved reserves are amortized in the aggregate by country using the unit-of-production method based upon estimated proved oil and gas reserves.  The Company currently does not have any gas production, which is sold, but we have developed policies to be inclusive of such production, if and when the Company becomes capable of selling such gas. For amortization purposes, relative volumes of oil and gas production and reserves are converted at the energy equivalent conversion rate of six thousand cubic feet of natural gas to one barrel of crude oil. Amortizable costs include estimates of future development costs of proved undeveloped reserves.  The costs of properties not yet evaluated are not amortized until evaluation of the property.  We make such evaluations for a well and associated lease rights when it is determined whether or not the well has proved oil and gas reserves.  Other unevaluated properties are evaluated for impairment as of the end of each calendar quarter based upon various factors at the time, including drilling plans, drilling activity, management’s estimated fair values of lease rights by project, and remaining lives of leases.

Capitalized costs of oil properties (net of related deferred income taxes) may not exceed a ‘ceiling’ amount equal to the present value, discounted at 10% per annum, of the estimated future net cash flows from proved oil reserves plus the cost of unevaluated properties (adjusted for related income tax effects).  Should capitalized costs exceed this ceiling, the excess is charged to earnings as an impairment expense, net of its related reduction of the deferred income tax provision.  The present value of estimated future net cash flows is computed by applying period-end oil prices of oil to estimated future production of proved oil gas reserves as of period-end, less estimated future expenditures (at period-end rates) to be incurred in developing and producing the proved reserves and assuming continuation of economic conditions existing at period-end. SEC guidance allows the ceiling to be increased for subsequent events occurring reasonably before the filing date of the affected financial statements and indicative that capitalized costs were not impaired at period-end.  Such subsequent events are increased oil prices and the proving up of additional reserves on properties owned at period-end.  The present value of proved reserves’ future net cash flows excludes future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet.

Equipment — We record at cost any long-lived tangible assets that are not oil properties.  Depreciation is recorded using the straight-line method over the estimated useful lives of the related assets of three to seven years.  Expenditures for replacements, renewals, and betterments are capitalized.  Maintenance and repairs are charged to operations as incurred.  Long-lived assets, other than oil and properties, are evaluated for impairment to determine if current circumstances and market conditions indicate the carrying amount may not be recoverable.  We have not recognized any impairment losses on non oil and gas long-lived assets.

Impairment — The accounting guidance, Accounting for the Impairment and Disposal of Long-Lived Assets, requires that long-lived assets to be held and used be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Oil properties accounted for using the successful efforts method of accounting (which we use) are excluded from this requirement but continue to be subject to the successful efforts method’s impairment rules.

Revenue Recognition — We recognize oil revenues from our interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable.  We recognize the sale of the partial interests in our oil wells once the terms of such contract have been fulfilled.

Major Customers — During the three months ended March 31, 2015 and 2014, we had two customers, respectively accounting for 100% of oil sales.  Because there are other purchasers that are capable of and willing to purchase our oil and because we have the option to change purchasers on our properties if conditions so warrant, we believe that our oil production can be sold in the market in the event that it is not sold to our existing customers, but in some circumstances a change in customers may entail significant transition costs and/or shutting in or curtailing production for weeks or even months during the transition to a new customer.

Net Income (Loss) Per Share — Basic net income (loss) per share is computed by dividing net income (loss) attributable to common stockholders by the weighted number of common shares outstanding during the period. Any common shares issued as a result of the exercise of stock options and warrants would come from newly issued common shares from our remaining authorized shares. For the year ended December 31, 2014 and the three months ended March 31, 2015, there were 3,215,000 stock options outstanding and $170,000 of convertible debt, excluded from the computation of dilutive securities as the effect would have been anti-dilutive.

Concentration of Credit Risk — Financial instruments which potentially subject the Company to concentrations of credit risk consist of cash.  We maintain substantially all cash assets at one financial institution.  We periodically evaluate the credit worthiness of financial institutions, and maintain cash accounts only in large high quality financial institutions. We believe that credit risk associated with cash is remote.  The Company is exposed to credit risk in the event of nonpayment by counter parties, a significant portion of which are concentrated in energy related industries. The creditworthiness of customers and other counter parties is subject to continuing review.

9

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued).

Share-Based Compensation — We adopted the accounting guidance for, Share-Based Payments, on a modified prospective basis. The accounting guidance requires publicly-held companies to recognize in their statements of operations the grant-date fair value of stock options and other equity-based compensation to employees, consistent with the rules for options to non-employees.

Reclassification — Certain amounts in the 2015 and 2014 consolidated financial statements have been reclassified to conform to the March 31, 2015 financial statement presentation. Such reclassifications have had no effect on net income (loss).

Recent Accounting Pronouncements

All other newly issued but not yet effective accounting pronouncements have been deemed to either not be relevant or immaterial to the operations and reporting disclosures of the Company.

In June 2014, FASB issued Accounting Standards Update (“ASU”) No. 2014-09, “ Revenue from Contracts with Customers”. The update gives entities a single comprehensive model to use in reporting information about the amount and timing of revenue resulting from contracts to provide goods or services to customers. The proposed ASU, which would apply to any entity that enters into contracts to provide goods or services, would supersede the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. Additionally, the update would supersede some cost guidance included in Subtopic 605-35, Revenue Recognition – Construction-Type and Production-Type Contracts. The update removes inconsistencies and weaknesses in revenue requirements and provides a more robust framework for addressing revenue issues and more useful information to users of financial statements through improved disclosure requirements. In addition, the update improves comparability of revenue recognition practices across entities, industries, jurisdictions, and capital markets and simplifies the preparation of financial statements by reducing the number of requirements to which an entity must refer. The update is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. We are currently reviewing the provisions of this ASU to determine if there will be any impact on our results of operations, cash flows or financial condition.

ASU 2014 -15 issued August 2014

In August 2014, the FASB issued Accounting Standards Update “ASU” 2014-15 on “Presentation of Financial Statements Going Concern (Subtopic 205-40) – Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern”. Currently, there is no guidance in U.S. GAAP about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern or to provide related footnote disclosures. The amendments in this Update provide that guidance. In doing so, the amendments are intended to reduce diversity in the timing and content of footnote disclosures. The amendments require management to assess an entity’s ability to continue as a going concern by incorporating and expanding upon certain principles that are currently in U.S. auditing standards. Specifically, the amendments (1) provide a definition of the term substantial doubt, (2) require an evaluation every reporting period including interim periods, (3) provide principles for considering the mitigating effect of management’s plans, (4) require certain disclosures when substantial doubt is alleviated as a result of consideration of management’s plans, (5) require an express statement and other disclosures when substantial doubt is not alleviated, and (6) require an assessment for a period of one year after the date that the financial statements are issued (or available to be issued).

The amendments in this Update are effective for public and nonpublic entities for annual period’s ending after December 15, 2016. Early adoption is permitted.

10

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 3 — OIL AND GAS PROPERTIES AND EQUIPMENT.

Oil and Gas Properties and equipment consisted of the following:

	March 31, 2015			December 31, 2014
Oil and gas properties, successful efforts method
Unevaluated costs, not yet subject to amortization	$	1,212,701		$	1,212,701
Evaluated costs		1,944,669			1,869,537
Asset retirement costs		39,600			39,600
		3,196,970			3,121,839
Well equipment, furniture and software		183,809			183,809
		3,380,779			3,305,648
Less accumulated depreciation, depletion and amortization		(1,707,914	)		(1,662,916	)
Oil and gas property and equipment	$	1,672,865		$	1,642,731

Unevaluated Oil Properties

Costs directly associated with the acquisition and evaluation of unproved properties are excluded from the amortization computation.  The following table shows, by year incurred, the unevaluated oil and gas property costs (net of transfers to evaluated costs and net of sales proceeds) excluded from the amortization computation: 

Year Incurred	Net Costs Incurred
Three months ended March 31, 2015	$	0
Year ended December 31, 2014		(112,704	)
Year ended December 31, 2013		(67,274	)
Year ended December 31, 2012		842,811
Year ended December 31, 2011		(592,569	)
Year ended December 31, 2010		916,532
Year ended December 31, 2009		225,905
	$	1,212,701

Costs associated with unevaluated properties are primarily lease acquisition costs. At December 31, 2014, we drilled 3 dry holes and recorded an impairment expense of $37,145, associated with dry holes. There were no pending costs for wells-in-progress at December 31, 2014. During the three months ended March 31, 2015 and March 31, 2014, we recorded an impairment expense of $0 and $0 respectively. There are no unevaluated costs relating to significant development activities. Reclassification of other unproved property costs to evaluated costs is largely dependent on (i) how quickly we drill on the unevaluated property, (ii) the results of such drilling, (iii) if third-parties pay drilling costs to earn a portion of our interest, and (iv) quarterly assessments of such costs for impairments.

Prospect leasing and acquisition normally require one to three years, and the subsequent evaluation normally requires an additional one to three years.

Acquisitions of oil properties

On January 4, 2014, per a Memorandum of Understanding the Company participated and permitted 87.5% working interests as the operator in the Todd Anderson Well #4 at the cost of approximately $27,500 and is responsible for 100% of the all costs associated with the well.

On February 16, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Gerald Norrad Well #3 at the cost of approximately $15,000. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On March 26, 2014 per Memorandum of Understanding the Company sold 37.5% working and royalty interest to two individuals and/or entities in the Millard Willis Well #8 for approximately $12,000 and is responsible for 45% of all the costs associated with the well.

11

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 3 — OIL AND GAS PROPERTIES AND EQUIPMENT (continued).

On March 31, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alvin Parrish Well #1 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 9, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Lester Clark #1 in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 29, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alvin Parrish Well #2 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On June 4, 2014, per a Memorandum of Understanding the Company participated and permitted 50% working interests as the operator in the Millard Willis Well #8 at the cost of $18,500 and is responsible for 55% of the all costs associated with the well.

On June 30, 2014 per Memorandum of Understanding the Company sold 37.5% working and royalty interest to two individuals and/or entities in the Millard Willis Well #9 for $35,000 and is responsible for 45% of all the costs associated with the well.

On August 4, 2014, per a Memorandum of Understanding the Company participated and permitted 50% working interests as the operator in the Millard Willis Well #9 at the cost of $18,500 and is responsible for 55% of the all costs associated with the well.

On August 15, 2014, the Company entered into a 50% interest in an 87.5% working interest lease named the Johnny Ringley Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $1,000. The lease is of approximately 68 acres, located in Cumberland County, Kentucky.

On August 20, 2014, per a Memorandum of Understanding, the Company participated in 20% working interest in the Kyle Padgett Well #7 at the cost of $4,250 and is responsible for 25% of all the costs associated with the well.

On September 8, 2014, the Company entered into an 87.5% working interest lease named the William Warren II Lease between the Company for an initial cost to the Company of $10. The lease is of approximately 640 acres, located in Overton County, Kentucky.

On September 8, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Lester Clark #1 in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On September 26, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the David Wright in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On September 30, 2014 per Memorandum of Understanding the Company sold 50% working and royalty interest to four individuals and/or entities in the William Warren II Well #1 for $35,000 and is responsible for 50% of all the costs associated with the well.

On November 18, 2014 per Memorandum of Understanding the Company sold 50% working and royalty interest to four individuals and/or entities in the Billy Walker Well #1 for $35,000 and is responsible for 50% of all the costs associated with the well.

On January 1, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to two individuals and/or entities in the Millard Willis Well #10 for $35,000 and is responsible for 50% of all the costs associated with the well.

12

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 3 — OIL AND GAS PROPERTIES AND EQUIPMENT (continued).

On January 2, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to two individuals and/or entities in the Johnny Ringley Well #1 for $17,500 and is responsible for 50% of all the costs associated with the well.

On January 31, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to four individuals and/or entities in the William Warren Well #2 for $35,000 and is responsible for 50% of all the costs associated with the well.

On March 31, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to two individuals and/or entities in the Sherrie Miles Well #1 for $7,000 and is responsible for 50% of all the costs associated with the well.

Impairment of Oil Properties

We use the successful efforts-cost accounting method, which requires recognition of an impairment of oil and gas properties when the total capitalized costs (net of related deferred income taxes) exceed a “ceiling” as described in Note 3.

Amortization Rate

Amortization of oil property is calculated quarterly based on the quarter’s production in barrels of oil equivalent (“BOE”) times an amortization rate.  The amortization rate is an amortization base divided by the BOE sum of proved reserves at the end of the quarter and production during the quarter.  The amortization base consists of (i) the capitalized evaluated oil costs at the end of the quarter before recording any impairment at quarter’s end, plus (ii) estimated future development costs for the proved reserves, less (iii) accumulated amortization at the beginning of the quarter.

The following table shows by type of asset the Depreciation, Depletion and Amortization (“DD&A”) expense for three months ended March 31, 2015 and 2014:

	Three months ended March 31,
	2015		2014
Amortization of costs for evaluated oil properties	$	38,435	$	48,422
Depreciation of office equipment, furniture and software		6,565		6,565
Total DD&A expense	$	44,999	$	54,987

The resulting depletion and depreciation costs of $44,999 and $54,987 for the three months ended March 31, 2015 and 2014, respectively, and have been recorded under the caption heading “oil lease operating expense” on our Statement of Operations.

NOTE 4 – LOAN PAYABLE, CONVERTIBLE NOTES PAYABLE, CONVERTIBLE NOTES PAYABLE – RELATED PARTY.

In April 2007 we executed an agreement with Mr. Daniel (Allen) Page whereby we received $250,000 in funds to be advanced through a line of credit which was evidenced by a convertible promissory note.  The note bears interest at a rate of 7.5% per annum and had an original maturity date of April 23, 2008. The initial $250,000 advanced under the credit line is convertible at any time into shares of our common stock at a price per share equal to $0.35.  We pay interest only payments until the maturity date of the convertible note, unless it is converted or prepaid.  Upon maturity or the conversion of the initial $250,000 principal amount and interest due under the note, we also agreed to issue to Mr. Page a four year warrant to purchase shares of common stock with an exercise price of $0.35 per share in an amount equal to 20% of the total shares issued upon conversion of the note.  On September 27, 2007, Mr. Page amended the note to provide an additional $100,000 of working capital to us. Under the terms of the amendment, the additional $100,000 is convertible into shares of our common stock at a price per share equal to $0.18. As consideration for this increase of availability under the credit line, at such time as the note matures or he converts the additional $100,000 into common stock, we agreed to issue him a warrant to purchase shares of common stock equal to 20% of the total shares to be issued upon the conversion of that portion of the note with an exercise price of $0.18 per share.  On May 1, 2009 we entered into a second amendment of the note to provide for an additional $50,000 of working capital to us, bringing the total amount available under the credit line to $400,000. Under the terms of the amendment, the additional $50,000 is convertible into shares of our common stock at a price per share equal to $0.12. As consideration for this extension, upon maturity of the note or at such time as he converts the note we agreed to issue him a warrant to purchase shares of common stock equal to 20% of the total share amount issued upon conversion of the note, with an exercise price of $0.12 per share, solely as it relates to this additional $50,000.

13

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 4 – LOAN PAYABLE, CONVERTIBLE NOTES PAYABLE, CONVERTIBLE NOTES PAYABLE – RELATED PARTY (continued).

On December 8, 2009 Mr. Page extended the due date of the note to June 30, 2010.  The warrants we will issue Mr. Page will expire four years from the date of issuance, which shall be deemed to be on the earlier of (i) the maturity date of the note; (ii) the date on which the funds are advanced in full and owing by us; or (iii) the date on which we elect to pay off the note in full during the term.  We agreed to register for resale the shares underlying the convertible note and warrants, but we have not filed the required registration statement. On June 29, 2010, Mr. Page extended the due date of the note to December 31, 2010. Effective December 13, 2010, the Company entered into a Fifth Amendment to the Convertible Line of Credit Note with Mr. Daniel (Allen) Page pursuant to which he extended the due date of all amounts due under the Convertible Line of Credit from December 31, 2011. The Convertible Line of Credit is now due on demand. In April 2012, the Company entered into a Security Agreement with Mr. Page pursuant to which it granted him a security interest in all of the Company’s assets as collateral for the amounts due under the Convertible Line of Credit. Although this line of credit has matured, Mr. Daniel (Allen) Page has not demanded payment on this credit line to date.

At March 31, 2015 and December 31, 2014, we owed Mr. Daniel (Allen) Page $170,000 and $170,000, respectively of principal and approximately $6,358 and $3,218, respectively of accrued but unpaid interest under this credit line. Mr. Daniel (Allen) Page, a principal shareholder of our Company, is the father of Mr. Ken Page, currently our sole officer and a member of our Board of Directors. We have also entered into a number of joint ventures with Mr. Daniel (Allen) Page. See Note 6- Related Party Transactions.

Convertible notes payable and loans payable are summarized as follows:

	March 31, 2015		December 31, 2014
Convertible line of credit note payable to a related party with an interest rate of 7.5% per annum, due December 31, 2013		170,000		170,000
	$	170,000	$	170,000

NOTE 5 — STOCKHOLDERS’ DEFICIT.

Stock Options

On March 22, 2004 our Board of Directors adopted, subject to stockholder approval, the 2004 Stock Incentive Plan (the “2004 Plan”). The 2004 Plan was approved by our stockholder in May 2004.  No award could be granted under the 2004 Plan subsequent to the 10th anniversary of the date on which the plan was approved by our stockholders. The number of shares of our common stock available for issuance under the 2004 Plan was 3,500,000.  

On September 29, 2009 our Board of Directors adopted our 2009 Equity Compensation Plan (the “2009 Plan”). The plan authorizes the grant of (i) options which qualify as incentive stock options under Section 422(b) of the Internal Revenue Code of 1986, as amended, (ii) non-qualified options which do not qualify as incentive stock options, (iii) awards of our common stock (iv) and rights to make direct purchases of our common stock which may be subject to certain restrictions. We have reserved 4,800,000 shares of our common stock for issuance upon grants made under the plan.  

In May 2014, this employment agreement was amended to reduce the monthly salary to be $3,500 a month and the Company opting to pay health insurance in the amount of $524.02. In addition, on June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share. The Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 175%, risk free interest rate of 2.0%, and expected life of 4.5 years.

On June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share. The Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 234%, risk free interest rate of 1.64%, and expected life of 4.5 years.

14

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 5 — STOCKHOLDERS’ DEFICIT. (continued).

Compensation based stock option and warrant activity for warrants and qualified and unqualified stock options are summarized as follows:

	Shares			Weighted Average Exercise Price
Outstanding at December 31, 2013		3,393,000		$	0.31
Granted		1,560,000			.16
Exercised		-			.00
Expired or cancelled		(1,738,000	)		.00
Outstanding at December 31, 2014		3,215,000		$	.31
Granted		-			-
Exercised		-			-
Expired or cancelled		-			-
Outstanding at March 31, 2015		3,215,000		$	.26

NOTE 6 –RELATED PARTY TRANSACTIONS.

The Company entered into a one year employment arrangement with its CEO in September 2007, with automatic annual renewals. The employment arrangement required an annual salary of $40,000 and a monthly expense allowance of $1,000, with 3,000,000 stock options issued. These stock options vest from March 2008 to September 2008 and have a $0.20 exercise price for three years. In September 2009, this employment agreement was amended to reduce the monthly salary to be $4,167.67 a month and an additional 120,000 options were issued with an exercise price of $0.25, vesting 10,000 options monthly commencing in September 2009. On December 14, 2010, our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,500,000 shares of our common stock at an exercise price of $0.30 per share. The options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 1.64%, annual volatility of 407%, risk free interest rate of 0%, and expected life of 4.5 years. In July 2013 we increased Mr. Page's compensation to $46,000 annually under the terms of an oral agreement. We also provided Mr. Page with the use of company-owned vehicles as an additional compensation.

During 2012, Mr. Ken Page forgave accrued salary due in the amount of $85,076, which had been accrued pursuant to the terms of his employment agreement. Such monies have been recorded as a contribution to capital. 

In May 2014, this employment agreement was amended to reduce the monthly salary to be $3,500 a month and the Company opting to pay health insurance in the amount of $524.02. In addition, on June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share. The Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 175%, risk free interest rate of 2.0%, and expected life of 4.5 years. The fair value of these options was determined to be $313,192, which is being amortized over the five year vesting period.

On February 16, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Gerald Norrad Well #3 at the cost of approximately $15,000. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On March 31, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alan Parrish Well #1 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 9, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Lester Clark #1 in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

15

TN-K ENERGY GROUP INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

as of March 31, 2015 and December 31, 2014 and three months ended March 31, 2015 and 2014

NOTE 6 –RELATED PARTY TRANSACTIONS. (continued).

On May 29, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alan Parrish Well #2 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On August 15, 2014, the Company entered into a 50% interest in an 87.5% working interest lease named the Johnny Ringley Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $1,000. The lease is of approximately 68 acres, located in Cumberland County, Kentucky.

On August 21, 2014, we entered into an agreement with Mr. Page pursuant to which certain terms of his Employment Agreement were amended at his request in an effort to assist our company during development of our new business. Under Amendment No. 2 to Mr. Page’s Employment Agreement, his base salary was reduced from $46,000 annually to $42,000 and we agreed to pay his health insurance premiums initially at the rate of $524 per month, which such amount may be increased or decreased upon a change in cost of such insurance based upon a subsequent policy providing identical coverage. This amendment memorialized an oral agreement between parties entered into in May 2014.

On September 26, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the David Wright in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

At March 31, 2015 and December 31, 2014 we owed Mr. Page $170,000 and $170,000, respectively of principal and approximately $6,358 and $3,218, respectively of accrued but unpaid interest under this credit line. At March 31, 2015 and December 31, 2014, we owed Mr. Page $57,366 and $51,768, respectively of accrued consulting expenses.

NOTE 7 — COMMITMENTS AND CONTINGENCIES.

The Company may be subject to various possible contingencies, which are derived primarily from interpretations of federal and state laws and regulations affecting the oil and gas industry. Although management believes it has complied with the various laws and regulations, new rulings and interpretations may require the Company to make future adjustments.

The Company continually evaluates its leasehold interests, therefore certain leases may be abandoned by the Company in the normal course of business.

The Company has been involved in litigation from time to time as a result of the failure to make payments on certain of its past due debts. Overall management believes the net recorded value of its past due payables adequately cover the total financial exposure of the past due payables.

16

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion of our financial condition and results of operation for the First Quarter 2015 and the First Quarter 2014 should be read in conjunction with the unaudited financial statements and the notes to those statements that are included elsewhere in this report. Our discussion includes forward-looking statements based upon current expectations that involve risks and uncertainties, such as our plans, objectives, expectations and intentions. Actual results and the timing of events could differ materially from those anticipated in these forward-looking statements as a result of a number of factors, including those set forth under the Item 1A. Risk Factors appearing in our Annual Report on Form 10-K for the year ended December 31, 2014 as previously filed with the Securities and Exchange Commission. We use words such as “anticipate,” “estimate,” “plan,” “project,” “continuing,” “ongoing,” “expect,” “believe,” “intend,” “may,” “will,” “should,” “could,” and similar expressions to identify forward-looking statements.

Overview

We are an independent oil exploration and production company, engaged in acquiring oil leases and exploring and developing crude oil reserves and production in the Appalachian basin. We concentrate our operations in Kentucky and Tennessee primarily in the Murfreesboro, Knox and Wells Creek formations, although we also have assets located in the Granville, Stones River and Sunnybrook formations. All of these formations are primary known producing formations. Our growth strategy is to focus on our operational growth in our core area, to convert our unproved reserves to proved reserves and to continue our acreage acquisitions while maintaining balanced, prudent financial management. In the past three years, we have realized substantial benefits from the sale of concentrations of our reserves, although this is not a focus, we do evaluate from time to time potential sales of our reserves for strategic and capital reasons.

Our Operations

Our operations are divided between leases in which we have a participation interest/overriding royalty interest and leases in which we are the operator. Interests owned by participation leases means we have a working or royalty interest in a property that is operated or maintained by another interest owner under an agreement. Overriding royalty interest means we assisted in the negotiations between the buyers and sellers of lease sales which we retained a royalty interest, and are provided options for additional participation of future wells. For participation leases, we receive payments for our oil sales from the operator and we are billed by the operator for a percentage of joint expenses relative to the costs of drilling and transporting the oil from the wells to the sales point. Since 2010, we have entered into a number of participation leases and working interest leases with third parties in which Mr. Daniel (Allen) Page, a related party, is also a party.

For drilling operations on leases in which we are the operator, we hire third parties to provide contract drilling services to us on an as needed basis. We have been able to reduce or eliminate our financial exposure in the initial drilling in our projects by creating joint venture arrangements that provide for others to pay for all or a disproportionate share of the initial drilling costs in exchange for a working or royalty interest in the well. We expect to continue to use these types of relationships to partially or completely fund initial drilling of future wells.

During 2015, we have continued to expand our acreage position in our core area, focusing on acreage we will operate. In addition to the challenges faced by small independent oil and gas companies, we continue to face a number of challenges in executing our business model which are particular to our company. Our revenues increased 812% for the First Quarter 2015 from the First Quarter 2014.

At March 31, 2015 and December 31, 2014, our balance sheet includes approximately $3.99 million and $3.93 million of obligations, a substantial portion of which relates to the prior business of our company before those operations were discontinued in 2005. Other than the secured credit line due a related party, none of the remaining obligations represent secured debt, although a number of the creditors have obtained judgments against our company. We do not have the resources to satisfy these obligations. If one or more of these judgment creditors should seek to enforce the judgment, our ability to continue our operations as they are presently conducted is in jeopardy.

We also face the challenge of limited personnel and diversion of our management’s time and attention. In 2011 we hired a part-time accountant and in 2014 we hired a full-time project coordinator, but as our company continues to grow, we need to hire additional staff to handle the increasing needs of our company, including from an administrative standpoint, and we need to invest in internal systems to ensure that our financial statements are properly prepared. Lastly, we need to raise additional capital to fund these necessary infrastructure increases and our continued expansion, as well as to provide adequate funds to satisfy our obligations. We have been relying on funding available to us under a secured line of credit extended by Mr. Daniel (Allen) Page, a related party, which matured in December 2011 and is due on demand. In April 2012 we granted Mr. Daniel (Allen) Page a security interest in all of our assets as collateral for this obligation. At March 31, 2015, $170,000 is outstanding under this facility which is the maximum amount available as the credit line matured in December 2011. The amount is convertible into shares of our common stock at various prices, but there are no assurances the holder will convert the obligation.

17

We do not have any external sources of liquidity. Our working capital is not sufficient to fund our operations and pay our obligations, many of which are past due, and may impede our ability to further grow our company. Although we need to raise additional working capital, we do not have any commitments for capital from third parties. Given the small size of our company, the quotation of our stock in the over-the-counter market and the significant liabilities on our balance sheet, we expect to encounter significant obstacles in raising equity or debit capital. If we are unable to access capital as needed, our ability to grow our company is in jeopardy and absent a significant increase in our revenues we may be unable to continue as a going concern.

Going Concern

For the three months ended March 31, 2015, we reported a net loss of $77,329 compared to a net loss of $98,852, respectively, for the three months ended March 31, 2014. At March 31, 2015 we have an accumulated deficit of $16.9 million. The report of our independent registered public accounting firm on our financial statements for the year ended December 31, 2013 contains an explanatory paragraph regarding our ability to continue as a going concern based upon our operating losses and need to raise additional capital. These factors, among others, raise substantial doubt about our ability to continue as a going concern. Our financial statements do not include any adjustments that might result from the outcome of this uncertainty. There are no assurances we will be successful in our efforts to increase our revenues and report profitable operations or to continue as a going concern, in which event investors would lose their entire investment in our company.

Results of Operations

Our revenues can include revenues from oil sales generated both from wells in which we are the operator as well as those in which we have a working interest, as well as from non-recurring well services and sales of interest in oil and gas leases to third parties and finder’s fees for the culmination of the sale of oil well interests between third parties. While oil sales revenues are constant from period to period, revenues from sales of oil and gas leases and finder’s fees are transaction based on one-time for the particular transaction. As such, we may not report revenues from those sources in all periods. Oil sales revenues decreased 79% in the First Quarter 2015 compared to the First Quarter 2014, due to low production income as the weather conditions were unfavorable for pumping during the period and the lower than industry average sales price per unit of oil extracted. During the First Quarters 2015 and 2014, the average sales price (including transfers) per unit of oil extracted from wells drilled by us was approximately $95.14 and approximately $45.35 respectively, for the three months ended March 31, 2015 and 2014.

During the First Quarter 2015 compared to the First Quarter 2014, the average number of barrels sold was approximately 730 and 928, respectively, for the three months ended March 31, 2015 and 2014. Revenues from the sale of oil and gas leases for the First Quarter 2015 was $94,500 as compared to $0 the First Quarter 2014.

Our total operating expenses during the First Quarter 2015 increased approximately 76% from the comparative period in 2014. The increase is directly related to the recording of annual accounting fees, the non-cash stock compensation expense incurred with the issuance of stock options and the cost of oil and gas leases sold. Oil lease operating expenses, which include our portion of the cost of contract drillers, and other expenses associated with the drilling operations and depletion expense, were 1400% of oil sales revenues for the three months ended March 31, 2015, respectively, which is attributable to our lower than usual amount of production and increased participation in drilling activities.

Cost of oil and gas leases sold were $29,258 for First Quarter 2015 and $0 for the First Quarter 2014.

Our sales, general and administrative expenses increased approximately 111% during the First Quarter 2015 from the comparative period in 2014. The increase is directly related to the recording of annual accounting fees, the non-cash stock compensation expense incurred with the issuance of stock options. We anticipate our operating expenses will increase during the balance of 2015 which will be reflective of our increased operations. We are not able at this time, however, to quantify the amount of the expected increase.

During First Quarter 2015 and 2014, we did not recognized any impairment expense.

 Our interest expense during First Quarter 2015 and 2014 was $3,544 and $3,618. The decreased is the result of the decreased amounts outstanding principal under the line of credit provided by a related party which provides funding for our operations.

Liquidity and Capital Resources

Liquidity is the ability of a company to generate sufficient cash to satisfy its needs for cash. At March 31, 2015, we had a working capital deficit of $3,502,246 as compared to a working capital deficit of $3,433,981 at December 31, 2014. Our current assets at March 31, 2015 include accounts receivable and receivables from the sale of a partial interest in oil wells of $52,688 compared to $17,572 at December 31, 2014, respectively, which are due 30 days from invoicing. Our current liabilities includes approximately $3.5 million of accounts payable and accrued expenses, as of March 31, 2015, compared to $3.43 million of accounts payable and accrued expenses, as of March 31, 2014. Included in our accrued expenses, as of March 31, 2015 is approximately $57,366 of consulting expenses due a related party, and approximately $154,000 of accrued taxes. In addition, at March 31, 2015 we owe a related party $170,000 of principal and $6,358, of accrued interest under a secured line of credit.

18

Net cash provided by operating activities for the First Quarter 2015 was $28,668 as compared to the net cash used in the First Quarter 2014 was ($59,070). During the First Quarter 2015 and 2014, $38,797 and $0 was used in equity based compensation, respectively. Net cash used in investing activities in the First Quarter 2015 reflects the purchase of oil and gas leases and sales of oil and gas rights, as compared to net cash used in investment activities in First Quarter 2014 reflects the purchase of oil and gas leases and fixed assets. There was no net cash used in financing activities in the First Quarter 2015 as compared to the repayment of notes payable for the First Quarter of 2014.

Recent Accounting Pronouncements

All new accounting pronouncements issued but not yet effective have been evaluated and determined to be not applicable or immaterial to the financial statement of the Company.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Not applicable for a smaller reporting company.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures. We maintain “disclosure controls and procedures” as such term is defined in Rule 13a-15(e) under the Securities Exchange Act of 1934. In designing and evaluating our disclosure controls and procedures, our management recognized that disclosure controls and procedures, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of disclosure controls and procedures are met. Additionally, in designing disclosure controls and procedures, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible disclosure controls and procedures. The design of any disclosure controls and procedures also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Based on his evaluation as of the end of the period covered by this report, our Chief Executive Officer who also serves as our principal financial and accounting officer has concluded that our disclosure controls and procedures were not effective such that the information relating to our company, required to be disclosed in our Securities and Exchange Commission reports (i) is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms and (ii) is accumulated and communicated to our management, including our Chief Executive Officer, to allow timely decisions regarding required disclosure as a result of continuing material weaknesses.

The material weakness identified for the period ended December 31, 2014 were related to insufficient personnel and accounting resources are were adequate to allow sufficient time to (i) perform a review of the consolidation and supporting financial statement disclosure schedules independent of the preparer (ii) adequately prepare for our quarterly reviews and annual audit and (iii) research all applicable accounting pronouncements as they relate to our financial statements and underlying disclosures. These material weaknesses have not been remediated and continued through the end of the First Quarter 2015. Due to these material weaknesses, in preparing our financial statements for the period ended March 31, 2015 we performed additional analysis and other post close procedures to ensure that such financial statements were stated fairly in all material respects in accordance with U.S. generally accepted accounting principles. Until such time as we remediate these material weaknesses, we expect that the material weaknesses in our disclosure controls and procedures will continue.

Changes in Internal Control over Financial Reporting. There have been no changes in our internal control over financial reporting during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings.

None.

Item 1A. Risk Factors.

Not applicable for a smaller reporting company.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

None.

19

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

Not applicable to our company’s operations.

Item 5. Other Information.

None.

Item 6. Exhibits.

No.	Description
31.1	Rule 13a-14(a)/ 15d-14(a) Certification of Chief Executive Officer *
31.2	Rule 13a-14(a)/ 15d-14(a) Certification of principal financial and accounting officer *
32.1	Section 1350 Certification of Chief Executive Officer and principal financial and accounting officer *

101.INS	XBRL INSTANCE DOCUMENT **
101.SCH	XBRL TAXONOMY EXTENSION SCHEMA **
101.CAL	XBRL TAXONOMY EXTENSION CALCULATION LINKBASE **
101.DEF	XBRL TAXONOMY EXTENSION DEFINITION LINKBASE **
101.LAB	XBRL TAXONOMY EXTENSION LABEL LINKBASE **
101.PRE	XBRL TAXONOMY EXTENSION PRESENTATION LINKBASE **

* filed herewith

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	TN-K ENERGY GROUP INC.
August 7, 2015	By: /s/ Ken Page
	Ken Page, Chief Executive Officer, principal financial and accounting officer

20

EX-31.1

EXHIBIT 31.1

Rule 13a-14(a)/15d-14(a) Certification

I, Ken Page, certify that:

1. I have reviewed this report on Form 10-Q for the period ended March 31, 2015 of TN-K Energy Group Inc.;

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 financial 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 known to us by others within those entities, particularly during the period in which this report is being prepared;
(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant's other certifying officer(s) 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 19, 2015			/s/Ken Page Ken Page, Chief Executive Officer, principal executive officer

EX-31.2

EXHIBIT 31.2

Rule 13a-14(a)/15d-14(a) Certification

I, Ken Page, certify that:

1. I have reviewed this report on Form 10-Q for the period ended March 31, 2015 of TN-K Energy Group Inc.;

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 financial 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 known to us by others within those entities, particularly during the period in which this report is being prepared;
(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant's other certifying officer(s) 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 19, 2015			/s/Ken Page Ken Page, principal financial and accounting officer

EX-32.1

EXHIBIT 32.1

Section 1350 Certification

In connection with the Quarterly Report of TN-K Energy Group Inc. (the “Company”) on Form 10-Q for the period ended March 31, 2015 as filed with the Securities and Exchange Commission (the “Report”), I, Ken Page, Chief Executive Officer and principal financial and accounting officer, of the Company, certify, pursuant to 18 U.S.C. SS. 1350, as adopted pursuant to SS. 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, and

2.	The information contained in the Report fairly presents, in all material respects, the financial conditions and results of operations of the Company.
Dated: August 19, 2015		/s/Ken Page Ken Page, Chief Executive Officer, principal executive officer, principal financial and accounting officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

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Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - USD ($)		1 Months Ended
	Sep. 27, 2007	Dec. 31, 2009	May. 30, 2009	Apr. 30, 2007	Mar. 31, 2015	Dec. 31, 2014
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) [Line Items]
Proceeds from Convertible Debt	$ 100,000		$ 50,000	$ 250,000
Debt Instrument, Interest Rate, Stated Percentage				7.50%
Term of Warrants Issued		4 years		4 years
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per share)	$ 0.18		$ 0.12	$ 0.35
Percentage of Shares Called by Warrants	20.00%		20.00%	20.00%
Line of Credit Facility, Maximum Borrowing Capacity			$ 400,000
Notes Payable, Related Parties, Current					$ 170,000	$ 170,000
Convertible Promissory Note [Member]
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) [Line Items]
Debt Instrument, Convertible, Conversion Price (in Dollars per share)	$ 0.18		$ 0.12	$ 0.35
Mr. Daniel (Allen) Page [Member]
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) [Line Items]
Notes Payable, Related Parties, Current					170,000	170,000
Interest Payable, Current					$ 6,358	$ 3,218

XML

Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party

3 Months Ended

Mar. 31, 2015

Disclosure Text Block [Abstract]

Long-term Debt [Text Block]

NOTE 4 – LOAN PAYABLE, CONVERTIBLE NOTES PAYABLE, CONVERTIBLE NOTES PAYABLE – RELATED PARTY.

In April 2007 we executed an agreement with Mr. Daniel (Allen) Page whereby we received $250,000 in funds to be advanced through a line of credit which was evidenced by a convertible promissory note.  The note bears interest at a rate of 7.5% per annum and had an original maturity date of April 23, 2008. The initial $250,000 advanced under the credit line is convertible at any time into shares of our common stock at a price per share equal to $0.35.  We pay interest only payments until the maturity date of the convertible note, unless it is converted or prepaid.  Upon maturity or the conversion of the initial $250,000 principal amount and interest due under the note, we also agreed to issue to Mr. Page a four year warrant to purchase shares of common stock with an exercise price of $0.35 per share in an amount equal to 20% of the total shares issued upon conversion of the note.  On September 27, 2007, Mr. Page amended the note to provide an additional $100,000 of working capital to us. Under the terms of the amendment, the additional $100,000 is convertible into shares of our common stock at a price per share equal to $0.18. As consideration for this increase of availability under the credit line, at such time as the note matures or he converts the additional $100,000 into common stock, we agreed to issue him a warrant to purchase shares of common stock equal to 20% of the total shares to be issued upon the conversion of that portion of the note with an exercise price of $0.18 per share.  On May 1, 2009 we entered into a second amendment of the note to provide for an additional $50,000 of working capital to us, bringing the total amount available under the credit line to $400,000. Under the terms of the amendment, the additional $50,000 is convertible into shares of our common stock at a price per share equal to $0.12. As consideration for this extension, upon maturity of the note or at such time as he converts the note we agreed to issue him a warrant to purchase shares of common stock equal to 20% of the total share amount issued upon conversion of the note, with an exercise price of $0.12 per share, solely as it relates to this additional $50,000.

On December 8, 2009 Mr. Page extended the due date of the note to June 30, 2010.  The warrants we will issue Mr. Page will expire four years from the date of issuance, which shall be deemed to be on the earlier of (i) the maturity date of the note; (ii) the date on which the funds are advanced in full and owing by us; or (iii) the date on which we elect to pay off the note in full during the term.  We agreed to register for resale the shares underlying the convertible note and warrants, but we have not filed the required registration statement. On June 29, 2010, Mr. Page extended the due date of the note to December 31, 2010. Effective December 13, 2010, the Company entered into a Fifth Amendment to the Convertible Line of Credit Note with Mr. Daniel (Allen) Page pursuant to which he extended the due date of all amounts due under the Convertible Line of Credit from December 31, 2011. The Convertible Line of Credit is now due on demand. In April 2012, the Company entered into a Security Agreement with Mr. Page pursuant to which it granted him a security interest in all of the Company’s assets as collateral for the amounts due under the Convertible Line of Credit. Although this line of credit has matured, Mr. Daniel (Allen) Page has not demanded payment on this credit line to date.

At March 31, 2015 and December 31, 2014, we owed Mr. Daniel (Allen) Page $170,000 and $170,000, respectively of principal and approximately $6,358 and $3,218, respectively of accrued but unpaid interest under this credit line. Mr. Daniel (Allen) Page, a principal shareholder of our Company, is the father of Mr. Ken Page, currently our sole officer and a member of our Board of Directors. We have also entered into a number of joint ventures with Mr. Daniel (Allen) Page. See Note 6- Related Party Transactions.

Convertible notes payable and loans payable are summarized as follows:

	March 31, 2015		December 31, 2014
Convertible line of credit note payable to a related party with an interest rate of 7.5% per annum, due December 31, 2013		170,000		170,000
	$	170,000	$	170,000

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Note 5 - Stockholders' Deficit (Details) - Activity for Warrants and Qualified and Unqualified Stock Options - $ / shares	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Activity for Warrants and Qualified and Unqualified Stock Options [Abstract]
Shares	3,215,000	3,215,000
Weighted Average Exercise Price	$ 0.26	$ 0.31
Shares, Granted	0	1,560,000
Weighted Average Exercise Price, Granted	$ 0	$ 0.16
Shares, Exercised	0	0
Weighted Average Exercise Price, Exercised	$ 0	$ 0.00
Shares, Expired or cancelled	0	(1,738,000)
Weighted Average Exercise Price, Expired or cancelled	$ 0	$ 0.00

XML

Note 5 - Stockholders' Deficit (Details) - USD ($)			1 Months Ended					3 Months Ended	12 Months Ended
	Jun. 27, 2014	Dec. 14, 2010	Jun. 27, 2014	May. 31, 2014	Sep. 30, 2009	Sep. 30, 2007	May. 31, 2004	Mar. 31, 2015	Dec. 31, 2014	Jul. 31, 2013	Sep. 29, 2009
Note 5 - Stockholders' Deficit (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in Shares)								0	1,560,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price (in Dollars per share)								$ 0	$ 0.16
The 2004 Plan [Member]
Note 5 - Stockholders' Deficit (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Grants under the Plan (in Shares)							0
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant (in Shares)							3,500,000
The 2009 Plan [Member]
Note 5 - Stockholders' Deficit (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant (in Shares)											4,800,000
Mr. Ken Page [Member]
Note 5 - Stockholders' Deficit (Details) [Line Items]
Employment Arrangement, Monthly Salary (in Dollars)				$ 3,500	$ 4,167.67	$ 40,000				$ 46,000
Related Party Transaction, Expenses from Transactions with Related Party (in Dollars)				$ 524.02
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	5 years	5 years	5 years	5 years		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in Shares)	1,560,000	1,500,000	1,560,000	1,560,000	120,000	3,000,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price (in Dollars per share)	$ 0.16	$ 0.30	$ 0.16	$ 0.16	$ 0.25	$ 0.20
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	0.00%	0.00%	0.00%	0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	234.00%	407.00%	175.00%	175.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.64%	1.64%	2.00%	2.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	4 years 6 months	4 years 6 months	4 years 6 months	4 years 6 months

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Note 6 - Related Party Transactions (Details)											1 Months Ended				3 Months Ended	12 Months Ended
	Sep. 26, 2014 USD ($)	Sep. 08, 2014 USD ($)	Aug. 21, 2014 USD ($)	Aug. 15, 2014 USD ($) a	Jun. 27, 2014 $ / shares shares	May. 29, 2014 USD ($)	May. 09, 2014 USD ($)	Mar. 31, 2014 USD ($)	Feb. 16, 2014 USD ($)	Dec. 14, 2010 $ / shares shares	Jun. 27, 2014 $ / shares shares	May. 31, 2014 USD ($) $ / shares shares	Sep. 30, 2009 USD ($) $ / shares shares	Sep. 30, 2007 USD ($) $ / shares shares	Mar. 31, 2015 USD ($) $ / shares shares	Dec. 31, 2014 USD ($) $ / shares shares	Dec. 31, 2012 USD ($)	Dec. 31, 2013 USD ($)	Jul. 31, 2013 USD ($)
Note 6 - Related Party Transactions (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in Shares) | shares															0	1,560,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price (in Dollars per share) | $ / shares															$ 0	$ 0.16
Notes Payable, Related Parties, Current (in Dollars)															$ 170,000	$ 170,000
Gerald Norrad Well #3 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Percent Working Interest in a Well									43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)									$ 15,000
Percent of Costs on a Well									50.00%
Alan Parrish Well #1 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Percent Working Interest in a Well								43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)								$ 16,500
Percent of Costs on a Well								50.00%
Lester Clark #1 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Percent Working Interest in a Well		43.75%					43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)		$ 16,500					$ 16,500
Percent of Costs on a Well		50.00%					50.00%
Alan Parrish Well #2 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Percent Working Interest in a Well						43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)						$ 16,500
Percent of Costs on a Well						50.00%
David Wright [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Percent Working Interest in a Well	43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)	$ 16,500
Percent of Costs on a Well	50.00%
Johnny Ringley Lease [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Percent Interest in Lease				50.00%
Percent Working Interest in Lease				87.50%
Operating Leases, Income Statement, Initial Direct Costs (in Dollars)				$ 1,000
Area of Land (in Acres) | a				68
Mr. Ken Page [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Employment Arrangement, Monthly Salary (in Dollars)												$ 3,500	$ 4,167.67	$ 40,000					$ 46,000
Employment Arrangement, Monthly Expense Allowance (in Dollars)														$ 1,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in Shares) | shares					1,560,000					1,500,000	1,560,000	1,560,000	120,000	3,000,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price (in Dollars per share) | $ / shares					$ 0.16					$ 0.30	$ 0.16	$ 0.16	$ 0.25	$ 0.20
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period					5 years					5 years	5 years	5 years		3 years
Monthly Options Vesting (in Shares) | shares													10,000
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate					1.64%					1.64%	2.00%	2.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate					234.00%					407.00%	175.00%	175.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate					0.00%					0.00%	0.00%	0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term					4 years 6 months					4 years 6 months	4 years 6 months	4 years 6 months
Related Party Transaction, Amounts of Transaction (in Dollars)																	$ 85,076
Related Party Transaction, Expenses from Transactions with Related Party (in Dollars)												$ 524.02
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Grant Date Intrinsic Value (in Dollars per share) | $ / shares											$ 313,192
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period											5 years
Mr. Daniel (Allen) Page [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party (in Dollars)			$ 524
Base Salary (in Dollars)			$ 42,000															$ 46,000
Notes Payable, Related Parties, Current (in Dollars)															170,000	170,000
Interest Payable, Current (in Dollars)															6,358	3,218
Due to Related Parties, Current (in Dollars)															$ 57,366	$ 51,768
Mr. Daniel (Allen) Page [Member] | Gerald Norrad Well #3 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs									50.00%
Mr. Daniel (Allen) Page [Member] | Alan Parrish Well #1 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs								50.00%
Mr. Daniel (Allen) Page [Member] | Lester Clark #1 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs		50.00%					50.00%
Mr. Daniel (Allen) Page [Member] | Alan Parrish Well #2 [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs						50.00%
Mr. Daniel (Allen) Page [Member] | David Wright [Member]
Note 6 - Related Party Transactions (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs	50.00%

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Note 3 - Oil and Gas Properties and Equipment

3 Months Ended

Mar. 31, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment Disclosure [Text Block]

NOTE 3 — OIL AND GAS PROPERTIES AND EQUIPMENT.

Oil and Gas Properties and equipment consisted of the following:

	March 31, 2015			December 31, 2014
Oil and gas properties, successful efforts method
Unevaluated costs, not yet subject to amortization	$	1,212,701		$	1,212,701
Evaluated costs		1,944,669			1,869,537
Asset retirement costs		39,600			39,600
		3,196,970			3,121,839
Well equipment, furniture and software		183,809			183,809
		3,380,779			3,305,648
Less accumulated depreciation, depletion and amortization		(1,707,914	)		(1,662,916	)
Oil and gas property and equipment	$	1,672,865		$	1,642,731

Unevaluated Oil Properties

Costs directly associated with the acquisition and evaluation of unproved properties are excluded from the amortization computation.  The following table shows, by year incurred, the unevaluated oil and gas property costs (net of transfers to evaluated costs and net of sales proceeds) excluded from the amortization computation: 

Year Incurred	Net Costs Incurred
Three months ended March 31, 2015	$	0
Year ended December 31, 2014		(112,704	)
Year ended December 31, 2013		(67,274	)
Year ended December 31, 2012		842,811
Year ended December 31, 2011		(592,569	)
Year ended December 31, 2010		916,532
Year ended December 31, 2009		225,905
	$	1,212,701

Costs associated with unevaluated properties are primarily lease acquisition costs. At December 31, 2014, we drilled 3 dry holes and recorded an impairment expense of $37,145, associated with dry holes. There were no pending costs for wells-in-progress at December 31, 2014. During the three months ended March 31, 2015 and March 31, 2014, we recorded an impairment expense of $0 and $0 respectively. There are no unevaluated costs relating to significant development activities. Reclassification of other unproved property costs to evaluated costs is largely dependent on (i) how quickly we drill on the unevaluated property, (ii) the results of such drilling, (iii) if third-parties pay drilling costs to earn a portion of our interest, and (iv) quarterly assessments of such costs for impairments.

Prospect leasing and acquisition normally require one to three years, and the subsequent evaluation normally requires an additional one to three years.

Acquisitions of oil properties

On January 4, 2014, per a Memorandum of Understanding the Company participated and permitted 87.5% working interests as the operator in the Todd Anderson Well #4 at the cost of approximately $27,500 and is responsible for 100% of the all costs associated with the well.

On February 16, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Gerald Norrad Well #3 at the cost of approximately $15,000. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On March 26, 2014 per Memorandum of Understanding the Company sold 37.5% working and royalty interest to two individuals and/or entities in the Millard Willis Well #8 for approximately $12,000 and is responsible for 45% of all the costs associated with the well.

On March 31, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alvin Parrish Well #1 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 9, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Lester Clark #1 in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 29, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alvin Parrish Well #2 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On June 4, 2014, per a Memorandum of Understanding the Company participated and permitted 50% working interests as the operator in the Millard Willis Well #8 at the cost of $18,500 and is responsible for 55% of the all costs associated with the well.

On June 30, 2014 per Memorandum of Understanding the Company sold 37.5% working and royalty interest to two individuals and/or entities in the Millard Willis Well #9 for $35,000 and is responsible for 45% of all the costs associated with the well.

On August 4, 2014, per a Memorandum of Understanding the Company participated and permitted 50% working interests as the operator in the Millard Willis Well #9 at the cost of $18,500 and is responsible for 55% of the all costs associated with the well.

On August 15, 2014, the Company entered into a 50% interest in an 87.5% working interest lease named the Johnny Ringley Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $1,000. The lease is of approximately 68 acres, located in Cumberland County, Kentucky.

On August 20, 2014, per a Memorandum of Understanding, the Company participated in 20% working interest in the Kyle Padgett Well #7 at the cost of $4,250 and is responsible for 25% of all the costs associated with the well.

On September 8, 2014, the Company entered into an 87.5% working interest lease named the William Warren II Lease between the Company for an initial cost to the Company of $10. The lease is of approximately 640 acres, located in Overton County, Kentucky.

On September 8, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Lester Clark #1 in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On September 26, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the David Wright in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On September 30, 2014 per Memorandum of Understanding the Company sold 50% working and royalty interest to four individuals and/or entities in the William Warren II Well #1 for $35,000 and is responsible for 50% of all the costs associated with the well.

On November 18, 2014 per Memorandum of Understanding the Company sold 50% working and royalty interest to four individuals and/or entities in the Billy Walker Well #1 for $35,000 and is responsible for 50% of all the costs associated with the well.

On January 1, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to two individuals and/or entities in the Millard Willis Well #10 for $35,000 and is responsible for 50% of all the costs associated with the well.

On January 2, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to two individuals and/or entities in the Johnny Ringley Well #1 for $17,500 and is responsible for 50% of all the costs associated with the well.

On January 31, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to four individuals and/or entities in the William Warren Well #2 for $35,000 and is responsible for 50% of all the costs associated with the well.

On March 31, 2015 per Memorandum of Understanding the Company sold 50% working and royalty interest to two individuals and/or entities in the Sherrie Miles Well #1 for $7,000 and is responsible for 50% of all the costs associated with the well.

Impairment of Oil Properties

We use the successful efforts-cost accounting method, which requires recognition of an impairment of oil and gas properties when the total capitalized costs (net of related deferred income taxes) exceed a “ceiling” as described in Note 3.

Amortization Rate

Amortization of oil property is calculated quarterly based on the quarter’s production in barrels of oil equivalent (“BOE”) times an amortization rate.  The amortization rate is an amortization base divided by the BOE sum of proved reserves at the end of the quarter and production during the quarter.  The amortization base consists of (i) the capitalized evaluated oil costs at the end of the quarter before recording any impairment at quarter’s end, plus (ii) estimated future development costs for the proved reserves, less (iii) accumulated amortization at the beginning of the quarter.

The following table shows by type of asset the Depreciation, Depletion and Amortization (“DD&A”) expense for three months ended March 31, 2015 and 2014:

	Three months ended March 31,
	2015		2014
Amortization of costs for evaluated oil properties	$	38,435	$	48,422
Depreciation of office equipment, furniture and software		6,565		6,565
Total DD&A expense	$	44,999	$	54,987

The resulting depletion and depreciation costs of $44,999 and $54,987 for the three months ended March 31, 2015 and 2014, respectively, and have been recorded under the caption heading “oil lease operating expense” on our Statement of Operations.

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Condensed Balance Sheets (Current Period Unaudited) - USD ($)	Mar. 31, 2015	Dec. 31, 2014
CURRENT ASSETS:
Cash and cash equivalents	$ 111,366	$ 157,830
Accounts receivable	52,688	17,572
TOTAL CURRENT ASSETS	164,054	175,402
OIL AND GAS PROPERTY (Successful efforts method), at cost	1,583,583	1,546,885
EQUIPMENT, net of depreciation	89,282	95,846
OTHER ASSETS	42,000	42,000
TOTAL ASSETS	1,878,919	1,860,133
CURRENT LIABILITIES:
Accounts payable	2,931,105	2,888,728
Accrued expenses	565,195	550,655
Convertible note payable - related party	170,000	170,000
TOTAL CURRENT LIABILITIES	3,666,300	3,609,383
LONG TERM LIABILITIES:
Asset retirement obligation	33,640	33,240
Deferred income taxes payable	285,097	285,097
TOTAL LONG TERM LIABILITIES	318,737	318,337
STOCKHOLDERS' DEFICIT:
Preferred stock, $.01 par value, 5,000,000 shares authorized, none issued, and outstanding	0	0
Common stock, $.03 par value, 100,000,000 shares authorized, 38,176,085 and 38,176,085 issued and outstanding, respectively	1,145,282	1,145,282
Additional Paid - In Capital	13,640,113	13,601,316
Accumulated deficit	(16,891,514)	(16,814,185)
TOTAL STOCKHOLDERS' DEFICIT	(2,106,119)	(2,067,587)
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT	$ 1,878,919	$ 1,860,133

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Note 1 - Organization and Basis of Presentation

3 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies [Text Block]

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION.

Organization

TN-K Energy Group Inc. is an independent energy company engaged in the acquisition and development of crude oil reserves and production in the Appalachian Basin and to conduct directly and indirectly through third parties, operations on the properties.  In these Notes, the terms “Company”, “TN-K”, “we”, “us”, “our” and terms of similar import refer to TN-K Energy Group Inc.

Basis of Presentation

The accompanying unaudited consolidated financial statements have been prepared in accordance with generally accepted accounting principles for interim financial information. Accordingly, they do not include all of the information and the footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments, consisting only of normal recurring accruals, considered necessary for a fair presentation have been included. Operating results for the three months ended March 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2015. The accompanying consolidated financial statements should be read in conjunction with the Company’s form 10-K for the fiscal year ended December 31, 2014 which was filed on June 15, 2015.

Going Concern

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern.  Going concern contemplates the realization of assets and the satisfaction of liabilities in the normal course of business over a reasonable length of time. The Company has incurred losses since inception and has negative cash flows from operations and a substantial portion of the debt is in default and has a stockholders’ deficit of $(2,106,119) as of March 31, 2015. The future of the Company is dependent upon its ability to obtain additional equity and/or debt financing and upon the continued development of commercially viable producing wells at levels which significantly increase the Company’s revenues and net income. Management cannot assure that the Company will be able to secure such financing or obtain financing on terms beneficial to the Company or that the Company will be able to significantly increase its revenues and net income. Failure to achieve these goals may result in the Company’s inability to continue as a going concern and the impairment of the recorded long-lived assets.

These financial statements do not include any adjustments relating to the recoverability and classifications of recorded assets, or the amounts and classification of liabilities that might be necessary in the event the Company cannot continue in existence.

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Note 3 - Oil and Gas Properties and Equipment (Details) - Oil and Gas Properties and Equipment - USD ($)	Mar. 31, 2015	Dec. 31, 2014
Oil and gas properties, successful efforts method
Unevaluated costs, not yet subject to amortization	$ 1,212,701	$ 1,212,701
Evaluated costs	1,944,669	1,869,537
Asset retirement costs	39,600	39,600
	3,196,970	3,121,839
Well equipment, furniture and software	183,809	183,809
	3,380,779	3,305,648
Less accumulated depreciation, depletion and amortization	(1,707,914)	(1,662,916)
Oil and gas property and equipment	$ 1,672,865	$ 1,642,731

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Note 3 - Oil and Gas Properties and Equipment (Details) - Depreciation, Depletion, and Amortization ("DD&A") Expense - USD ($)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Note 3 - Oil and Gas Properties and Equipment (Details) - Depreciation, Depletion, and Amortization ("DD&A") Expense [Line Items]
Depreciation, depletion, and amortization	$ 44,999	$ 54,987
Oil and Gas Properties [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) - Depreciation, Depletion, and Amortization ("DD&A") Expense [Line Items]
Depreciation, depletion, and amortization	38,435	48,422
Furniture and Fixtures [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) - Depreciation, Depletion, and Amortization ("DD&A") Expense [Line Items]
Depreciation, depletion, and amortization	$ 6,565	$ 6,565

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Note 2 - Summary of Signifcant Accounting Policies

3 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

Significant Accounting Policies [Text Block]

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES.

Cash and Cash Equivalents — For purposes of reporting cash flows, we consider cash equivalents to be all highly liquid investments with a maturity of three months or less at the time of purchase. The Company typically has cash in banks in excess of federally insured amounts.

Use of Estimates - Our financial statements are prepared in accordance with GAAP.  Preparation in accordance with GAAP requires us to (1) adopt accounting policies within accounting rules set by the Financial Accounting Standards Board (“FASB”) and by the United States Securities and Exchange Commission (“SEC”) and (2) make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and other disclosed amounts.  This Note describes our significant accounting policies.  Our management believes the major estimates and assumptions impacting our financial statements are the following:

• estimates of proven (i.e., reasonably certain) oil and gas reserve quantities, which affect the calculations of amortization and impairment of capitalized costs of oil and gas properties;

• estimates of the fair value of oil and gas properties we own, particularly properties that we have not yet explored, or fully explored, by drilling and completing wells;

• estimates of the fair value of stock options at date of grant;

• estimates as to the future realization of deferred income tax assets; and

• the assumption required by GAAP that proved reserves and generally proved reserve value for measuring capitalized cost impairment be based on the prices of oil and gas at the end of the reporting period.

The estimated fair values of our unevaluated oil and gas properties affect the calculation of gain on the sale of material properties and affect our assessment as to whether portions of unevaluated capitalized costs are impaired, which also affects the calculation of recorded amortization and impairment expense with regards to our capitalized costs of oil and gas properties.

The fair value of stock options at the date of grant to employees and members of our Board of Directors is based on judgment as to expected future volatility of our common stock and expected future choices by option holders as to when options are exercised.

Actual results may differ from estimates and assumptions of future events.  Future production may vary materially from estimated oil and gas proved reserves.  Actual future prices may vary significantly from price assumptions used for determining proved reserves and for financial reporting.

Fair Value — The carrying amounts reported in the balance sheets for cash, and accounts receivable approximate fair value because of the immediate or short-term maturity of these financial instruments. Predominately most of the payables are the results of operations and financings of our prior business which ceased operations in 2005, as a result of the undercapitalized nature of our Company and the age of these delinquent payables, we are unable to determine the fair value of these payables.

Accounts Receivable and Credit Policies — We have certain trade receivables consisting of oil and gas sales obligations due under normal trade terms. Our management regularly reviews trade receivables and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible.  At December 31, 2014 and March 31, 2015, management had determined no allowance for uncollectible receivables was necessary. At March 31, 2015 and December 31, 2014, we had accounts receivable and receivables from the production of oil sale of $52,688, of which $0 was accounts receivable-related party, and $17,572, of which $0 was accounts receivable-related party, respectively.

Asset Retirement Obligations — When we incur an obligation for future asset retirement costs, we record as a liability and as a cost of the acquired asset the present value of the estimated future asset retirement obligation.  For example, when we drill a well, we record a liability and an asset cost for the present value of estimated costs we will incur at the end of the well’s life to plug the well, remove surface equipment and provide restoration of the well site’s surface.  Over time, accretion of the liability is recognized as an operating expense, and the capitalized cost is amortized over the expected useful life of the related asset.  Our asset retirement obligations (“ARO”) relate primarily to the plugging, dismantlement, removal, site reclamation and similar activities of our oil and gas properties.

The following table reflects the change in ARO at:  

	March 31, 2015		December 31, 2014
Asset retirement obligation beginning of period	$	33,240	$	31,640
Liabilities incurred		-		-
Liabilities settled		-		-
Accretion		400		1,600
Revisions in estimated liabilities		-		-
Asset retirement obligation end of period	$	33,640	$	33,240
Current portion of obligation end of period	$	-	$	-

Oil and Gas Properties — We use the successful efforts method of accounting for oil and gas activities.  Under this method, subject to a limitation based on estimated value, all costs are capitalized directly associated with property acquisition, exploration and development.  Internal costs that are capitalized at March 31, 2015 and December 31, 2014, were nil as such costs have been limited to costs directly identifiable with acquisition, exploration and development activities for the Company’s account and exclude indirect costs and costs related to production or general corporate overhead.

The Company follows the successful efforts method of accounting for its oil and gas activities. Accordingly, costs associated with the acquisition, drilling and equipping of successful exploratory wells are capitalized. Geological and geophysical costs, delay and surface rentals and drilling costs of unsuccessful exploratory wells are charged to expense as incurred. Costs of drilling development wells are capitalized. Upon the sale or retirement of oil and gas properties, the cost and accumulated depreciation or depletion are removed from the accounts and any gain or loss is credited or charged to operations.

Capitalized costs of oil and gas properties evaluated as having, or not having, proved reserves are amortized in the aggregate by country using the unit-of-production method based upon estimated proved oil and gas reserves.  The Company currently does not have any gas production, which is sold, but we have developed policies to be inclusive of such production, if and when the Company becomes capable of selling such gas. For amortization purposes, relative volumes of oil and gas production and reserves are converted at the energy equivalent conversion rate of six thousand cubic feet of natural gas to one barrel of crude oil. Amortizable costs include estimates of future development costs of proved undeveloped reserves.  The costs of properties not yet evaluated are not amortized until evaluation of the property.  We make such evaluations for a well and associated lease rights when it is determined whether or not the well has proved oil and gas reserves.  Other unevaluated properties are evaluated for impairment as of the end of each calendar quarter based upon various factors at the time, including drilling plans, drilling activity, management’s estimated fair values of lease rights by project, and remaining lives of leases.

Capitalized costs of oil properties (net of related deferred income taxes) may not exceed a ‘ceiling’ amount equal to the present value, discounted at 10% per annum, of the estimated future net cash flows from proved oil reserves plus the cost of unevaluated properties (adjusted for related income tax effects).  Should capitalized costs exceed this ceiling, the excess is charged to earnings as an impairment expense, net of its related reduction of the deferred income tax provision.  The present value of estimated future net cash flows is computed by applying period-end oil prices of oil to estimated future production of proved oil gas reserves as of period-end, less estimated future expenditures (at period-end rates) to be incurred in developing and producing the proved reserves and assuming continuation of economic conditions existing at period-end. SEC guidance allows the ceiling to be increased for subsequent events occurring reasonably before the filing date of the affected financial statements and indicative that capitalized costs were not impaired at period-end.  Such subsequent events are increased oil prices and the proving up of additional reserves on properties owned at period-end.  The present value of proved reserves’ future net cash flows excludes future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet.

Equipment — We record at cost any long-lived tangible assets that are not oil properties.  Depreciation is recorded using the straight-line method over the estimated useful lives of the related assets of three to seven years.  Expenditures for replacements, renewals, and betterments are capitalized.  Maintenance and repairs are charged to operations as incurred.  Long-lived assets, other than oil and properties, are evaluated for impairment to determine if current circumstances and market conditions indicate the carrying amount may not be recoverable.  We have not recognized any impairment losses on non oil and gas long-lived assets.

Impairment — The accounting guidance, Accounting for the Impairment and Disposal of Long-Lived Assets, requires that long-lived assets to be held and used be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Oil properties accounted for using the successful efforts method of accounting (which we use) are excluded from this requirement but continue to be subject to the successful efforts method’s impairment rules.

Revenue Recognition — We recognize oil revenues from our interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable.  We recognize the sale of the partial interests in our oil wells once the terms of such contract have been fulfilled.

Major Customers — During the three months ended March 31, 2015 and 2014, we had two customers, respectively accounting for 100% of oil sales.  Because there are other purchasers that are capable of and willing to purchase our oil and because we have the option to change purchasers on our properties if conditions so warrant, we believe that our oil production can be sold in the market in the event that it is not sold to our existing customers, but in some circumstances a change in customers may entail significant transition costs and/or shutting in or curtailing production for weeks or even months during the transition to a new customer.

Net Income (Loss) Per Share — Basic net income (loss) per share is computed by dividing net income (loss) attributable to common stockholders by the weighted number of common shares outstanding during the period. Any common shares issued as a result of the exercise of stock options and warrants would come from newly issued common shares from our remaining authorized shares. For the year ended December 31, 2014 and the three months ended March 31, 2015, there were 3,215,000 stock options outstanding and $170,000 of convertible debt, excluded from the computation of dilutive securities as the effect would have been anti-dilutive.

Concentration of Credit Risk — Financial instruments which potentially subject the Company to concentrations of credit risk consist of cash.  We maintain substantially all cash assets at one financial institution.  We periodically evaluate the credit worthiness of financial institutions, and maintain cash accounts only in large high quality financial institutions. We believe that credit risk associated with cash is remote.  The Company is exposed to credit risk in the event of nonpayment by counter parties, a significant portion of which are concentrated in energy related industries. The creditworthiness of customers and other counter parties is subject to continuing review.

Share-Based Compensation — We adopted the accounting guidance for, Share-Based Payments, on a modified prospective basis. The accounting guidance requires publicly-held companies to recognize in their statements of operations the grant-date fair value of stock options and other equity-based compensation to employees, consistent with the rules for options to non-employees.

Reclassification — Certain amounts in the 2015 and 2014 consolidated financial statements have been reclassified to conform to the March 31, 2015 financial statement presentation. Such reclassifications have had no effect on net income (loss).

Recent Accounting Pronouncements

All other newly issued but not yet effective accounting pronouncements have been deemed to either not be relevant or immaterial to the operations and reporting disclosures of the Company.

In June 2014, FASB issued Accounting Standards Update (“ASU”) No. 2014-09, “ Revenue from Contracts with Customers”. The update gives entities a single comprehensive model to use in reporting information about the amount and timing of revenue resulting from contracts to provide goods or services to customers. The proposed ASU, which would apply to any entity that enters into contracts to provide goods or services, would supersede the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. Additionally, the update would supersede some cost guidance included in Subtopic 605-35, Revenue Recognition – Construction-Type and Production-Type Contracts. The update removes inconsistencies and weaknesses in revenue requirements and provides a more robust framework for addressing revenue issues and more useful information to users of financial statements through improved disclosure requirements. In addition, the update improves comparability of revenue recognition practices across entities, industries, jurisdictions, and capital markets and simplifies the preparation of financial statements by reducing the number of requirements to which an entity must refer. The update is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. We are currently reviewing the provisions of this ASU to determine if there will be any impact on our results of operations, cash flows or financial condition.

ASU 2014 -15 issued August 2014

In August 2014, the FASB issued Accounting Standards Update “ASU” 2014-15 on “Presentation of Financial Statements Going Concern (Subtopic 205-40) – Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern”. Currently, there is no guidance in U.S. GAAP about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern or to provide related footnote disclosures. The amendments in this Update provide that guidance. In doing so, the amendments are intended to reduce diversity in the timing and content of footnote disclosures. The amendments require management to assess an entity’s ability to continue as a going concern by incorporating and expanding upon certain principles that are currently in U.S. auditing standards. Specifically, the amendments (1) provide a definition of the term substantial doubt, (2) require an evaluation every reporting period including interim periods, (3) provide principles for considering the mitigating effect of management’s plans, (4) require certain disclosures when substantial doubt is alleviated as a result of consideration of management’s plans, (5) require an express statement and other disclosures when substantial doubt is not alleviated, and (6) require an assessment for a period of one year after the date that the financial statements are issued (or available to be issued).

The amendments in this Update are effective for public and nonpublic entities for annual period’s ending after December 15, 2016. Early adoption is permitted.

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Condensed Balance Sheets (Current Period Unaudited) (Parentheticals) - $ / shares	Mar. 31, 2015	Dec. 31, 2014
Preferred stock par value (in Dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock par value (in Dollars per share)	$ 0.03	$ 0.03
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	38,176,085	38,176,085
Common stock, shares outstanding	38,176,085	38,176,085

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Note 5 - Stockholders' Deficit (Tables)

3 Months Ended

Mar. 31, 2015

Stockholders' Equity Note [Abstract]

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]

	Shares			Weighted Average Exercise Price
Outstanding at December 31, 2013		3,393,000		$	0.31
Granted		1,560,000			.16
Exercised		-			.00
Expired or cancelled		(1,738,000	)		.00
Outstanding at December 31, 2014		3,215,000		$	.31
Granted		-			-
Exercised		-			-
Expired or cancelled		-			-
Outstanding at March 31, 2015		3,215,000		$	.26

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Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2015	Aug. 07, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	TN-K ENERGY GROUP INC.
Trading Symbol	TNKY
Document Type	10-Q
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		38,176,085
Amendment Flag	false
Entity Central Index Key	0000942650
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Smaller Reporting Company
Entity Well-known Seasoned Issuer	No
Document Period End Date	Mar. 31, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1

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Note 1 - Organization and Basis of Presentation (Details) - USD ($)	Mar. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Stockholders' Equity Attributable to Parent	$ (2,106,119)	$ (2,067,587)

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Condensed Statement of Operations (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Revenue:
Oil sales	$ 2,775	$ 12,886
Well Equipment Rental	20,300
Sale of oil and gas leases	94,500
Total Revenue	117,575	12,886
Expense:
Oil lease operating expense	39,266	50,038
Cost of oil and gas leases sold	29,258
Sales, general and administrative	122,836	58,082
Total Operating Expenses	191,360	108,120
Loss From Operations	(73,785)	(95,234)
Other Income (Expense):
Interest expense	(3,544)	(3,618)
Total Other Income (Expense)	(3,544)	(3,618)
Net loss before taxes	(77,329)	(98,852)
Income taxes	0	0
Net Loss	$ (77,329)	$ (98,852)
Weighted average number of common shares outstanding -
Basic (in Shares)	38,176,085	38,176,085
Diluted (in Shares)	38,176,085	38,176,085

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Note 7 - Commitments and Contingencies

3 Months Ended

Mar. 31, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies Disclosure [Text Block]

NOTE 7 — COMMITMENTS AND CONTINGENCIES.

The Company may be subject to various possible contingencies, which are derived primarily from interpretations of federal and state laws and regulations affecting the oil and gas industry. Although management believes it has complied with the various laws and regulations, new rulings and interpretations may require the Company to make future adjustments.

The Company continually evaluates its leasehold interests, therefore certain leases may be abandoned by the Company in the normal course of business.

The Company has been involved in litigation from time to time as a result of the failure to make payments on certain of its past due debts. Overall management believes the net recorded value of its past due payables adequately cover the total financial exposure of the past due payables.

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Note 6 - Related Party Transactions

3 Months Ended

Mar. 31, 2015

Related Party Transactions [Abstract]

Related Party Transactions Disclosure [Text Block]

NOTE 6 –RELATED PARTY TRANSACTIONS.

The Company entered into a one year employment arrangement with its CEO in September 2007, with automatic annual renewals. The employment arrangement required an annual salary of $40,000 and a monthly expense allowance of $1,000, with 3,000,000 stock options issued. These stock options vest from March 2008 to September 2008 and have a $0.20 exercise price for three years. In September 2009, this employment agreement was amended to reduce the monthly salary to be $4,167.67 a month and an additional 120,000 options were issued with an exercise price of $0.25, vesting 10,000 options monthly commencing in September 2009. On December 14, 2010, our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,500,000 shares of our common stock at an exercise price of $0.30 per share. The options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 1.64%, annual volatility of 407%, risk free interest rate of 0%, and expected life of 4.5 years. In July 2013 we increased Mr. Page's compensation to $46,000 annually under the terms of an oral agreement. We also provided Mr. Page with the use of company-owned vehicles as an additional compensation.

During 2012, Mr. Ken Page forgave accrued salary due in the amount of $85,076, which had been accrued pursuant to the terms of his employment agreement. Such monies have been recorded as a contribution to capital. 

In May 2014, this employment agreement was amended to reduce the monthly salary to be $3,500 a month and the Company opting to pay health insurance in the amount of $524.02. In addition, on June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share. The Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 175%, risk free interest rate of 2.0%, and expected life of 4.5 years. The fair value of these options was determined to be $313,192, which is being amortized over the five year vesting period.

On February 16, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Gerald Norrad Well #3 at the cost of approximately $15,000. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On March 31, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alan Parrish Well #1 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 9, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Lester Clark #1 in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On May 29, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Alan Parrish Well #2 in Clinton County, Kentucky at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On August 15, 2014, the Company entered into a 50% interest in an 87.5% working interest lease named the Johnny Ringley Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $1,000. The lease is of approximately 68 acres, located in Cumberland County, Kentucky.

On August 21, 2014, we entered into an agreement with Mr. Page pursuant to which certain terms of his Employment Agreement were amended at his request in an effort to assist our company during development of our new business. Under Amendment No. 2 to Mr. Page’s Employment Agreement, his base salary was reduced from $46,000 annually to $42,000 and we agreed to pay his health insurance premiums initially at the rate of $524 per month, which such amount may be increased or decreased upon a change in cost of such insurance based upon a subsequent policy providing identical coverage. This amendment memorialized an oral agreement between parties entered into in May 2014.

On September 26, 2014, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the David Wright in Fentress County, Tennessee at the cost of approximately $16,500 and is responsible for 50% of the all costs associated with the well. The Company is responsible for 50% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

At March 31, 2015 and December 31, 2014 we owed Mr. Page $170,000 and $170,000, respectively of principal and approximately $6,358 and $3,218, respectively of accrued but unpaid interest under this credit line. At March 31, 2015 and December 31, 2014, we owed Mr. Page $57,366 and $51,768, respectively of accrued consulting expenses.

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Note 3 - Oil and Gas Properties and Equipment (Details) - Unevaluated Oil and Gas Property Costs Excluded from Amortization Computation - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Unevaluated Oil and Gas Property Costs Excluded from Amortization Computation [Abstract]
Unevaluated Oil and Gas Property Costs Excluded from Amortization	$ 0	$ (112,704)	$ (67,274)	$ 842,811	$ (592,569)	$ 916,532	$ 225,905
	$ 1,212,701

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Note 2 - Summary of Signifcant Accounting Policies (Details)	3 Months Ended		12 Months Ended
	Mar. 31, 2015 USD ($) shares	Mar. 31, 2014	Dec. 31, 2014 USD ($) shares
Note 2 - Summary of Signifcant Accounting Policies (Details) [Line Items]
Allowance for Doubtful Accounts Receivable, Current	$ 0		$ 0
Accounts Receivable, Net	52,688		17,572
Due from Related Parties, Current	$ 0		0
Fair Value Inputs, Discount Rate	10.00%
Convertible Debt	$ 170,000		$ 170,000
Sales Revenue, Goods, Net [Member] | Customer Concentration Risk [Member]
Note 2 - Summary of Signifcant Accounting Policies (Details) [Line Items]
Number of Customers	2	2
Employee Stock Option [Member]
Note 2 - Summary of Signifcant Accounting Policies (Details) [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount (in Shares) | shares	3,215,000		3,215,000
Two Customers [Member] | Sales Revenue, Goods, Net [Member] | Customer Concentration Risk [Member]
Note 2 - Summary of Signifcant Accounting Policies (Details) [Line Items]
Concentration Risk, Percentage	100.00%	100.00%
Minimum [Member]
Note 2 - Summary of Signifcant Accounting Policies (Details) [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Maximum [Member]
Note 2 - Summary of Signifcant Accounting Policies (Details) [Line Items]
Property, Plant and Equipment, Useful Life	7 years

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Note 3 - Oil and Gas Properties and Equipment (Tables)

3 Months Ended

Mar. 31, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment [Table Text Block]

	March 31, 2015			December 31, 2014
Oil and gas properties, successful efforts method
Unevaluated costs, not yet subject to amortization	$	1,212,701		$	1,212,701
Evaluated costs		1,944,669			1,869,537
Asset retirement costs		39,600			39,600
		3,196,970			3,121,839
Well equipment, furniture and software		183,809			183,809
		3,380,779			3,305,648
Less accumulated depreciation, depletion and amortization		(1,707,914	)		(1,662,916	)
Oil and gas property and equipment	$	1,672,865		$	1,642,731

Schedule of Capitalized Costs of Unproved Properties Excluded from Amortization [Table Text Block]

Year Incurred	Net Costs Incurred
Three months ended March 31, 2015	$	0
Year ended December 31, 2014		(112,704	)
Year ended December 31, 2013		(67,274	)
Year ended December 31, 2012		842,811
Year ended December 31, 2011		(592,569	)
Year ended December 31, 2010		916,532
Year ended December 31, 2009		225,905
	$	1,212,701

Schedule of Depreciation, Depletion, and Amortization by Asset Type [Table Text Block]

	Three months ended March 31,
	2015		2014
Amortization of costs for evaluated oil properties	$	38,435	$	48,422
Depreciation of office equipment, furniture and software		6,565		6,565
Total DD&A expense	$	44,999	$	54,987

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Accounting Policies, by Policy (Policies)

3 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash and Cash Equivalents — For purposes of reporting cash flows, we consider cash equivalents to be all highly liquid investments with a maturity of three months or less at the time of purchase. The Company typically has cash in banks in excess of federally insured amounts.

Use of Estimates, Policy [Policy Text Block]

Use of Estimates - Our financial statements are prepared in accordance with GAAP.  Preparation in accordance with GAAP requires us to (1) adopt accounting policies within accounting rules set by the Financial Accounting Standards Board (“FASB”) and by the United States Securities and Exchange Commission (“SEC”) and (2) make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and other disclosed amounts.  This Note describes our significant accounting policies.  Our management believes the major estimates and assumptions impacting our financial statements are the following:

• estimates of proven (i.e., reasonably certain) oil and gas reserve quantities, which affect the calculations of amortization and impairment of capitalized costs of oil and gas properties;

• estimates of the fair value of oil and gas properties we own, particularly properties that we have not yet explored, or fully explored, by drilling and completing wells;

• estimates of the fair value of stock options at date of grant;

• estimates as to the future realization of deferred income tax assets; and

• the assumption required by GAAP that proved reserves and generally proved reserve value for measuring capitalized cost impairment be based on the prices of oil and gas at the end of the reporting period.

The estimated fair values of our unevaluated oil and gas properties affect the calculation of gain on the sale of material properties and affect our assessment as to whether portions of unevaluated capitalized costs are impaired, which also affects the calculation of recorded amortization and impairment expense with regards to our capitalized costs of oil and gas properties.

The fair value of stock options at the date of grant to employees and members of our Board of Directors is based on judgment as to expected future volatility of our common stock and expected future choices by option holders as to when options are exercised.

Actual results may differ from estimates and assumptions of future events.  Future production may vary materially from estimated oil and gas proved reserves.  Actual future prices may vary significantly from price assumptions used for determining proved reserves and for financial reporting.

Fair Value Measurement, Policy [Policy Text Block]

Fair Value — The carrying amounts reported in the balance sheets for cash, and accounts receivable approximate fair value because of the immediate or short-term maturity of these financial instruments. Predominately most of the payables are the results of operations and financings of our prior business which ceased operations in 2005, as a result of the undercapitalized nature of our Company and the age of these delinquent payables, we are unable to determine the fair value of these payables.

Receivables, Policy [Policy Text Block]

Accounts Receivable and Credit Policies — We have certain trade receivables consisting of oil and gas sales obligations due under normal trade terms. Our management regularly reviews trade receivables and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible.  At December 31, 2014 and March 31, 2015, management had determined no allowance for uncollectible receivables was necessary. At March 31, 2015 and December 31, 2014, we had accounts receivable and receivables from the production of oil sale of $52,688, of which $0 was accounts receivable-related party, and $17,572, of which $0 was accounts receivable-related party, respectively.

Asset Retirement Obligations, Policy [Policy Text Block]

Asset Retirement Obligations — When we incur an obligation for future asset retirement costs, we record as a liability and as a cost of the acquired asset the present value of the estimated future asset retirement obligation.  For example, when we drill a well, we record a liability and an asset cost for the present value of estimated costs we will incur at the end of the well’s life to plug the well, remove surface equipment and provide restoration of the well site’s surface.  Over time, accretion of the liability is recognized as an operating expense, and the capitalized cost is amortized over the expected useful life of the related asset.  Our asset retirement obligations (“ARO”) relate primarily to the plugging, dismantlement, removal, site reclamation and similar activities of our oil and gas properties.

The following table reflects the change in ARO at:  

	March 31, 2015		December 31, 2014
Asset retirement obligation beginning of period	$	33,240	$	31,640
Liabilities incurred		-		-
Liabilities settled		-		-
Accretion		400		1,600
Revisions in estimated liabilities		-		-
Asset retirement obligation end of period	$	33,640	$	33,240
Current portion of obligation end of period	$	-	$	-

Oil and Gas Properties Policy [Policy Text Block]

Oil and Gas Properties — We use the successful efforts method of accounting for oil and gas activities.  Under this method, subject to a limitation based on estimated value, all costs are capitalized directly associated with property acquisition, exploration and development.  Internal costs that are capitalized at March 31, 2015 and December 31, 2014, were nil as such costs have been limited to costs directly identifiable with acquisition, exploration and development activities for the Company’s account and exclude indirect costs and costs related to production or general corporate overhead.

The Company follows the successful efforts method of accounting for its oil and gas activities. Accordingly, costs associated with the acquisition, drilling and equipping of successful exploratory wells are capitalized. Geological and geophysical costs, delay and surface rentals and drilling costs of unsuccessful exploratory wells are charged to expense as incurred. Costs of drilling development wells are capitalized. Upon the sale or retirement of oil and gas properties, the cost and accumulated depreciation or depletion are removed from the accounts and any gain or loss is credited or charged to operations.

Capitalized costs of oil and gas properties evaluated as having, or not having, proved reserves are amortized in the aggregate by country using the unit-of-production method based upon estimated proved oil and gas reserves.  The Company currently does not have any gas production, which is sold, but we have developed policies to be inclusive of such production, if and when the Company becomes capable of selling such gas. For amortization purposes, relative volumes of oil and gas production and reserves are converted at the energy equivalent conversion rate of six thousand cubic feet of natural gas to one barrel of crude oil. Amortizable costs include estimates of future development costs of proved undeveloped reserves.  The costs of properties not yet evaluated are not amortized until evaluation of the property.  We make such evaluations for a well and associated lease rights when it is determined whether or not the well has proved oil and gas reserves.  Other unevaluated properties are evaluated for impairment as of the end of each calendar quarter based upon various factors at the time, including drilling plans, drilling activity, management’s estimated fair values of lease rights by project, and remaining lives of leases.

Capitalized costs of oil properties (net of related deferred income taxes) may not exceed a ‘ceiling’ amount equal to the present value, discounted at 10% per annum, of the estimated future net cash flows from proved oil reserves plus the cost of unevaluated properties (adjusted for related income tax effects).  Should capitalized costs exceed this ceiling, the excess is charged to earnings as an impairment expense, net of its related reduction of the deferred income tax provision.  The present value of estimated future net cash flows is computed by applying period-end oil prices of oil to estimated future production of proved oil gas reserves as of period-end, less estimated future expenditures (at period-end rates) to be incurred in developing and producing the proved reserves and assuming continuation of economic conditions existing at period-end. SEC guidance allows the ceiling to be increased for subsequent events occurring reasonably before the filing date of the affected financial statements and indicative that capitalized costs were not impaired at period-end.  Such subsequent events are increased oil prices and the proving up of additional reserves on properties owned at period-end.  The present value of proved reserves’ future net cash flows excludes future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet.

Property, Plant and Equipment, Policy [Policy Text Block]

Equipment — We record at cost any long-lived tangible assets that are not oil properties.  Depreciation is recorded using the straight-line method over the estimated useful lives of the related assets of three to seven years.  Expenditures for replacements, renewals, and betterments are capitalized.  Maintenance and repairs are charged to operations as incurred.  Long-lived assets, other than oil and properties, are evaluated for impairment to determine if current circumstances and market conditions indicate the carrying amount may not be recoverable.  We have not recognized any impairment losses on non oil and gas long-lived assets.

Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]

Impairment — The accounting guidance, Accounting for the Impairment and Disposal of Long-Lived Assets, requires that long-lived assets to be held and used be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Oil properties accounted for using the successful efforts method of accounting (which we use) are excluded from this requirement but continue to be subject to the successful efforts method’s impairment rules.

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition — We recognize oil revenues from our interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable.  We recognize the sale of the partial interests in our oil wells once the terms of such contract have been fulfilled.

Major Customers, Policy [Policy Text Block]

Major Customers — During the three months ended March 31, 2015 and 2014, we had two customers, respectively accounting for 100% of oil sales.  Because there are other purchasers that are capable of and willing to purchase our oil and because we have the option to change purchasers on our properties if conditions so warrant, we believe that our oil production can be sold in the market in the event that it is not sold to our existing customers, but in some circumstances a change in customers may entail significant transition costs and/or shutting in or curtailing production for weeks or even months during the transition to a new customer.

Earnings Per Share, Policy [Policy Text Block]

Net Income (Loss) Per Share — Basic net income (loss) per share is computed by dividing net income (loss) attributable to common stockholders by the weighted number of common shares outstanding during the period. Any common shares issued as a result of the exercise of stock options and warrants would come from newly issued common shares from our remaining authorized shares. For the year ended December 31, 2014 and the three months ended March 31, 2015, there were 3,215,000 stock options outstanding and $170,000 of convertible debt, excluded from the computation of dilutive securities as the effect would have been anti-dilutive.

Concentration Risk, Credit Risk, Policy [Policy Text Block]

Concentration of Credit Risk — Financial instruments which potentially subject the Company to concentrations of credit risk consist of cash.  We maintain substantially all cash assets at one financial institution.  We periodically evaluate the credit worthiness of financial institutions, and maintain cash accounts only in large high quality financial institutions. We believe that credit risk associated with cash is remote.  The Company is exposed to credit risk in the event of nonpayment by counter parties, a significant portion of which are concentrated in energy related industries. The creditworthiness of customers and other counter parties is subject to continuing review.

Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]

Share-Based Compensation — We adopted the accounting guidance for, Share-Based Payments, on a modified prospective basis. The accounting guidance requires publicly-held companies to recognize in their statements of operations the grant-date fair value of stock options and other equity-based compensation to employees, consistent with the rules for options to non-employees.

Reclassification, Policy [Policy Text Block]

Reclassification — Certain amounts in the 2015 and 2014 consolidated financial statements have been reclassified to conform to the March 31, 2015 financial statement presentation. Such reclassifications have had no effect on net income (loss).

New Accounting Pronouncements, Policy [Policy Text Block]

Recent Accounting Pronouncements

All other newly issued but not yet effective accounting pronouncements have been deemed to either not be relevant or immaterial to the operations and reporting disclosures of the Company.

In June 2014, FASB issued Accounting Standards Update (“ASU”) No. 2014-09, “ Revenue from Contracts with Customers”. The update gives entities a single comprehensive model to use in reporting information about the amount and timing of revenue resulting from contracts to provide goods or services to customers. The proposed ASU, which would apply to any entity that enters into contracts to provide goods or services, would supersede the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. Additionally, the update would supersede some cost guidance included in Subtopic 605-35, Revenue Recognition – Construction-Type and Production-Type Contracts. The update removes inconsistencies and weaknesses in revenue requirements and provides a more robust framework for addressing revenue issues and more useful information to users of financial statements through improved disclosure requirements. In addition, the update improves comparability of revenue recognition practices across entities, industries, jurisdictions, and capital markets and simplifies the preparation of financial statements by reducing the number of requirements to which an entity must refer. The update is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. We are currently reviewing the provisions of this ASU to determine if there will be any impact on our results of operations, cash flows or financial condition.

ASU 2014 -15 issued August 2014

In August 2014, the FASB issued Accounting Standards Update “ASU” 2014-15 on “Presentation of Financial Statements Going Concern (Subtopic 205-40) – Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern”. Currently, there is no guidance in U.S. GAAP about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern or to provide related footnote disclosures. The amendments in this Update provide that guidance. In doing so, the amendments are intended to reduce diversity in the timing and content of footnote disclosures. The amendments require management to assess an entity’s ability to continue as a going concern by incorporating and expanding upon certain principles that are currently in U.S. auditing standards. Specifically, the amendments (1) provide a definition of the term substantial doubt, (2) require an evaluation every reporting period including interim periods, (3) provide principles for considering the mitigating effect of management’s plans, (4) require certain disclosures when substantial doubt is alleviated as a result of consideration of management’s plans, (5) require an express statement and other disclosures when substantial doubt is not alleviated, and (6) require an assessment for a period of one year after the date that the financial statements are issued (or available to be issued).

The amendments in this Update are effective for public and nonpublic entities for annual period’s ending after December 15, 2016. Early adoption is permitted.

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Note 2 - Summary of Signifcant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

Schedule of Change in Asset Retirement Obligation [Table Text Block]

	March 31, 2015		December 31, 2014
Asset retirement obligation beginning of period	$	33,240	$	31,640
Liabilities incurred		-		-
Liabilities settled		-		-
Accretion		400		1,600
Revisions in estimated liabilities		-		-
Asset retirement obligation end of period	$	33,640	$	33,240
Current portion of obligation end of period	$	-	$	-

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Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Tables)

3 Months Ended

Mar. 31, 2015

Disclosure Text Block [Abstract]

Schedule of Debt [Table Text Block]

	March 31, 2015		December 31, 2014
Convertible line of credit note payable to a related party with an interest rate of 7.5% per annum, due December 31, 2013		170,000		170,000
	$	170,000	$	170,000

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Note 3 - Oil and Gas Properties and Equipment (Details)																				3 Months Ended		12 Months Ended
	Mar. 31, 2015 USD ($)	Jan. 31, 2015 USD ($)	Jan. 02, 2015 USD ($)	Jan. 01, 2015 USD ($)	Nov. 18, 2014 USD ($)	Sep. 30, 2014 USD ($)	Sep. 26, 2014 USD ($)	Sep. 08, 2014 USD ($) a	Aug. 20, 2014 USD ($)	Aug. 15, 2014 USD ($) a	Aug. 04, 2014 USD ($)	Jun. 30, 2014 USD ($)	Jun. 04, 2014 USD ($)	May. 29, 2014 USD ($)	May. 09, 2014 USD ($)	Mar. 31, 2014 USD ($)	Mar. 26, 2014 USD ($)	Feb. 16, 2014 USD ($)	Jan. 04, 2014 USD ($)	Mar. 31, 2015 USD ($)	Mar. 31, 2014 USD ($)	Dec. 31, 2014 USD ($)
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Number of Dry Holes Drilled																						3
Results of Operations, Dry Hole Costs (in Dollars)																						$ 37,145
Capitalized Exploratory Well Cost, Additions Pending Determination of Proved Reserves (in Dollars)																						$ 0
Asset Impairment Charges (in Dollars)																				$ 0	$ 0
Depreciation, Depletion and Amortization (in Dollars)																				$ 44,999	$ 54,987
Todd Anderson Well # 4 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well																			87.50%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)																			$ 27,500
Percent of Costs on a Well																			100.00%
Gerald Norrad Well #3 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well																		43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)																		$ 15,000
Percent of Costs on a Well																		50.00%
Millard Willis Well #8 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well													50.00%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)													$ 18,500
Percent of Costs on a Well													55.00%
Percent of Working and Royalty Interests Sold																	37.50%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)																	$ 12,000
Alan Parrish Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well																43.75%					43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)																$ 16,500
Percent of Costs on a Well																50.00%					50.00%
Lester Clark #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well								43.75%							43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)								$ 16,500							$ 16,500
Percent of Costs on a Well								50.00%							50.00%
Alvin Parrish Well #2 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well														43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)														$ 16,500
Percent of Costs on a Well														50.00%
Millard Willis Well #9 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well											50.00%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)											$ 18,500
Percent of Costs on a Well											55.00%
Percent of Working and Royalty Interests Sold												37.50%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)												$ 35,000
Kyle Padgett Well #7 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well									20.00%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)									$ 4,250
Percent of Costs on a Well									25.00%
David Wright [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in a Well							43.75%
Costs Incurred, Acquisition of Oil and Gas Properties (in Dollars)							$ 16,500
Percent of Costs on a Well							50.00%
William Warren II Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Working and Royalty Interests Sold						50.00%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)						$ 35,000
Billy Walker Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Working and Royalty Interests Sold					50.00%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)					$ 35,000
Millard Willis Well #10 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well				50.00%
Percent of Working and Royalty Interests Sold				50.00%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)				$ 35,000
Johnny Ringley Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well			50.00%
Percent of Working and Royalty Interests Sold			50.00%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)			$ 17,500
William Warren Well #2 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well		50.00%
Percent of Working and Royalty Interests Sold		50.00%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)		$ 35,000
Sherrie Miles Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well	50.00%																			50.00%
Percent of Working and Royalty Interests Sold	50.00%																			50.00%
Proceeds from Divestiture of Interest in Subsidiaries and Affiliates (in Dollars)	$ 7,000
Disposal Of Well [Member] | Millard Willis Well #8 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well																	45.00%
Disposal Of Well [Member] | Millard Willis Well #9 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well												45.00%
Disposal Of Well [Member] | William Warren II Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well						50.00%
Disposal Of Well [Member] | Billy Walker Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent of Costs on a Well					50.00%
Johnny Ringley Lease [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Interest in Lease										50.00%
Percent Working Interest in Lease										87.50%
Operating Leases, Income Statement, Initial Direct Costs (in Dollars)										$ 1,000
Area of Land (in Acres) | a										68
William Warren II Lease [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Percent Working Interest in Lease								87.50%
Operating Leases, Income Statement, Initial Direct Costs (in Dollars)								$ 10
Area of Land (in Acres) | a								640
Mr. Daniel (Allen) Page [Member] | Gerald Norrad Well #3 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs																		50.00%
Mr. Daniel (Allen) Page [Member] | Alan Parrish Well #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs																50.00%					50.00%
Mr. Daniel (Allen) Page [Member] | Lester Clark #1 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs								50.00%							50.00%
Mr. Daniel (Allen) Page [Member] | Alvin Parrish Well #2 [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs														50.00%
Mr. Daniel (Allen) Page [Member] | David Wright [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Related Party Transaction, Percent of Remaining Costs							50.00%
Minimum [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Prospect Leasing and Acquisition Period																				1 year
Prospect Leasing and Acquisition, Subsequent Evaluation Period																				1 year
Maximum [Member]
Note 3 - Oil and Gas Properties and Equipment (Details) [Line Items]
Prospect Leasing and Acquisition Period																				3 years
Prospect Leasing and Acquisition, Subsequent Evaluation Period																				3 years

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Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - Convertible Notes Payable and Loans Payable - USD ($)	Mar. 31, 2015	Dec. 31, 2014
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - Convertible Notes Payable and Loans Payable [Line Items]
Convertible notes payable	$ 170,000	$ 170,000
Payable to a Related Party [Member]
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - Convertible Notes Payable and Loans Payable [Line Items]
Convertible notes payable	$ 170,000	$ 170,000

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Condensed Statement of Cash Flows (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Cash Flow From Operating Activities:
Net Loss	$ (77,329)	$ (98,852)
Adjustments to reconcile Net Loss to Net Cash (Used by) Provided by Operating Activities:
Depreciation and depletion	44,999	54,987
Change in fair fair of asset retirement obligation	400	400
Equity based compensation	38,797
Changes in operating assets and liabilities:
Accounts receivable	(35,116)	(3,751)
Sale of oil and gas rights	27,426
Accounts payable and accrued expenses	56,917	(11,854)
Net Cash Provided by (Used by) Operating Activities	56,094	(59,070)
Cash Flow From Investing Activities:
Purchase and development of oil and gas rights	(102,558)	(58,713)
Net Cash Used by Investing Activities	(102,558)	(58,713)
Cash Flow From Financing Activities:
Repayment of notes payable		(10,000)
Net Cash Used by Financing Activities		(10,000)
Net (Decrease) In Cash and Cash Equivalents	(46,464)	(127,783)
Cash and cash equivalents at beginning of period	157,830	514,003
Cash and cash equivalents at end of period	111,366	386,220
Cash paid for income taxes	0	0
Cash paid for interest	$ 0	$ 0

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Note 5 - Stockholders' Deficit

3 Months Ended

Mar. 31, 2015

Stockholders' Equity Note [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

NOTE 5 — STOCKHOLDERS’ DEFICIT.

Stock Options

On March 22, 2004 our Board of Directors adopted, subject to stockholder approval, the 2004 Stock Incentive Plan (the “2004 Plan”). The 2004 Plan was approved by our stockholder in May 2004.  No award could be granted under the 2004 Plan subsequent to the 10th anniversary of the date on which the plan was approved by our stockholders. The number of shares of our common stock available for issuance under the 2004 Plan was 3,500,000.  

On September 29, 2009 our Board of Directors adopted our 2009 Equity Compensation Plan (the “2009 Plan”). The plan authorizes the grant of (i) options which qualify as incentive stock options under Section 422(b) of the Internal Revenue Code of 1986, as amended, (ii) non-qualified options which do not qualify as incentive stock options, (iii) awards of our common stock (iv) and rights to make direct purchases of our common stock which may be subject to certain restrictions. We have reserved 4,800,000 shares of our common stock for issuance upon grants made under the plan.  

In May 2014, this employment agreement was amended to reduce the monthly salary to be $3,500 a month and the Company opting to pay health insurance in the amount of $524.02. In addition, on June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share. The Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 175%, risk free interest rate of 2.0%, and expected life of 4.5 years.

On June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share. The Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 234%, risk free interest rate of 1.64%, and expected life of 4.5 years.

Compensation based stock option and warrant activity for warrants and qualified and unqualified stock options are summarized as follows:

	Shares			Weighted Average Exercise Price
Outstanding at December 31, 2013		3,393,000		$	0.31
Granted		1,560,000			.16
Exercised		-			.00
Expired or cancelled		(1,738,000	)		.00
Outstanding at December 31, 2014		3,215,000		$	.31
Granted		-			-
Exercised		-			-
Expired or cancelled		-			-
Outstanding at March 31, 2015		3,215,000		$	.26

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Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - Convertible Notes Payable and Loans Payable (Parentheticals)	Mar. 31, 2015	Dec. 31, 2014	Apr. 30, 2007
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - Convertible Notes Payable and Loans Payable (Parentheticals) [Line Items]
Interest rate			7.50%
Payable to a Related Party [Member]
Note 4 - Loan Payable, Convertible Notes Payable, Convertible Notes Payable - Related Party (Details) - Convertible Notes Payable and Loans Payable (Parentheticals) [Line Items]
Interest rate	7.50%	7.50%

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Label	Element	Value
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price	us-gaap_ShareBasedCompensationArrangementByShareBasedPaymentAwardOptionsOutstandingWeightedAverageExercisePrice	$ 0.31
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number	us-gaap_ShareBasedCompensationArrangementByShareBasedPaymentAwardOptionsOutstandingNumber	3,393,000

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Note 2 - Summary of Signifcant Accounting Policies (Details) - Change in Asset Retirement Obligations - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Change in Asset Retirement Obligations [Abstract]
Asset retirement obligation beginning of period	$ 33,240	$ 31,640
Liabilities incurred	0	0
Liabilities settled	0	0
Accretion	400	1,600
Revisions in estimated liabilities	0	0
Asset retirement obligation end of period	33,640	33,240
Current portion of obligation end of period	$ 0	$ 0