UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

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

For the fiscal year ended December 31, ~~2012~~2014

[ ]	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.

(Exact 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)

Registrant's telephone number, including area code:

(931) 707-9599

Securities registered under Section 12(b) of the Act:

Title of each class	Name of each exchange on which registered
None	Not applicable

Securities registered under Section 12(g) of the Act:

Common Stock, par value $0.03 per share

(Title of class)

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☐ Yes ☒ No

o Yes x No

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

o☐ Yes x☒ No

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.

o☐ Yes ~~xNo~~☒No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.4.05 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

x☒ Yes o☐ No

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

x☒

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company:

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

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

o☐ Yes x☒ No

State the aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was sold, or the average bid and asked prices of such common equity, as of the last business day of the registrant's most recently completed second fiscal quarter. Approximately 11$7,~~203~~197,~~643~~617 on June 2930, ~~2012~~2014.

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 ~~April~~June 810, ~~2013~~2015.

DOCUMENTS INCORPORATED BY REFERENCE

List hereunder the following documents if incorporated by reference and the Part of the Form 10-K (e.g., Part I, Part II, etc.) into which the document is incorporated: (1) Any annual report to security holders; (2) Any proxy or information statement; and (3) Any prospectus filed pursuant to Rule 424(b) or (c) under the Securities Act of 1933. The listed documents should be clearly described for identification purposes (e.g., annual report to security holders for fiscal year ended December 24, 1980). None.

TN-K ENERGY GROUP INC.

FORM 10-K

TABLE OF CONTENTS

		Page No.
Part I
Item 1.	Business.	45
Item 1A.	Risk Factors.	89
Item 1B.	Unresolved Staff Comments.	1112
Item 2.	Properties.	12
Item 3.	Legal Proceedings.	1213
Item 4.	Mine Safety Disclosures.	1213
Part II
Item 5.	Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.	1213
Item 6.	Selected Financial Data.	1314
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations.	1314
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk.	1617
Item 8.	Financial Statements and Supplementary Data.	1617
Item 9.	Changes In and Disagreements With Accountants on Accounting and Financial Disclosure.	1618
Item 9A.	Controls and Procedures.	1718
Item 9B.	Other Information.	1819
Part III
Item 10.	Directors, Executive Officers and Corporate Governance.	1819
Item 11.	Executive Compensation.	2021
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.	2123
Item 13.	Certain Relationships and Related Transactions, and Director Independence.	2324
Item 14.	Principal Accounting Fees and Services.	2326
Part IV
Item 15.	Exhibits, Financial Statement Schedules.	2426

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This report contains forward-looking statements. 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. 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 failure to pay a related party secured credit line which is now due and which is secured by all of our assets,

•

potential conflicts of interest involving related party transactions,

•

our business and growth strategies,

•

risks associated with our operations as a small independent oil company with limited capital resources,

•

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~~drilling ~~gas~~ operations including the impairment of carrying value of our assets,

• our ability to find additional reserves, ~~and~~

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

~~Forward-looking~~• ~~statements~~unanticipated 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~~changes ~~may prove to be inaccurate. Management cautions all readers that the forward-looking statements contained~~ in ~~this~~oil ~~report are not guarantees of future performance~~prices, 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:

• ~~our~~other ~~inability~~uncertainties toinherent ~~satisfy~~in ~~our~~the ~~debt~~production ~~obligations~~of oil and natural gas, and

• ~~potential~~Federal ~~conflicts~~laws ofimpacting ~~interest~~the ~~involving~~tradeablity ~~related~~of ~~party~~our ~~transactions,~~common stock.

•The forward-looking statements contained in this report are largely based on our ~~failure~~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 ~~pay~~be areasonable, ~~related~~they ~~party~~are ~~secured~~inherently ~~credit~~uncertain ~~line~~and ~~which~~involve isa ~~now~~number ~~due~~of risks and ~~which~~uncertainties isthat ~~secured~~are bybeyond 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 ~~our~~future ~~assets~~performance, and we cannot assure any reader that such statements will be realized or the forward-looking events and circumstances will occur.

• our inability to raise capital as needed,

• 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 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.

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 ~~formerly known as Digital Lifestyles Group, Inc~~.. In addition, when used herein and unless specifically set forth to the contrary, “~~2012~~2014” refers to the year ~~ended~~ending December 31, ~~2012~~2014, “~~2011~~2014” refers to the year ended December 31, ~~2011~~2014, ~~and~~ “2013” refers to the year ~~ending~~ended December 31, 2013.

PART I

ITEM 1. DESCRIPTION OF BUSINESS.

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. While we have acquired working interests in existing wells in an effort to balance our revenue sources, we primarily focus our efforts on acreage acquisitions in which we will be the operator of the wells which we believe gives us the greatest ability to maximize our revenues over the long term. 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 recent 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, receive a finder’s fee, 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.

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. In ~~2012~~2014, we have sold ~~27.5% of our~~ working ~~and operating~~ interest in 385 of our wells ~~and~~ranging afrom ~~checkerboard retaining 2~~37.5% ~~over~~to an50% ~~overriding~~working and royalty interest~~. Following~~ ~~this~~per ~~transaction,~~well weand ~~are~~for noeach ~~longer~~well we are responsible for completion and operating costs ~~for~~on ~~these~~those wells. Inranging ~~2011,~~from we50% ~~had~~to ~~sold~~55% ~~working~~per ~~interests~~well, into 5two ofindividuals ~~our~~and/or ~~wells~~entities ~~ranging~~on ~~from~~the ~~20%~~Millard toWillis, ~~35%~~William ~~per~~Warren ~~well.~~and ~~For~~Billy ~~each~~Walker ~~sale~~lease. In 2013, we ~~are~~sold ~~responsible~~27.5% ~~for~~of ~~completion~~our working and operating ~~costs~~interest onin ~~those~~6 of our wells ranging from 2527.5% to 5837.50% working and royalty interest per well , to two individuals and/or entities on the Millard Willis lease. This has allowed us to move forward in drilling a greater number of wells than we would otherwise able to drill based upon our limited financial resources. We expect to continue to use these types of relationships to partially or completely fund initial drilling of future wells.

Reserves

We own approximately 21,~~512~~804.9962 gross acres of leasehold interests with 6338 producing oil wells in which we own an interest. Wells drilled in this area range from 900 feet to 2,000 feet in depth and the well spacing is generally four acres per well. The following table provides information on our reserves at December 31, ~~2012~~2014.

Summary of Oil Reserves as of Fiscal-Year End Based on Aver Fiscal-Year Prices

Gross

Net

Future Net Revenues

Reserves category

Oil (Bbls)

Total ($)

Discount @ 10% ($)

PROVED

~~150~~66,~~155~~062

135,~~914~~802

1456,~~048,742~~905

~~650~~230,~~545~~722

UNDEVELOPED:

7512,~~595~~249

83,~~640~~644

~~534~~176,~~282~~213

~~347~~98,~~838~~819

TOTAL PROVED

~~225~~78,~~750~~311

229,~~554~~446

1633,~~583,024~~118

~~998~~329,~~383~~541

Probable- undeveloped

~~156~~58,~~675~~335

3712,~~068~~753

2829,~~295,729~~066

1442,~~459,237~~527

Possible – undeveloped

~~236~~148,~~445~~327

6838,~~039~~011

42,~~143~~423,~~719~~731

21,~~510~~199,~~875~~111

Total All Reserves

~~618~~284,~~870~~973

~~127~~60,~~661~~210

83,~~022~~885,~~472~~915

41,~~968~~971,~~495~~179

When used in this table, “Bbls” means barrels of oil. We also use a number of terms when describing our reserves. “Proved reserves” are the quantities of oil that, by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be economically producible. We provide information on two types of proved reserves - developed and undeveloped. “Proved developed reserves” are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. Proved undeveloped reserves” are reasonably certain reserves in drilling units immediately adjacent to the drilling unit containing a producing well as well as areas beyond one offsetting drilling unit from a producing well.

Under SEC rules we are also permitted to provide information about probable and possible reserves. “Probable reserves” are additional reserves that are less certain to be recovered than proved reserves but which, in sum with proved reserves, are as likely as not to be recovered. “Possible reserves” are additional reserves that are less certain to be recovered than probable reserves. The various reserve categories have different risks associated with them. Proved reserves are more likely to be produced than probable reserves and probable reserves are more likely to be produced than possible reserves. Because of these risks, the different reserve categories should not be considered to be directly additive.

Our reserve estimates at December 31, ~~2012~~2014 were prepared by Lee Keeling and Associates, Inc., an independent engineering firm. These reserve report which is filed as an exhibit to this report was prepared in accordance with the generally accepted petroleum engineering and evaluation principles and most recent definitions and guidelines established by the SEC. All reserve definitions comply with the applicable definitions of the rules of the SEC. The reserves were estimated using engineering and geological methods widely accepted in our industry. The accuracy of the reserve estimates is dependent upon the quality of available data and upon independent geological and engineering interpretation of that data. For proved developed producing, the estimates considered to be definitive, using performance methods that utilize extrapolations of various historical data including oil and water production and pressure history. For other than proved producing, proved undeveloped reserves and probable and possible reserve estimates were made using volumetric methods.

Our policies regarding internal controls over reserve estimates require reserves to be in compliance with the SEC definitions and guidance and for reserves to be prepared by an independent engineering firm under the supervision of our Chief Executive Officer. We provide the engineering firm with estimate preparation material such as property interests, production, current operation costs, current production prices and other information. This information is reviewed by our Chief Executive Officer to ensure accuracy and completeness of the data prior to submission to our third party engineering firm. A letter which identifies the professional qualifications of the independent engineering firm who prepared the reserve report is included in the reserve report. There was no conversion of undeveloped reserves to prove reserves ~~during~~or ~~2012. During 2012 we spent approximately $281,493 on converting~~ proved ~~undeveloped~~developed reserves toduring ~~proved developed reserves~~2014.

The engineering report also projected discounted future net revenues from our net reserves and the present value, discounted at 10% per annum, of that future net revenue as summarized in the foregoing table. Future net revenues are the amount, exclusive of federal and state income taxes, that will accrue to the subject interests for continued operation of the properties to depletion. It should not be construed as a fair market or trading value. Provisions have been made for future expenses required for recompletion and drilling, but no provision has been made for the cost of plugging and abandoning the properties. The pricing used was based on a determination of a 12-month average price, calculated as the unweighted average price of the monthly prices received by us for oil for the 12-month period prior to the end of the reporting period.

The following table presents our producing oil wells at December 31, ~~2012~~2014.

Producing Wells
Gross (a)			6338
Net (b)			67.~~343~~64

(a) The number of gross wells is the total number of wells in which a working interest is owned.

(b) The number of net wells is the sum of fractional working interests we own in gross wells expressed as whole numbers and fractions thereof.

Certain of the leasehold interests we own are subject to royalty, overriding royalty and other outstanding interests customary to the industry. The properties may also be subject to additional burdens, liens or encumbrances customary to the industry, including items such as operating agreements, current taxes, development obligations under natural gas and oil leases, farm-out agreements and other restrictions. We do not believe that any of these burdens will materially interfere with the use of the properties. The following table presents leased acres as of December 31, 2012.

	Gross		Net
Developed acres		452		81.84
Undeveloped acres		2,060.99		925.38
Total acreage		2,512.99		1,007.22

At December 31, 2012, there were 2060.99 of gross acres of undeveloped acres and 452 acres of net undeveloped acres that we control under fee leases. The following table presents the net undeveloped acres that we control under fee leases and the period the leases are scheduled to expire, absent pre-expiration drilling and production which extends the term of the lease(s). The expiration dates of the leases are subject to automatic renewals so long as we are producing oil and/or gas on the lease.

	Net Undeveloped Acres
Lease	Year of Expiration	Total Acres
Anderson, Charles Lease, Overton County, TN	Automatic Renewal	53.2
Anderson, Todd Lease, Clinton County, KY	Automatic Renewal		38.88
Bayer, Miner Lease, Overton County, TN	Automatic Renewal		11.73
Blaydes, Harold Lease, Green County, KY	Automatic Renewal		32.55
Bradley Lease, Green County, KY	Automatic Renewal		0.75
Chamber Lease, Clinton County, KY	Automatic Renewal		92.4
Clark Lease, Green County, KY	Automatic Renewal		217.875
Dishman, Ernest Lease, Overton County, TN	Automatic Renewal		5.69
Duvall, Billy Lease, Clinton, County, KY	Automatic Renewal		2.8
Irby, Jimmy, Clinton County, KY	Automatic Renewal		13.62
McClellan, Otis Lease, Clinton County, KY	Automatic Renewal		6.13
Nadeau, Kenneth Lease, Green County, KY	Automatic Renewal		53.37
Norrad, Gerald, Overton County, TN	Automatic Renewal		148
Simmons, Roquel, Clinton County, KY	Automatic Renewal		1.4
Willis, Millard, Clinton County, KY	Automatic Renewal		245

The following table presents our net productive and dry development wells and our net productive and dry exploratory wells drilled during the past three fiscal years. There is no correlation between the number of productive wells completed during any period and the aggregate reserves to those wells. Productive wells consist of producing wells capable of commercial production.

	Drilling Activities
	2012				2011				2010
	Net		Gross		Net		Gross		Net		Gross
Development:
Producing		.65		3		10.21		40		10.21		.375
Non-Producing		4.14		13		7.64		25		7.64		.750
Dry		1.75		7		3.08		12		3.08		0
Total development		6.54		23		20.93		77		20.93		1.125
Exploratory:
Productive		0		0		0		0		0		0
Dry		0		0		0		0		0		0
Total drilling activity		6.54		23		20.93		77		20.93		1.125

	Gross		Net
Developed acres		284		42.72
Undeveloped acres		1,512.26		649.38
Total acreage		1,796.26		692.11

At December 31, 2014, there were 1,512.26 of gross acres of undeveloped acres and 649.38 acres of net undeveloped acres that we control under fee leases. The following table presents the net undeveloped acres that we control under fee leases and the period the leases are scheduled to expire, absent pre-expiration drilling and production which extends the term of the lease(s). The expiration dates of the leases are subject to automatic renewals so long as we are producing oil and/or gas on the lease.

	Net Undeveloped Acres
Lease	Year of Expiration	Total Acres
Anderson, Charles Lease, Overton County, TN	Automatic Renewal		50.4
Anderson, Todd Lease, Clinton County, KY	Automatic Renewal		38.88
Bayer, Miner Lease, Overton County, TN	Automatic Renewal		11.73
Blaydes, Harold Lease, Green County, KY	Automatic Renewal		35.35
Bradley Lease, Green County, KY	Automatic Renewal		1.15
Chamber Lease, Clinton County, KY	Automatic Renewal		88.2
Clark Lease, Green County, KY	Automatic Renewal		192.675
Willis, Millard, Clinton County, KY	Automatic Renewal		231

	Drilling Activities
	2014				2013				2012
	Net		Gross		Net		Gross		Net		Gross
Development:
Producing		.75		1		.438		1		.65		3
Non-Producing		2.7		7		.438		1		4.14		13

Dry		1.313		3		1.313		3		1.75		7
Total development		4.763				2.189				6.54		23

Exploratory:
Productive		0		0		0		0		0		0
Dry		0		0		0		0		0		0

Total drilling activity		4.763		11		2.189		5		6.54		23

As of the date of this report, we are continuing drilling activities on our leasehold interests in an effort to further expand our producing wells.

Customers, Sales and Delivery

We store extracted oil in on-site bulk storage tanks awaiting delivery to our customers. Our customers pay all costs associated with transporting the oil from these storage tanks. In each of ~~2012~~2014 and ~~2011~~2013 we had two customers who represented 100% of our 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 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.

The following table presents information regarding production volumes and revenues, average sales prices and costs, after deducting royalties and interests of others, with respect to oil production attributable to our interest for the last three fiscal years. In the following table, average production cost are costs incurred to operate and maintain the wells and equipment and to pay the production costs, which does not include ad valoreum and severance taxes per unit of production, and is exclusive of work-over costs.

Year Ended December 31,

Oil production (Bbls)

~~2012~~2014

~~2011~~2013

~~2010~~2012

Production

~~2,260~~570.40

81,~~226~~667

112,~~350~~260

Average sales price ($)

9089.~~693~~49

9194.5704

7590.~~9625~~693

Average production cost ($)

~~110~~344.8297

64132.5376

21110.6182

Competition

We compete with major integrated oil and natural gas companies and independent oil and gas companies. Most of our competitors have substantially larger financial resources, operations, staffs and facilities and our competitors may be able to pay more for prospective oil and gas properties or prospects and to evaluate, bid for and purchase a greater number of properties and prospects than our financial or human resources permit. Given our size, limited operating history and limited financial resources there are no assurances we will ever be able to effectively compete in our segment.

Government Regulation

We are subject to numerous federal, ~~provincial,~~ state, ~~local~~ and ~~foreign~~local ~~country~~ laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil lease for the cost of pollution clean-up resulting from operations, subject the lessee to liability for pollution damages and require suspension or cessation of operations in affected areas. Although environmental requirements have a substantial impact upon the energy industry, as a whole, we do not believe that these requirements affect us differently, to any material degree, than other companies in our industry. All of the jurisdictions in which we operate have statutory provisions regulating the exploration for and production of crude oil. These provisions include permitting regulations regarding the drilling of wells, maintaining bonding requirements to drill or operate wells, locating wells, the method of drilling and casing wells, the surface use and restoration of properties upon which wells are drilled and the plugging and abandoning of wells. We have made and will continue to make expenditures in our efforts to comply with these requirements, which we believe are necessary business costs in the oil industry.

Changes to existing, or additions of, laws, regulations, enforcement policies or requirements in one or more of ~~the countries or~~ regions in which we operate could require us to make additional capital expenditures. ~~While~~Given ~~the~~our ~~events~~limited ~~in the U.S. Gulf of Mexico in 2010 resulted in the enactment of~~resources, ~~and may result in the enactment of~~ additional, ~~laws~~regulatory ~~or requirements regulating the discharge of materials into the environment~~burdens, weif ~~do not believe that any such regulations or laws~~ enacted, orwould ~~adopted~~adversely ~~as of this date will have a material adverse~~ impact on our ~~cost~~results of operations in future periods.

Employees

As of March 31, ~~2011~~2015, we had one full time employee, Mr. Page, our Chief Executive Officer and ~~one~~two part time ~~employee~~employees.

Our History

We were incorporated in Delaware on May 17, 1994 as CD Kidz Inc. On March 20, 1995, our name was changed to Wanderlust Interactive, Inc. In March 1996, we completed an initial public offering of our securities and the net proceeds were used principally to establish our New York headquarters and to produce two CD-ROM games based upon the Pink Panther character, which games were completed in September 1996 and September 1997, respectively. We initially marketed such games through distributors in the United States and licensed such games for distribution by others both in the United States and in over fifteen foreign countries.

In February 1997, we acquired all of the outstanding stock of Western Technologies, Inc. as well as certain assets and liabilities of Smith Engineering, a sole proprietorship, from Jay Smith III, our then President, Chief Executive Officer and Treasurer. Western Technologies designed and developed video and computer games and electronic toys and electronic consumer products, mostly pursuant to funded contracts with other name brand manufacturers. The agreement provided for the sale of 100% of the outstanding shares of stock of Western Technologies and certain assets and certain liabilities of Smith Engineering in exchange for 266,667 shares of our common stock. The cost of the acquired enterprise was $5,082,000. We assigned value of $15 per share to the shares issued and assumed liabilities in excess of assets which amounted to $1,082,000. As part of the acquisition, a license agreement was entered into between Western Technologies and Mr. Smith in which Mr. Smith granted to Western Technologies the exclusive right to use and market patents and license agreements owned by Mr. Smith.

After expending most of the funds raised in our initial public offering to produce the two Pink Panther CD-ROM games during 1996 and 1997, we realized that the development costs of such CD-ROM games greatly exceeded both the short-term and long-term anticipated revenue streams from such products and shifted our focus to pre-funded or contract design and development work, such as that historically conducted by Western Technologies. In September 1997, we substantially downsized our New York office and shifted our headquarters to Western Technologies’ offices located in Los Angeles. In April 1998, we closed our New York office permanently and consolidated our entire staff in our remaining Los Angeles office and production space.

On May 14, 1998, our name was further changed to Adrenalin Interactive, Inc. In December 1999, we completed a reverse merger with McGlen Micro, Inc., in which the stockholders of McGlen Micro, Inc. acquired control of us. As a result of the acquisition, each share of McGlen Micro, Inc. was converted into 0.0988961 shares of our common stock, with 2,548,553 shares being issued. On December 17, 1999, we changed our name to McGlen Internet Group, Inc. and on March 15, 2002, we changed our name to Northgate Innovations, Inc.

On March 20, 2002, we completed a reverse acquisition with Lan Plus Corporation in which the stockholders of Lan Plus acquired control of our company. As a result of the acquisition, each share of Lan Plus was converted into approximately 3.128 shares of our common stock, with approximately 14,113,000 shares being issued. In addition, immediately prior to the close of the merger, we instituted a 10:1 reverse stock split and the our accounts payable to, and advances from Lan Plus, in the amount of approximately $2.3 million were converted to common stock eliminating the debt; the stock was then retired to treasury and cancelled. Lan Plus was a manufacturer of branded turnkey computer products and services. Under our Northgate(R) brand name we developed, manufactured, marketed, and sold a wide range of desktop systems, notebook computers, workstations and network servers, as well as offering a variety of hardware components and peripherals to complement our desktop systems, notebook computers, and network servers.

In December 2003, an investor group acquired a majority of our outstanding common stock and in early 2004 this investor group brought in a new management team and implemented a new business strategy. As part of this new business strategy, in June 2004, we changed our name from Northgate Innovations, Inc. to Digital Lifestyles Group, Inc. Beginning in late 2004, we deemphasized the sale of our Northgate(R) brand products to focus our resources solely on the development, marketing and sale of a new product line, branded hip-e, which featured desktop computers, notebook computers and peripherals and was designed and targeted to the teen market.

In April 2005, we received notice from Microsoft Corporation that it had terminated our license to use its proprietary Windows(R) operating system due to our failure to make required royalty payments. Due to the loss of the license, we were unable to ship our products, the majority of which use Microsoft’s proprietary Windows(R) operating system and as a result we were unable to fulfill any orders for our hip-e brand desktop computers. As we lacked sufficient funds required to renew our license with Microsoft and were unable to distribute or sell our products, our management team decided to cease all operations other than to liquidate our assets for the benefit of a secured creditor.

Prior to our entry into the energy industry through the leasing of our first oil and gas property in the fourth quarter of 2009, we were a “shell company” as such term is defined in Rule 12b-2 under the Securities Exchange Act of 1934. As a result of entering into these leases and undertaking efforts to begin drilling operations on the sites we ceased to be a shell company.

On October 9, 2009 we changed our name to TN-K Energy Group Inc. to better reflect our current operations.

ITEM 1.A RISK FACTORS.

Before you invest in our securities, you should be aware that there are various risks. You should consider carefully these risk factors, together with all of the other information included in this annual report before you decide to purchase our securities. If any of the following risks and uncertainties develop into actual events, our business, financial condition or results of operations could be materially adversely affected.

Our auditors have raised substantial doubts as to our ability to continue as a going concern.

Our financial statements have been prepared assuming we will continue as a going concern. Since inception we have experienced recurring losses from operations, which losses have caused an accumulated deficit of approximately $16.081 million as of December 31, ~~2012~~2014. 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. We anticipate that we will continue to incur losses in future periods until we are successful in significantly increasing our revenues. There are no assurances that we will be able to raise our revenues to a level which supports profitable operations and provides sufficient funds to pay our obligations. If we are unable to meet those obligations, we could be forced to cease operations in which event investors would lose their entire investment in our company.

Our primary assets serve as collateral under a line of credit due to a related party. If we should default on this obligation, the holder could foreclose on our assets and we would be unable to continue our business and operations. The conversion of this obligation into shares of our common stock will be dilutive to our stockholders.

We have granted Mr. Daniel (Allen) Page, a related party and the lender under the line of credit, a security interest in all of our assets. At December 31, ~~2012~~2014 we owed $~~180~~170,000 of principal and $~~455~~3,214 of accrued unpaid interest under this credit line which matured in December ~~2011~~2013 and is now due on demand. If we should default under the repayment of this obligation, the Mr. Page could seek to foreclose on these assets in an effort to seek repayment under the obligation. If he was successful, we would be unable to conduct our business as it is presently conducted and our ability to generate revenue and fund our ongoing operations would be materially adversely affected. In such an event we would be forced to cease operations and stockholders would likely ~~loose~~lose their entire investment in our company. In addition, the principal and interest due under this credit line are convertible into shares of our common stock at conversion prices ranging from $0.12 to $0.35 per share, and we are obligated to issue him warrants upon the conversion of this obligation. The issuance of these securities will be dilutive to our existing stockholders.

We engage in a number of material transactions with a related party and there are no assurances the terms of these transactions are fair to our company.

As described later in this report under Part III, Item 13. Certain Relationships and Related Transactions, and Director Independence, during ~~2012~~2014 and 2013 we entered into a number of transactions with Mr. Daniel (Allen) Page. While not an officer or director of our company, in his role as a consultant to us he has the ability to exert significant influence on our business and operations. These affiliated transactions may, from time to time, result in a conflict of interest for our management. Because these transactions are not subject to the approval of our stockholders and were not negotiated on an arms-length basis, investors in our company are wholly dependent upon the judgment of our management in these related party transactions.

Our business model and growth strategies may not prove successful over the long-term.

Our ability to develop our operations in the energy sector is constrained by our limited working capital and size of our operations. While we have been able to acquire participating interests in producing wells, as well leasing unproven acreage for our drilling operations, using minimal amounts of cash by leveraging our common stock, it is possible that the value of the shares we have issued have exceeded the price we would have paid for the same assets had we been negotiating a cash transaction. In ~~2012~~2014 and 2013, we recognized an impairment of $177,516 and $~~216~~253,~~739~~682, respectively, net of income tax on various properties we acquired as the value of the reserves was less than the value of the shares we issued as consideration in the transaction. While we believe that the internally generated values we ascribed to the various assets to determine the purchase prices at the time of the acquisitions have a great likelihood of proving accurate over time as the wells are drilled, there are no assurance that our believe is correct. In addition, our business model envisions that we will continue to utilize our common stock to the extent possible in lieu of cash for future acquisitions of acreage and participating interests. There are no assurances we will be able to continue this model, which may hinder our ability to expand our acreage holdings which is a key factor to our future growth.

There are a number of external factors which impact our operating results which are beyond our control.

The oil gas produced by us must be marketed in order for our company to receive revenues. Oil prices are not regulated, but instead are subject to factors which are generally beyond our control, such as the supply and demand. For example, reduced oil demand and excess oil supplies will result in lower prices. Other factors affecting the price and marketing of oil and natural gas production, which are also beyond our control cannot be accurately predicted, are:

·● the cost, proximity, availability, and capacity of pipelines and other transportation facilities; ·● the price and availability of other energy sources such as coal, nuclear energy, solar, wind and alternative fuels;

·● local, state, and federal regulations regarding production, conservation, and transportation; ·● overall domestic and global economic conditions;

·● the impact of the U.S. dollar exchange rates on oil and natural gas prices; ·● technological advances affecting energy consumption;

·● governmental relations, regulations and taxation; ● the general level of supply and market demand for oil on a regional, national and worldwide basis and the impact of energy conservation efforts;

9● weather conditions and fluctuating seasonal supply and demand for oil and natural gas; ● economic and political instability, including war or terrorist acts in oil producing countries, including those of the Middle East, Africa and South America;

·● the ~~general~~amount ~~level~~of domestic production of ~~supply~~oil gas; and ~~market~~● ~~demand~~the ~~for~~amount and price of imports of oil onfrom aforeign ~~regional~~sources, ~~national~~which ~~and~~include ~~worldwide~~production ~~basis~~quotas ~~and~~for petroleum products from time to time with the ~~impact~~intent of ~~energy~~increasing, ~~conservation~~maintaining, ~~efforts;~~or decreasing price levels.

· weather conditions and fluctuating seasonal supply and demand for oil and natural gas; · economic and political instability, including war or terrorist acts in oil producing countries, including those of the Middle East, Africa and South America;

· the amount of domestic production of oil gas; and · the amount and price of imports of oil from foreign sources, which include production quotas for petroleum products from time to time with the intent of increasing, maintaining, or decreasing price levels.

We are unable to predict what effect these various factors will have on the future price of the oil, one or more of which will impact our revenues and profits in future periods.

We have a significant amount of past due debt.

At December 31, ~~2012~~2014, our balance sheet includes approximately $3.543 million of past due debt, including past due obligations and accrued expenses. The vast majority of these liabilities predate our current operations and our current management. We do not have the funds necessary to satisfy these obligations. There are judgments against our company for a significant amount of these past due obligations, all of which relate to obligations incurred prior to our current management. If one or more of these judgment creditors should attempt to collect the amounts due, it is unlikely that we would be able to continue our operations as they are presently conducted.

Estimates of oil reserves are inherently imprecise. Any material inaccuracies in these reserve estimates or underlying assumptions will affect materially the quantities and present value of our reserves.

The estimates of proved oil reserves and the future net cash flows attributable to those reserves were prepared by independent petroleum engineers and geologists. There are numerous uncertainties inherent in estimating quantities of proved oil reserves and cash flows attributable to such reserves, including factors beyond our control and that of our engineers. Reserve engineering is a subjective process of estimating underground accumulations of oil that cannot be measured in an exact manner. Different reserve engineers may make different estimates of reserves and cash flows based on the same available data. The accuracy of an estimate of quantities of reserves, or of cash flows attributable to such reserves, is a function of the available data, assumptions regarding future oil prices and expenditures for future development drilling and exploration activities, and of engineering and geological interpretation and judgment. Additionally, reserves and future cash flows may be subject to material downward or upward revisions, based upon production history, development drilling and exploration activities and the price of oil. Actual future production, revenue, taxes, development drilling expenditures, operating expenses, underlying information, quantities of recoverable reserves and the value of cash flows from such reserves may vary significantly from the assumptions and underlying information set forth herein.

Oil prices are volatile and significant decline in the price of crude oil will adversely impact our results in future periods.

Our revenues, profitability and liquidity are substantially dependent upon prevailing prices for oil, which can be extremely volatile. Even relatively modest drops in prices can significantly affect our financial results and impede our growth. Prices for oil may fluctuate widely in response to relatively minor changes in the supply of and demand for oil, market uncertainty and a wide variety of additional factors that are beyond our control, such as the domestic and foreign supply of oil; the price of foreign imports; the ability of members of the Organization of Petroleum Exporting Countries to agree to and maintain oil price and production controls; technological advances affecting energy consumption; domestic and foreign governmental regulations; and the variations between product prices at sales points and applicable index prices. Our operations are focused on oil exploration and production in the Appalachian Basin region of the United States. Regional oil prices may vary from national prices due to regional factors such as regional production being constrained by regional capacity.

Oil drilling operations are inherently risky.

The nature of the oil business involves a variety of risks, particularly the risk of drilling wells that are found to be unable to produce any oil at prices sufficient to repay the costs of the wells and the costs of producing the wells. We have recognized impairment expenses of $177,516 and $253,682 in 2014 and 2013, respectively. It is possible that in the future we ~~may~~will continue to recognize substantial impairment expenses when uneconomic wells and declines in oil prices result in impairments of the capitalized costs of our oil properties. The oil business also includes operating hazards such as fires, explosions, cratering, blow-outs and encountering formations with abnormal pressures. The occurrence of any of these risks could result in losses. The occurrence of any one of these significant events, if it is not fully insured against, could have a material adverse effect on our financial position and results of operations.

In our operations were we are the well operator, we utilize the services of independent drilling contractors. We do not carry insurance against well blow-outs and other unusual risks in the drilling, completion and operation of oil wells. In the event that fires, blow-outs and other events occur, our losses will not be covered by insurance and will have a material impact on our liquidity in future periods. If the scope of the accident is significant enough, it could cause us to cease a portion of our operations which would adversely impact our revenues in future periods. Our drilling activities also involve risks, such as drilling non-productive wells or dry holes, which are beyond our control. The cost of drilling and operating wells and of installing production facilities and pipelines is uncertain. Cost overruns are common risks that often make a project uneconomical. We may also decide to reduce or cease its drilling operations due to title problems, weather conditions or noncompliance with governmental requirements, all of which will adversely impact our results of operations in future periods.

We may be unable to find additional reserves.

Our revenues depend in part on whether we find or acquire additional reserves. Unless we conduct successful exploration and development activities, or acquire properties, our proved reserves will decline. Our future oil reserves and production as well as our cash flow and income are dependent on our ability to efficiently develop and exploit our current reserves and economically find or acquire additional reserves. Our planned exploration and development projects may not result in significant additional reserves, and we may be unable to drill productive wells at low reserve replacement costs.

We are subject to extensive government regulations.

Our business is affected by numerous federal, state and local laws and regulations, including energy, environmental, conservation, tax and other laws and regulations relating to the oil and gas industry. These include, but are not limited to:

	•	the prevention of waste,
	•	the discharge of materials into the environment,

	•	the conservation of oil and natural gas,
	•	pollution,

	•	permits for drilling operations,
	•	drilling bonds, and

•

reports concerning operations, spacing of wells, and the unitization and pooling of properties.

Failure to comply with any laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of injunctive relief, or both. Moreover, changes in any of the above laws and regulations could have a material adverse effect on our business. Concerns of global warming may result in changes to laws and regulations that increase the cost of oil operations and decrease the use and demand for crude oil. In view of the many uncertainties with respect to current and future laws and regulations, including their applicability to us, we cannot predict the overall effect of such laws and regulations on our future operations.

Shortages of rigs, equipment, supplies and personnel could delay or otherwise adversely affect our cost of operations or our ability to operate according to our business plans.

We hire independent drilling operators for our operations. While we have not experienced any shortages to date, it is possible that we may experience shortages of drilling and completion rigs, field equipment and qualified personnel which may cause delays in our ability to continue to drill, complete, test and connect wells to processing facilities. It is also possible that we could be subject to sharp increases in these costs. The demand for and wage rates of qualified drilling rig crews generally rise in response to the increased number of active rigs in service and could increase sharply in the event of a shortage. Shortages of drilling and completion rigs, field equipment or qualified personnel could delay, restrict or curtail our exploration and development operations, which may materially adversely affect our business, financial condition and results of operations.

The tradability of our common stock is limited under the penny stock regulations which may cause the holders of our common stock difficulty should they wish to sell the shares.

Because the quoted price of our common stock is less than $5.00 per share, our common stock is considered a “penny stock,” and trading in our common stock is subject to the requirements of Rule 15g-9 under the Securities Exchange Act of 1934. Under this rule, broker/dealers who recommend low-priced securities to persons other than established customers and accredited investors must satisfy special sales practice requirements. The broker/dealer must make an individualized written suitability determination for the purchaser and receive the purchaser’s written consent prior to the transaction.

SEC regulations also require additional disclosure in connection with any trades involving a “penny stock,” including the delivery, prior to any penny stock transaction, of a disclosure schedule explaining the penny stock market and its associated risks. These requirements severely limit the liquidity of securities in the secondary market because few broker or dealers are likely to undertake these compliance activities and this limited liquidity will make it more difficult for an investor to sell his shares of our common stock in the secondary market should the investor wish to liquidate the investment. In addition to the applicability of the penny stock rules, other risks associated with trading in penny stocks could also be price fluctuations and the lack of a liquid market.

ITEM 1B. UNRESOLVED STAFF COMMENTS.

Not applicable to a smaller reporting company.

ITEM 2. DESCRIPTION OF PROPERTY.

Principal executive office

Our principal executive offices are located in approximately 1,200 square feet of office space which we rent from an unrelated third party on a month to month basis for a monthly rental of $350. While these facilities are suitable for our needs for foreseeable future, we may elect to move our offices closer to our drilling operations. In that event, we do not anticipate that we would have any difficulty in leasing suitable office space upon similar terms.

Oil and gas properties

Information on our oil and gas properties appears earlier in this report under Item 1. Business.

ITEM 3. LEGAL PROCEEDINGS.

We are not a party to any pending or threatened litigation.

ITEM 4. MINE SAFETY DISCLOSURES.

Not applicable to our operations.

PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.

Our common stock is quoted in the OTC Markets OTCQB tier under the symbol TNKY. The reported high and low last sale prices for the common stock are shown below for the periods indicated. The quotations reflect inter-dealer prices, without retail mark-up, markdown or commission, and may not represent actual transactions.

	High		Low
2011
2014
First quarter ended March 31, 2011	$	0.30	$	0.17
First quarter ended March 31, 2014	$	0.15	$	0.09
Second quarter ended June 30, 2011	$	0.24	$	0.12
Second quarter ended June 30, 2014	$	0.23	$	0.08
Third quarter ended September 30, 2011	$	0.21	$	0.10
Third quarter ended September 30, 2014	$	0.19	$	0.11
Fourth quarter ended December 31, 2011	$	0.34	$	0.09
Fourth quarter ended December 31, 2014	$	0.14	$	0.05
2012
2013
First quarter ended March 31, 2012	$	0.53	$	0.22
First quarter ended March 31, 2013	$	0.48	$	0.20
Second quarter ended June 30, 2012	$	0.55	$	0.31
Second quarter ended June 30, 2013	$	0.45	$	0.26
Third quarter ended September 30, 2012	$	0.45	$	0.25
Third quarter ended September 30, 2013	$	0.29	$	0.15
Fourth quarter ended December 31, 2012	$	0.42	$	0.23
Fourth quarter ended December 31, 2013	$	0.25	$	0.11

The last sale price of our common stock as reported on the OTC Markets OTCQB tier was $0.4009 per share on ~~April~~June 810, ~~2013~~2015. As of ~~April~~June 810, ~~2013~~2015, there were approximately ~~134~~125 record owners of our common stock.

Dividend Policy

We have never paid cash dividends on our common stock. Under the terms of the Security Agreement with a related party described elsewhere herein, we are prohibited from declaring and paying dividends so long as there are amounts outstanding under the related secured credit line. Under Delaware law, we may declare and pay dividends on our capital stock either out of our surplus, as defined in the relevant Delaware statutes, or if there is no such surplus, out of our net profits for the fiscal year in which the dividend is declared and/or the preceding fiscal year. If, however, the capital of our company, computed in accordance with the relevant Delaware statutes, has been diminished by depreciation in the value of our property, or by losses, or otherwise, to an amount less than the aggregate amount of the capital represented by the issued and outstanding stock of all classes having a preference upon the distribution of assets, we are prohibited from declaring and paying out of such net profits and dividends upon any shares of our capital stock until the deficiency in the amount of capital represented by the issued and outstanding stock of all classes having a preference upon the distribution of assets shall have been repaired.

Recent Sales of Unregistered Securities

None except as previously reported.

Issuer Purchases of Equity Securities

None.

ITEM 6. SELECTED FINANCIAL DATA.

Not applicable to a smaller reporting company.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

The following discussion of our financial condition and results of operations for ~~2012~~2014 and ~~2011~~2013 should be read in conjunction with the 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, Cautionary Notice Regarding Forward-Looking Statements and Business sections in this Form 10-K. 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 prove reserves and to continue our acreage acquisitions while maintaining balanced, prudent financial management. . In the past three recent 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 ana royalty interest, ~~receive a finder’s fee,~~ 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. From time to time we sell working interests in wells. In ~~2011~~2014, we ~~had~~have sold working ~~interests~~interest in 5 of our wells ranging from 2037.5% to 3550% working and royalty interest per well and for each well we are responsible for completion and operating costs on those wells ranging from 2550% to 5850% per well, ~~which lead~~ to ~~the~~two ~~negotiations~~individuals ~~of overriding royalty interest of 5% per existing wells. In 2012, we had sold our 27.5% working interests in 38 wells. We are responsible for 33.33% of future completion~~ and/or ~~operating~~entities ~~costs~~ on ~~those wells. These terms have led to~~ the ~~negotiations~~Millard ofWillis, ~~overriding~~William ~~royalty~~Warren ~~interest of 5% per each of these existing wells~~ and ~~will~~Billy ~~allow~~Walker ~~us to move forward in drilling a greater number of wells, at minimal costs, than we would otherwise able to drill based upon our limited financial resources~~lease. We expect to continue to use these types of relationships to partially or completely fund initial drilling of future wells.

During ~~2013~~2014, we plan to continue to expand our acreage position in our core area, focusing on acreage we will operate. In ~~addition~~2014, to the ~~challenges~~Company ~~faced~~entered byinto ~~small~~an ~~independent~~agreement ~~oil~~between ~~and~~the ~~gas~~Company ~~companies,~~and weMr. ~~continue~~Daniel to(Allen) ~~face~~Page, a ~~number~~related party, of ~~challenges~~50% interest in ~~executing~~an ~~our~~87.5% ~~business~~working ~~model~~interest ~~which~~lease ~~are~~with ~~particular~~approximately to68 ~~our~~acres ~~company.~~named Atthe ~~December~~Johnny ~~31,~~Ringley ~~2012~~lease ~~our~~located ~~balance~~in ~~sheet~~Cumberland ~~includes~~County, ~~approximately $3~~Kentucky.5 ~~million~~The ofCompany ~~obligations,~~also aentered ~~substantial~~into ~~portion~~an operating agreement of ~~which~~an ~~relates~~87.5% toworking ~~the~~interest ~~prior~~lease ~~business~~with ofapproximately ~~our~~640 ~~company~~acres ~~before~~named ~~those~~the ~~operations~~William ~~were~~Warren ~~discontinued~~II lease located in ~~2005.~~Overton ~~Other~~County, ~~than~~Kentucky. ~~the~~In ~~secured~~addition ~~credit~~to ~~line~~the ~~due~~challenges afaced ~~related~~by ~~party,~~small ~~none~~independent ofoil ~~the~~and ~~remaining~~gas ~~obligations~~companies, ~~represent~~we ~~secured~~continue ~~debt,~~to ~~although~~face a number of ~~the~~challenges ~~creditors~~in ~~have~~executing ~~obtained~~our ~~judgments~~business ~~against~~model which are particular to our company. WeOur dototal ~~not~~revenues ~~have~~decreased ~~the~~67% in ~~resources~~2014 tofrom ~~satisfy~~the ~~these~~comparable ~~obligations.~~period Ifin ~~one~~2013 orwhich ~~more~~attributed ofto ~~these~~the ~~judgment~~sale ~~creditors~~of ~~should~~oil ~~seek~~and togas ~~enforce~~leases during the ~~judgment~~2013 period, ~~our~~as ~~ability~~well toas ~~continue~~a ~~our~~lower ~~operations~~amount asof ~~they~~natural depletion of wells and downtime which are ~~presently~~the ~~conducted~~effects isof inour ~~jeopardy~~decision to reduce drilling and completion cost through negotiated sales.

1314

WeAt ~~also~~December ~~face~~31, ~~the~~2014 ~~challenge~~and of2013, ~~limited~~our ~~personnel~~balance ~~and~~sheet ~~diversion~~includes ofapproximately ~~our~~$3.609 ~~management’s~~million ~~time~~ and ~~attention~~$3.627 Inmillion ~~2011~~of weobligations, ~~hired~~ a ~~part-time~~substantial ~~accountant,~~portion ~~but~~of aswhich ~~our~~relates ~~company continues~~ to ~~grow, we need hire additional staff to handle~~ the ~~increasing~~prior ~~needs~~business of our company, ~~including~~before ~~from~~those anoperations ~~administrative~~were ~~standpoint,~~discontinued ~~and we need to invest~~ in ~~internal systems to ensure that our financial statements are properly prepared~~2005. ~~Lastly,~~ weOther ~~need~~than tothe 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~~line bydue ~~Mr. Daniel (Allen ) Page,~~ a related party, ~~which~~none ~~matured~~of inthe ~~December~~remaining ~~2011~~obligations ~~and~~represent issecured ~~due on demand. As described elsewhere herein~~debt, inalthough ~~April~~a ~~2012~~number weof ~~granted~~the ~~Mr.~~creditors ~~Daniel~~have (obtained ~~Allen~~judgments )against ~~Page~~our acompany. ~~security~~We ~~interest~~do innot ~~all~~have ofthe ~~our~~resources ~~assets~~to assatisfy ~~collateral~~these ~~for this obligation~~obligations. At ~~December~~If ~~31,~~one ~~2012,~~or ~~$180,000~~more isof ~~outstanding~~these ~~under~~judgment ~~this~~creditors ~~facility~~should ~~which~~seek isto ~~the~~enforce ~~maximum amount available as~~ the ~~credit~~judgment, ~~line~~our ~~matured~~ability into ~~December~~continue ~~2011. The amount is convertible into shares of~~ our ~~common~~operations ~~stock~~as atthey ~~various prices, but there~~ are nopresently ~~assurances~~conducted ~~the~~is ~~holder~~in ~~will convert the obligation~~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 part-time project coordinator, but as our company continues to grow, we need 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. Historically, we have been relying upon 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. As described elsewhere herein, in April 2012 we granted Mr. Daniel (Allen) Page a security interest in all of our assets as collateral for this obligation. At December 31, 2014, $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.

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

~~While~~We we reported net ~~income~~loss of $~~4.0~~673,849 ~~million~~ for ~~2012,~~2014 ~~these operating results are primarily attributable to one-time transactions~~ and ~~non-cash gains. At December 31, 2012~~ we had an accumulated deficit of approximately $16.081 million. The report of our independent registered public accounting firm on our financial statements for the year ended December 31, ~~2012~~2014 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

We generally generate ~~revenues from sales of oil, well services, sales of oil and gas leases and finder’s fees. During 2012, we have also generated one time revenues from commissions. Our~~ revenue ~~in revenues~~ from oil sales is generated both from wells in which we are the operator as well as those in which we have a working interest., ~~Our~~as ~~revenues~~well ~~from all sources in 2012 was substantially comparable~~ as ~~2011, however, our revenues~~ from well ~~oil~~services ~~sales decreased by 73% in 2012 from 2011 primarily as a result of the natural depletion of wells, downtime,~~ and ~~the~~ sales of ~~our portions of working~~ interest in oil ~~leases. During 2012, the average sales price (net of taxes~~ and ~~transfers)~~gas ~~per~~leases ~~unit of oil extracted from wells drilled by us was approximately $90.69 as compared~~ to ~~approximately~~third ~~$90.04~~parties inand ~~2011. Commission~~finder’s ~~revenues represent~~ fees wefor ~~receive from recorded from~~ the culmination of the sale of oil well interests between third parties. We ~~did~~While ~~not~~oil ~~have~~sales ~~any~~revenues ~~comparable~~are ~~transactions~~constant infrom ~~2011. Finder’s~~period ~~fee~~to ~~revenues~~period, ~~which~~revenues ~~represents fees we receive~~ from ~~recorded~~sales ~~from the culmination~~ of ~~the sale of~~ oil ~~well~~and ~~interests~~gas ~~between~~leases ~~third parties, declined 13% in 2012 from 2011. Well services~~ and ~~rentals,~~finder’s ~~which represents~~ fees weare ~~receive~~transaction ~~from for~~based ~~the oversight~~ on ~~the~~one-time ~~oil~~for ~~well interests we do not own, but manage~~ the ~~production~~particular ontransaction. ~~such~~Revenues ~~non-owned~~generated ~~oil~~from well ~~interests,~~services ~~declined~~can ~~97%~~also influctuate ~~2012~~dramatically from ~~2011. This~~period ~~decrease is primarily attributable~~ to ~~the~~period. ~~sale~~As ~~of a major portion of our producing oil wells~~such, ~~which~~we ~~had~~may ~~other~~not ~~third~~report ~~party~~revenues ~~minority~~from ~~oil~~those ~~well~~sources ~~interests,~~in ~~which~~all ~~we had production oversight~~periods. ~~Included~~ inOur revenues infrom ~~2012~~all ~~was~~sources ~~also revenue of $1.2 million~~ in ~~sales~~2014 ofwere ~~oil~~substantially ~~and~~less ~~gas~~when ~~leases,~~compared anto ~~increase~~2013 ofdue ~~27%~~to ~~from~~low ~~2011,~~production ofincome ~~which~~as ~~$23,000 is attributable to~~ the ~~sales~~weather toconditions ~~third~~were ~~parties~~unfavorable offor ~~various~~pumping ~~interests~~during inthe ~~wells~~period ~~and~~as $1well ~~million~~as ~~is attributable to~~ the ~~sales~~sale of ~~the~~some ~~Junior~~producing ~~and~~wells ~~Pansy~~in ~~Clark lease~~2013.

~~Our~~During ~~total operating expenses in 2012 decreased approximately 40.5% from 2011. Oil lease operating expenses~~2014, ~~which~~the ~~include~~average ~~our~~sales ~~portion~~price of(net ~~the cost~~ of ~~contract~~taxes ~~drillers,~~and ~~other~~transfers) ~~expenses~~per ~~associated~~unit ~~with~~of ~~the~~oil ~~drilling~~extracted ~~operations~~from ~~and~~wells ~~depletion~~drilled ~~expense,~~by ~~were~~us ~~122%~~was ofapproximately ~~oil~~$89.49 ~~sales revenues in 2012~~ as compared to 70approximately $94.5%04 ~~of oil sales revenues~~ in ~~2011~~2013. ~~The~~During ~~declines~~the in2014 ~~margins~~compared ~~for~~to ~~our~~2013, ~~oil~~the ~~sales~~average ~~are~~number ~~attributable to our sale~~ of ~~the~~barrels ~~Clark~~sold ~~oil~~was ~~lease~~approximately 779 inand ~~April~~1,667, ~~2012~~respectively. ~~Cost~~ ofOur revenues from oil ~~and~~sales ~~gas~~decreased ~~leases~~by ~~sold~~56% in ~~2012~~2014 ~~were~~from ~~36%~~2013 ofprimarily ~~the~~as ~~revenue~~a ~~from~~result ~~the sale~~ of the ~~oil~~natural ~~and~~depletion ~~gas~~of ~~leases~~wells, asdowntime, ~~compared~~and tothe ~~84.8%~~sales inof ~~2011. The~~our ~~decline~~portions isof ~~attributable~~working tointerest ~~our lower cost~~ in ~~the~~oil ~~Junior and Pansy Clark lease~~leases.

~~During~~Our ~~2012~~total ~~our~~operating ~~sales,~~expenses ~~general~~in ~~and~~2014 ~~administrative~~increased ~~expenses decreased~~ approximately 2013% from ~~2011 which~~2013. The increase is ~~primarily~~directly ~~attributable~~related to ~~lower~~the ~~compensation~~operator’s ~~and~~year-end ~~compensation~~reporting ~~related~~of ~~benefits. Included~~wells inthat ~~sales,~~the ~~general~~Company ~~and~~was ~~administrative~~receiving ~~expenses~~overriding royalty interest in ~~2012~~recording isimpairment. ~~consulting~~Oil ~~expenses~~lease ofoperating ~~$49~~expenses,~~566~~ ~~paid~~which toinclude aour ~~related~~portion ~~party,~~of ~~and~~the ~~$26,616~~cost of ~~non-cash~~contract ~~depreciation~~drillers, ~~expense. In~~other ~~2012~~expenses ~~the~~associated ~~amount~~with ofthe ~~impairment~~drilling ofoperations ~~developed~~and ~~properties~~depletion expense, ~~which~~were ~~represents~~282% ~~the~~of ~~cost~~oil ofsales ~~dry~~revenues ~~holes~~in ~~drilled,~~2014 ~~declined~~as ~~27.7%~~compared ~~from~~to ~~2011. Although~~141% weof ~~experienced~~oil asales ~~decrease~~revenues in ~~operating~~2013. ~~expenses~~The inincrease ~~2012,~~is wedirectly ~~anticipate~~related ~~our~~to ~~operating~~the ~~expenses~~non-cash ~~will~~stock ~~continue~~compensation toexpense ~~increase~~incurred inwith ~~2013~~the ~~which~~issuance ~~will~~of bestock ~~reflective~~options ofand ~~our~~the ~~increased~~declines ~~business~~in ~~operations.~~margins Wefor our oil sales are ~~not~~attributable ~~able~~to atthe ~~this~~natural ~~time~~depletion of wells, ~~however~~downtime, toand ~~quantify~~ the ~~amount~~sales of ~~the~~our ~~expected~~portions ~~increase~~of working interest in oil leases which historically had higher margins.

14Cost of oil and gas leases sold in 2014 were 6% of the revenue from the sale of the oil and gas leases, as compared to 9% in 2013 as the cost of oil and gas sold were minimized resulting from our new package drilling which lowered our overall drilling and completion costs associated with joint ventured wells.

Included in our total other income during 2012 is non-cash gains on derivatives of $1.2 million as compared to $289,000 in 2011. These gains on derivatives consists of non-cash gains related to the write-off of the Alloy note in the first quarter of 2012 based upon the statute of limitations on the enforceability of this obligation and are associated with the change in the fair value of derivative liabilities. The difference in fair value of the derivative liabilities between the date of their issuance and their measurement date has been recognized as other income in those periods.15

~~Also~~During ~~included~~2014, in our ~~total~~sales, ~~other~~general ~~income~~and inadministrative ~~2012~~expenses increased approximately 73% from 2013 which is primarily attributable to the non-cash ~~gain~~stock ofcompensation ~~$1.7~~expense ~~million~~incurred ~~from~~with the ~~write-off~~issuance of ~~aged~~stock ~~accounts~~options. ~~payable~~Included in sales, general and ~~gain~~administrative onexpenses ~~debt~~in ~~relief~~2014 is consulting expenses of $51,768 paid to Mr. ~~This~~Daniel ~~gain~~(Allen) isPage, ~~one-time~~a related party, an increase 2% over 2013, and ~~not~~$26,259 ~~related~~of tonon-cash ~~our~~depreciation ~~operating~~expense, ~~performance~~increase of 16% from 2013.

During ~~2012~~2014, we recognized aan ~~gain~~impairment expense of $~~742~~177,~~700~~516 oncompared ~~liquidated~~to ~~damages~~$253,682 in 2013. These impairment expenses are related to ~~registration~~impairment ~~rights~~of ~~granted~~developed byproperties ~~our~~as ~~prior~~we ~~management,~~have ~~associated~~determined ~~with~~that the ~~interest~~carrying ~~accrued~~value ~~for~~of ~~the~~these ~~conversion~~assets ~~note~~is oflikely not recoverable. Given the ~~Woods~~nature ~~note~~of ~~and~~our ~~the~~operations ~~gain~~it asis likely we will recognize comparable expenses in future periods. Although we experienced a ~~result~~decrease in operating expenses in 2014, we anticipate our operating expenses will increase in 2014 which will be reflective of our increased business operations. We are not able at this time, however, to quantify the ~~write-off~~amount of the ~~Alloy~~expected ~~promissory note~~increase.

~~Our~~During 2014, our interest expense ~~during~~was ~~2012 of~~ $1614,~~000~~024 ~~significantly decreased, as~~ compared to ~~2011;~~ $~~144~~15,~~000~~100; asrespectively. aThe decreased is the result of the decreased amounts outstanding principal under the ~~secured~~ 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 December 31, ~~2012~~2014, we had a working capital deficit of $3,~~142~~443,~~186~~981 as compared to a working capital deficit of $63,~~078~~096,~~670~~764 at December 31, ~~2011~~2013. Our current liabilities at December 31, ~~2012~~2014 include approximately $3.56 million of accounts payable and accrued expenses. Included in our accrued expenses at December 31, ~~2012~~2014 is approximately $3145,~~000~~900 of consulting expenses accruing from first quarter 2013, due a related party, and approximately $154,000 of accrued taxes. In addition, at December 31, ~~2012~~2014 we owe a related party $~~180~~170,000 of principal and $~~455~~3,214 of accrued interest under a secured line of credit described below.

Net cash ~~provided~~used by operating activities for ~~2012~~2014 was $~~316~~62,~~409~~019 as compared to net cash ~~used~~provided inby operating activities of $~~726~~326,~~848~~067 for ~~2010~~2013. ~~The~~During ~~change reflects~~ the ~~decreased~~2014 ~~net~~period, ~~income~~we ~~directly~~primarily ~~related~~used cash to ~~the~~fund ~~sales~~our ofloss ~~oil~~and ~~production.~~reduce ~~Net~~our ~~cash~~accounts ~~used~~payable inand ~~investing~~accrued ~~activities~~expenses. inDuring ~~2012~~the ~~was~~2013 ~~$29~~period,~~397~~ ~~and~~cash ~~reflects~~was ~~the~~provided ~~sale~~by ofour ~~oil~~net ~~and~~income ~~gas leases~~ and ~~fixed~~increases ~~assets, net of the sale of working interest~~ in ~~certain of~~ our ~~wells~~accounts ~~and~~payable ~~the~~offset ~~refund~~by ofincreased ~~ARO~~in ~~deposits~~accounts receivable. Net cash ~~provided~~used byin investing activities in ~~2011~~2014 was $284,155 reflected the sale of oil and gas rights, net of purchase of oil and gas rights and purchase of fixed assets. We ~~did~~Net ~~not generate any~~ cash ~~from~~used by financing activities infor ~~2012~~2014 was $10,000 and $0 for 2013.

Secured line of credit with Mr. Daniel (Allen) Page.

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. Daniel (Allen) 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. Daniel (Allen) 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, and to extend the maturity date of the note to December 31, 2009. 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. Daniel (Allen) 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. Daniel (Allen) Page extended the due date of the note to December 31, 2010.

1516

Effective December 13, 2010, we 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 to December 31, ~~2011~~2012. The Convertible Line of Credit is now due on demand. In April 2012, we entered into a Security Agreement with Mr. Daniel (Allen) Page to provide collateral for the repayment of this obligation. The Security Agreement provides that if there is an “event of default” under the agreement, the lender is entitled to take possession of our assets. Events of default include, among other items, (i) a failure to pay the obligations when due, (ii) a judgment in excess of $10,000, (iii) appointment of a receiver or an event of bankruptcy, or (iii) a breach by us of any covenant of the Security Agreement. Under the terms of the Security Agreement, we also agreed not to take certain actions, including:

	•	not incur additional indebtedness, other than trade payables and certain permitted liens,
	•	declare or pay any dividends on our securities,
	•	prepay any indebtedness,
	•	make any advances or loans to any person,
	•	assume, guaranty or otherwise become liable for the debt of any other person,
	•	enter into any merger, consolidation or other reorganization or acquire all or any assets of another business,
	•	form a subsidiary or enter into any partnership or joint venture,
	•	materially change the nature of our business,
	•	enter into any transaction with an affiliate except in the ordinary course on arms-length terms or
	•	bill any receivable under any other name than our corporate name.

Recent Accounting Pronouncements

InAll ~~May~~other newly ~~2011, the FASB~~ issued ~~ASU~~but ~~2011-04,~~not ~~“Fair~~yet Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRS,” (“ASU 2011-04”). This standard results in a common requirement between the FASB and the International Accounting Standards Board for measuring fair value and disclosing information about fair value measurements. ASU 2011-04 is effective ~~for~~accounting ~~fiscal~~pronouncements ~~years~~have ~~and~~been ~~interim~~deemed ~~periods~~to ~~beginning~~either ~~after December 15, 2011. We do~~ not ~~expect~~be ~~the~~relevant ~~adoption~~or ofimmaterial ~~this accounting pronouncement~~ to ~~have~~the ~~any~~operations ~~effect on our financial position~~ and ~~results~~reporting disclosures of ~~operations~~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.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

Not applicable for a smaller reporting company.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

Please see our Financial Statements beginning on page F-1 of this annual report.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.

On October 23, 2012, we dismissed Sherb & Co., LLP as our independent registered public accounting firm and engaged Liggett, Vogt & Webb, P.A. as our independent registered public accounting firm. Sherb & Co., LLP audited our financial statements for the periods ended December 31, 2011 and 2010. The dismissal of Sherb & Co., LLP was approved by our Board of Directors on October 23, 2012. Sherb & Co., LLP did not resign or decline to stand for re-election.

Neither the report of Sherb & Co., LLP dated April 13, 2012 on our balance sheets as of December 31, 2011 and 2010 and the related statements of operations, stockholders' deficit, and cash flows for the years ended December 31, 2011 and 2010 nor the report of Sherb & Co., LLP dated April 13, 2011 on our balance sheets as of December 31, 2010 and 2009 and the related statements of operations, stockholders' deficit, and cash flows for the years ended December 31, 2010 and 2009 contained an adverse opinion or a disclaimer of opinion, nor were either such report qualified or modified as to uncertainty, audit scope, or accounting principles, except that both such reports raised substantial doubts on our ability to continue as a going concern.

During our two most recent fiscal years and the subsequent interim period preceding our decision to dismiss Sherb & Co., LLP we had no disagreements with the firm on any matter of accounting principles or practices, financial statement disclosure, or auditing scope of procedure which disagreement if not resolved to the satisfaction of Sherb & Co., LLP would have caused it to make reference to the subject matter of the disagreement in connection with its report.

During our two most recent fiscal years and the subsequent interim period prior to retaining Liggett, Vogt & Webb, P.A. (1) neither we nor anyone on our behalf consulted Liggett, Vogt & Webb, P.A. regarding (a) either the application of accounting principles to a specified transaction, either completed or proposed, or the type of audit opinion that might be rendered on our financial statements or (b) any matter that was the subject of a disagreement or a reportable event as set forth in Item 304(a)(1)(iv) and (v), respectively, of Regulation S-K, and (2) Liggett, Vogt & Webb, P.A. did not provide us with a written report or oral advice that they concluded was an important factor considered by us in reaching a decision as to accounting, auditing or financial reporting issue.

ITEM 9A. 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 Annual Report on Form 10-K, 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 material weaknesses in our internal control over financial reporting as described below.

The material weakness identified are related to insufficient personnel and accounting resources are not 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. In addition, during 2012 we failed to timely file a Current Report on Form 8-K. Due to these material weaknesses, in preparing our financial statements for the year ended December 31, 2012 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. While we hired an experienced accountant in 2011 in an effort to mitigate to an extent these material weaknesses, she is a part-time employee and we continue to lack sufficient personnel and resources to ensure 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, we expect that the material weaknesses in our disclosure controls and procedures will continue in 2013 until such time as we devote a portion of our limited resources to expanding our personnel and providing greater resources to our accounting staff.

Management’s Report on Internal Control over Financial Reporting. Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. Our internal control over financial reporting is designed 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. Our internal control over financial reporting includes those policies and procedures that:

• pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;

• provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and

• provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.

A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis. A significant deficiency is a deficiency, or a combination of deficiencies, in internal control over financial reporting that is less severe than a material weakness; yet important enough to merit attention by those responsible for oversight of the company’s financial reporting. Because of the inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Our management assessed the effectiveness of our internal control over financial reporting as of December 31, ~~2012~~2014. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control-Integrated Framework. Management's assessment included an evaluation of the design of our internal control over financial reporting and testing of the operational effectiveness of these controls. Based on this assessment, our management has concluded that as of December 31, ~~2012~~2014, our internal control over financial reporting was not effective to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with U.S. generally accepted accounting principles as a result of the material weaknesses ~~identified in our disclosure controls and procedures as described earlier in this section~~.

17The material weaknesses identified are related to insufficient personnel and accounting resources are not 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. Due to these material weaknesses, in preparing our financial statements for the year ended December 31, 2014 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. While we hired an experienced accountant in 2011 in an effort to mitigate to an extent these material weaknesses, she is a part-time employee and we continue to lack sufficient personnel and resources. Although we believe the possibility of errors in our financial statements is remote, until such time as we hire a full time principal financial officer and expand our staff with qualified personnel, we expect to continue to report material weaknesses in our internal control over financial reporting.

Changes in Internal Control over Financial Reporting.

There have been no changes in our internal control over financial reporting during our fourth fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

ITEM 9B. Other Information.

None.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.

Executive officers and directors

Name	Age	Positions
Ken Page	4043	Chairman of the Board, Chief Executive Officer, President, Secretary
Brad McNeil	4548	Director

Ken Page. Mr. Page has served as Chairman of the Board and Chief Executive Officer of our company since September 2007. Prior to joining the company, in 2006 Mr. Page was an associate broker with No. 1 Quality Realty in Tennessee. From 2002 to 2006, Mr. Page was a programmer with S &S Precision Inc., a Tennessee manufacturer of industrial molds, tool and die material and packing.

Brad McNeil. Mr. McNeil has been a member of our Board of Directors since October 2007. Since 2000 Mr. McNeil has been the Plant Manager for Certified Cylinder, Inc., a Tennessee tank refurbisher. In addition, during the past 1720 years Mr. McNeil has provided part-time field work for independent oil operators.

There are no family relationships between our officers and directors. Each director is elected at our annual meeting of stockholders and holds office until the next annual meeting of stockholders, or until his successor is elected and qualified.

Consulting Agreement with Daniel (Allen) Page

Since March 2010 we have been a party to a consulting agreement with Mr. Daniel (Allen) Page. Mr. Daniel (Allen) Page, a principal stockholder of our company, is also the father of our Chief Executive Officer. Under the terms of the most recent agreement with Mr. Daniel (Allen ) Page entered into in August 2012, he provides a variety of consulting services to us, including:

•

providing advice to us on matters related to our current and future drilling operations and overseeing certain of our drilling operations,

•

advising us on potential lease acquisitions and assisting our company in negotiations to expand our lease holdings,

•

assisting with the strategic analysis of our business objectives and assisting in the implementation of a strategic plan for our company, with a view towards enabling us to achieve our financial goals;

•

providing in-depth consultations to our management and Board of Directors to determine the amount and structure of the capital sought by our company;

•

assisting us with investor relations services, and

•

providing such additional general business advisory services as we may request from time to time

Under the terms of the 2012 agreement we agreed to pay Mr. Daniel (Allen) Page a fee of $4046,000 and pay his expenses incurred in providing the services to us up to a maximum of $1,000 per month. We also provide Mr. Page with the full-time use of a company-owned vehicle as additional compensation. The initial term of the agreement is one year and the term automatically expands for successive one year terms unless either we or Mr. Page provide notice of non-renewal at least 60 days prior to the expiration of the then current term. The agreement contains customary confidentiality provisions. As of December 31, ~~2012~~2014, we have accrued as a liability an aggregate of $3145,~~149~~866 under this agreement.

We are also a party to a number of additional transactions with Mr. Daniel (Allen) Page as described later in this report under Part III, Item 13. Certain Relationships and Related Transactions, and Director Independence. While he has not been elected as a member of our Board of Directors or appointed as an officer of our company, as a result of the scope of his services to us and the level of influence he has over our business and operations. Mr. Daniel (Allen) Page ~~could~~is be deemed to be a control person of our company within the meaning of Rule 405 of the Securities Act of 1933.

1819

Director Qualifications, Committees of our Board of Directors and the Role of our Board in Risk Oversight

We are a small company and we only recently begun operating in the energy sector during the fourth quarter of 2009. Mr. Page and Mr. McNeil were appointed to our Board of Directors in September 2007 and October 2007, respectively, at the time when we were a shell company. While Mr. Page and Mr. McNeil have remained members of our Board of Directors, we believe they each remain a good fit for our current needs. Mr. Page’s family has interests in oil and gas operations in Tennessee and Kentucky and through this family business Mr. Page brought both a practical understanding of the geographic particularities and as well as hands-on experience in our business sector to our Board. Since beginning operations in the energy sector, his relationships with landowners and independent drilling rig operators have facilitated our ability to quickly expand our business and develop revenue producing operations while conserving our limited capital. Mr. McNeil’s experience in field work with independent oil operators in Tennessee and Kentucky provides him with an enhanced understanding of our operations which provides an additional dimension to his role as an independent director.

Mr. Page serves as both our Chief Executive Officer and as one of the two members of our Board of Directors. Mr. McNeil is considered an independent director, but is not considered a “lead” independent director. The business and operations of our company are managed by our Board as a whole, including oversight of various risks, such as operational and liquidity risks that our company faces. Management is responsible for the day-to-day management of the risks we face, while the Board, as a whole, has responsibility for the oversight of risk management. In his role and as independent director, Mr. McNeil meets regularly with Mr. Page to discuss strategy and risks we face and to address any questions or concerns he may have on risk management and any other matters. We have not established any committees, including an Audit Committee, a Compensation Committee or a Nominating Committee, any committee performing a similar function. The functions of those committees are being undertaken by Board of Directors as a whole. Because we have only two directors, one of which is not independent, we believe that the establishment of these committees would be more form over substance.

We have not established any committees, including an Audit Committee, a Compensation Committee or a Nominating Committee, any committee performing a similar function. The functions of those committees are being undertaken by Board of Directors as a whole. Because we have only two directors, one of which is not independent, we believe that the establishment of these committees would be more form over substance.

We do not have a policy regarding the consideration of any director candidates which may be recommended by our stockholders, including the minimum qualifications for director candidates, nor has our Board of Directors established a process for identifying and evaluating director nominees, nor do we have a policy regarding director diversity. We have not adopted a policy regarding the handling of any potential recommendation of director candidates by our stockholders, including the procedures to be followed. Our Board has not considered or adopted any of these policies as we have never received a recommendation from any stockholder for any candidate to serve on our Board of Directors. Given our relative size and lack of directors and officers insurance coverage, we do not anticipate that any of our stockholders will make such a recommendation in the near future. While there have been no nominations of additional directors proposed, in the event such a proposal is made, all members of our Board will participate in the consideration of director nominees. In considering a director nominee, it is likely that our Board will consider the professional and/or educational background of any nominee with a view towards how this person might bring a different viewpoint or experience to our Board.

Neither of our directors is an “audit committee financial expert” within the meaning of Item 401(e) of Regulation S-K. In general, an “audit committee financial expert” is an individual member of the audit committee or Board of Directors who:

•

understands generally accepted accounting principles and financial statements,

•

is able to assess the general application of such principles in connection with accounting for estimates, accruals and reserves,

•

has experience preparing, auditing, analyzing or evaluating financial statements comparable to the breadth and complexity to our financial statements,

•

understands internal controls over financial reporting, and

•

understands audit committee functions.

Our securities are not quoted on an exchange that has requirements that a majority of our Board members be independent and we are not currently otherwise subject to any law, rule or regulation requiring that all or any portion of our Board of Directors include “independent” directors, nor are we required to establish or maintain an Audit Committee or other committee of our Board of Directors.

Code of Ethics and Business Conduct

We have adopted a code of ethics applicable to our chief executive officer, who is our principal executive officer, and our chief financial officer, who is our principal financial and accounting officer. We will provide a copy, without charge, to any person desiring a copy of the Code of Ethics, by written request to, 649 Sparta Highway, Suite 102, Crossville, TN 38571.

Compliance with Section 16(a) of the Exchange Act

Section 16(a) of the Securities Exchange Act of 1934, as amended, requires our executive officers and directors, and persons who beneficially own more than 10% of a registered class of our equity securities to file with the Securities and Exchange Commission initial statements of beneficial ownership, reports of changes in ownership and annual reports concerning their ownership of our common shares and other equity securities, on Forms 3, 4 and 5 respectively. Executive officers, directors and greater than 10% stockholders are required by the Securities and Exchange Commission regulations to furnish us with copies of all Section 16(a) reports they file. Based on our review of the copies of such forms received by us, and to the best of our knowledge, all executive officers, directors and persons holding greater than 10% of our issued and outstanding stock have filed the required reports in a timely manner during ~~2012~~2014.

ITEM 11. EXECUTIVE COMPENSATION.

The following table summarizes all compensation recorded by us in ~~2012~~2014 and ~~2011~~2013 for our principal executive officer, each other executive officer serving as such whose annual compensation exceeded $100,000, and up to two additional individuals for whom disclosure would have been made in this table but for the fact that the individual was not serving as an executive officer of our company at December 31, ~~2012~~2014. The value attributable to any option awards is computed in accordance with FASB ASC Topic 718. The assumptions made in the valuations of the option awards are included in Note 7 of the Notes to our Financial Statements appearing later in this report.

SUMMARY COMPENSATION TABLE
Name and principal position (a)	Year (b)	Salary ($) (c)	Bonus ($) (d)	Stock Awards ($) (e)	Option Awards ($) (f)	Non- Equity Incentive Plan Compen- sation ($) (g)	Non- qualified Deferred Compen- sation Earnings ($) (h)	All Other Compen- sation ($) (i)	Total ($) (j)
Ken Page, Chief Executive Officer 1	~~2012~~2014	6842,000	0	0	0163,803	0	0	07,630	4049,~~000~~630
	2011	68,000	0	0	0	0	0	0	68,000
	2013	46,000	0	0	0	0	0	0	46,000

1 All Other Compensation represents a monthly expense allowance payable to Mr. Page under the terms of his employment agreement.

Employment Agreement with Mr. Page

On September 27, 2007, we entered into an Employment Agreement with Mr. Page whereby he agreed to serve as our Chief Executive Officer and Chairman of our Board of Directors. The Employment Agreement has an initial term of one year and thereafter will automatically be extended for two year periods unless notice of non-renewal is given by either party no later than 30 days prior to the end of the expiration of each term. Under the Employment Agreement, Mr. Page initially was to receive a monthly salary of $6,000, plus $1,000 per month as an expense allowance.

In addition, under the Employment Agreement, after six months of employment, Mr. Page received a grant of a three year option to purchase 3,000,000 shares of our common stock at a price of $0.20 per share, which vested in six equal monthly installments from the date of issuance. These options expired unexercised in 2010. Mr. Page also received a right to immediately appoint two directors to our Board of Directors. Pursuant to the agreement, Mr. McNeil was appointed to our Board of Directors. Mr. Page does not have any present attention to appoint an additional director to our Board.

On September 29, 2009 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 our development of our new business. Under Amendment No. 1 to Mr. Page’s Employment Agreement, his base salary was reduced from $72,000 per year to $50,000 per year and we granted him non-qualified options to purchase an aggregate of 120,000 shares of our common stock pursuant to our 2009 Equity Compensation Plan which have an exercise price of $0.25 per share. The options vest in 12 equal monthly installments at the end of each month beginning in September 2009.

On July 1, 2012 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 our development of our new business. Under Amendment No. 2 to Mr. Page’s Employment Agreement, his base salary was reduced from $50,000 per year to $40,000 per year and he forgave his accrued wages of $ 85,076. We provide Mr. Page with the full time use of a company-owned vehicle as additional compensation. 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 $542.02. In addition, on June 27, 2014 our Board of Directors granted Mr. Ken Page five year non-qualified options to purchase 1,560,000 shares of our common stock at an exercise price of $0.16 per share.

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.

The terms of the employment agreement were approved by our Board of Directors, of which Mr. Page is one of two members. We have not utilized the services of a compensation consultant.

Outstanding Equity Awards at Fiscal Year-End

The following table provides information concerning unexercised options, stock that has not vested and equity incentive plan awards for each named executive officer outstanding as of December 31, ~~2012~~2014:

OPTION AWARDS									~~STOCK AWARDS~~			STOCK AWARDS
Name (a)	Number of Securities Underlying Unexercised Options (#) Exercisable (b)		Number of Securities Underlying Unexercised Options (#) Unexercisable (c)		Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Unearned Options (#) (d)	Option Exercise Price ($) (e)		Option Expiration Date (f)	Number of Shares or Units of Stock That Have Not Vested (#) (g)		Market Value of Shares or Units of Stock That Have Not Vested ($) (h)	Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights that Have Not Vested (#) (i)		Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights That Have Not Vested (#) (j)
Name	Number of Securities Underlying Unexercised Options (#) Exercisable			Number of Securities Underlying Unexercised Options (#) Unexercisable		Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Unearned Options (#)			Option Exercise Price ($)		Option Expiration Date	Number of Shares or Units of Stock That Have Not Vested (#)			Market Value of Shares or Units of Stock That Have Not Vested ($)		Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights that Have Not Vested (#)		Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights That Have Not Vested (#)
Ken Page	~~120,000~~	1,500,000	0		0	~~0.25~~	0	~~9/29/14~~	0	0.30	09/14/15	0	0	0		0		0		0
	388,000		0		0	0.25		9/29/14	0		0	0		0
Ken Page		1,560,000			0		0			0.16	06/27/2018		0			0		0		0
	1,500,000		0		0	0.30		9/14/15	0		0	0		0

Stock Option Plans

2004 Stock Incentive Plan

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. At December 31, ~~2012~~2014 there were outstanding options to purchase 205,000 shares of our common stock at an exercise prices ranging from $0.25 to $0.56 per share.

2009 Equity Compensation Plan

On September 29, 2009 our Board of Directors adopted our 2009 Equity Compensation Plan (the “2009 Plan”). The purpose of the 2009 Plan is to enable our company to offer to our employees, officers, directors and consultants whose past, present and/or potential contributions to our company have been or will be important to our success, an opportunity to acquire a proprietary interest in our company. The types of long-term incentive awards that may be provided under the plan will enable us to respond to changes in compensation practices, tax laws, accounting regulations and the size and diversity of its businesses. 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. At December 31, 2012 we had options to purchase 2,188,000 shares of our common stock with exercise prices ranging from $0.12 to $0.30 outstanding under the 2009 Plan.

Compensation of Directors

We have not established standard compensation arrangements for our directors and the compensation payable to each individual for their service on our Board is determined from time to time by our Board of Directors based upon the amount of time expended by each of the directors on our behalf. Mr. Page, who is an executive officer of our company, does not receive any compensation specifically for his services as a director. In ~~2012~~2014 we did not compensate Mr. McNeil for his services to us as a director.

ITEM 12.

SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.

At ~~April~~June 810, ~~2013~~2015, we had 38,176,085 shares of our common stock issued and outstanding. The following table sets forth information regarding the beneficial ownership of our common stock as of ~~April~~March 821, ~~2013~~2015 by:

	•	each person known by us to be the beneficial owner of more than 5% of our common stock;
	•	each of our directors;
	•	each of our named executive officers; and
	•	our named executive officers, directors and director nominees as a group.

Unless otherwise indicated, the business address of each person listed is in care of 649 Sparta Highway, Suite 102, Crossville, TN 38571. The percentages in the table have been calculated on the basis of treating as outstanding for a particular person, all shares of our common stock outstanding on that date and all shares of our common stock issuable to that holder in the event of exercise of outstanding options, warrants, rights or conversion privileges owned by that person at that date which are exercisable within 60 days of that date. Except as otherwise indicated, the persons listed below have sole voting and investment power with respect to all shares of our common stock owned by them, except to the extent that power may be shared with a spouse.

Name of Beneficial Owner	Amount and Nature of Beneficial Ownership		% of Class
Ken Page ⁽¹⁾		3,060,000		8.0	%
All officers and directors as a group (two persons) ⁽¹⁾		3,060,000		8.0	%
Travis Coomer ⁽²⁾		3,264,285		8.5	%
Mitchell Coomer ⁽³⁾		2,735,715		7.2	%
Daniel (Allen)Page ⁽⁴⁾		2,960,822		7.8	%

Name of Beneficial Owner	Amount and Nature of Beneficial Ownership		% of Class
Ken Page 1		2,008,000		5.0	%
Brad McNeil 2		180,000	<1		%
All officers and directors as a group (two persons)1,2		2,188,000		5.4	%
Travis Coomer 3		3,264,285		8.6	%
Mitchell Coomer 4		2,735,715		7.2	%
Daniel (Allen)Page 5		2,960,822		6.4	%

⁽¹⁾ The number of shares of common stock beneficially owned by Mr. Ken Page includes shares underlying options to purchase:

• 1 ~~The~~,500,000 ~~number of~~ shares of our common stock ~~beneficially~~with ~~owned~~an byexercise ~~Mr.~~price ~~Ken~~of ~~Page~~$0.30 ~~includes~~per ~~shares~~share ~~underlying~~which ~~options~~expire toin ~~purchase:~~September 2015.

	•	508,000 shares of our common stock with an exercise price of $0.25 per share which expire in September 2014, and
	•	1,500,000 shares of our common stock with an exercise price of $0.30 per share which expire in September 2015.

⁽²⁾ Mr. Coomer’s address is 1115 Jamestown Street, Suite 3, Columbia, KY 42728.

~~2 The number of shares of common stock beneficially owned by~~ (3) Mr. ~~McNeil~~Coomer’s ~~includes~~address ~~shares~~is ~~underlying~~401 ~~options~~Coomer toRoad, ~~purchase 180~~Columbia,~~000~~ ~~shares~~KY ~~of our common stock with an exercise price of $0~~42728.~~12 per share which expire in September 2014.~~

3 (4) Mr. ~~Coomer~~Daniel (Allen) Page’s address is ~~1115~~Post ~~Jamestown~~Office ~~Street~~Box 574, ~~Suite~~Crossville, 3TN 38557. The number of shares owned by Mr. Page includes 1,054,852 ~~Columbia~~shares which are presently outstanding, KYtogether ~~42728.~~with:

4 Mr. Coomer’s address is 401 Coomer Road, Columbia, KY 42728.

	•	1,825,970 shares issuable upon the conversion of $180,000 principal amount due under the secured line of credit note with Mr. Daniel (Allen) Page, and
	•	80,000 shares issuable upon the exercise of warrants with exercise prices ranging from $0.12 to $0.35 per share we will issue Mr. Daniel (Allen) Page upon the conversion or satisfaction of secured line of credit.

5 Mr. Daniel (Allen) Page’s address is Post Office Box 574, Crossville, TN 38557. The number of shares owned by Mr. Page includes 1,054,852 shares which are presently outstanding, together with:

	•	1,825,970 shares issuable upon the conversion of $180,000 principal amount due under the secured line of credit note with Mr. Daniel (Allen) Page together with accrued interest of $4,339 at March 31, 2012, and
	•	80,000 shares issuable upon the exercise of warrants with exercise prices ranging from $0.12 to $0.35 per share we will issue Mr. Daniel (Allen) Page upon the conversion or satisfaction of secured line of credit.

Securities Authorized for Issuance under Equity Compensation Plans

The following table sets forth securities authorized for issuance under any equity compensation plans approved by our shareholders as well as any equity compensation plans not approved by our shareholders as of December 31, ~~2012~~2014.

	Number of securities to be issued upon exercise of outstanding options, warrants and rights (a)		Weighted average exercise price of outstanding options, warrants and rights (b)		Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c)
Plan category

Plans approved by our shareholders:		0	n/a		n/a

Plans not approved by shareholders:
2004 Stock Incentive Plan		205,000	$	0.385		0
2009 Equity Compensation Plan		2,188,000	$	0.274		2,612,000

A description of the 2004 Stock Incentive Plan and the 2009 Equity Compensation Plan is contained earlier in this report under Part III, Item 11. Executive Compensation - Stock Option Plans.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.

From time to time we enter into transactions with Mr. Daniel (Allen) Page, a related party. See Part III, Item 10., Directors, Executive Officers and Corporate Governance. During 2012 we entered into a number of joint venture transactions on various oil leases with Mr. Daniel (Allen) Page, including:

•

On April 12, 2012, we entered into a 35% interest in a 100% working interest in the Teddy Hicks Lease for an initial cost to us $10. We are responsible for 42% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 58% of such costs;

•

On July 27, 2012, we entered into a 85% interest in a 100% working interest in the Jimmie and Linda Irby Lease for an initial cost to us of $10;

•

On October 1, 2012, we entered into a 50% interest in a 87.5% working interest in the Gerald Norrad Lease for an initial cost to us of $10;

•

On October 1, 2012, we also entered into a 37.5% interest in a 75% working interest in the John Lee Lease for an initial cost to us of $10;

•

On October 1, 2012, we also entered into a 25% interest in a 87.5% working interest lease in the Barclay Kirkland Lease for an initial cost to the Company of $10;

•

On October 4, 2012, under the terms of a Memorandum of Understanding we participated and permitted 25% working interests as the operator in the Barclay Kirkland Well #1 in Cumberland County, Kentucky at the cost of approximately $15,500. We are responsible for 32% of the all costs associated with the well, and Mr. Page is responsible for the remaining 68% of such costs; and

•

On October 23, 2012, we entered into a 15% interest in an 75% working interest in John Lee Well #1 pursuant to the terms of an Assignment of Interest in Oil and Gas Lease dated October 1, 2012 by and our company and Mr. Page for an initial cost to the Company of $10. We are responsible for 25% of the costs on this well and Mr. Page is responsible for the remaining 75% of such costs.

During ~~2012~~2013 we ~~were~~entered ~~also~~into athe ~~party~~following tojoint ~~several~~venture ~~additional~~transaction ~~transactions~~on an oil lease with Mr. Daniel (Allen) Page~~, including~~:

• ~~Mr.~~ ~~Daniel~~On ~~(Allen)~~December ~~Page~~19, ~~also~~2013, ~~provides~~per a ~~secured~~Memorandum ~~line~~ of ~~credit~~Understanding tothe usCompany ~~which~~participated isand ~~described~~permitted ~~earlier~~43.75% inworking ~~this~~interests ~~report~~as ~~under~~the ~~Item~~operator 7.in ~~Management’s~~the ~~Discussion~~William ~~and~~Johnson ~~Analysis~~Well of#1 ~~Financial~~in ~~Condition~~Fentress ~~and~~County, ~~Results~~Tennessee ofat ~~Operations~~the –cost ~~Secured Line~~ of ~~Credit~~approximately ~~with Mr. Daniel (Allen) Page. During 2012 we paid Mr. Page~~ $16,~~318~~500 ofand ~~interest~~is ~~under~~responsible ~~this~~for ~~secured~~50% ~~credit~~of ~~line. At~~the ~~December~~all ~~31,~~costs ~~2012~~associated wewith ~~owed~~the Mrwell. ~~Daniel~~The ~~(Allen)~~Company ~~Page~~is ~~$180,000~~responsible ~~principal~~for ~~and~~50% ~~$455~~ of ~~accrued~~the ~~but~~costs ~~unpaid~~on ~~interest. In~~this ~~April~~well ~~2012~~and ~~we entered into a Security Agreement with~~ Mr. Daniel (Allen) Page ~~pursuant~~is toresponsible ~~which~~for wethe ~~granted~~remaining ~~him~~50% ~~a security interest in all~~ of ~~our~~such ~~assets to ensure the repayment of the secured credit line which is described in greater detail earlier in this report; and~~costs.

~~• On~~During ~~August~~2014 ~~15,~~we ~~2012,~~entered ~~effective~~into ~~July~~a 1,number ~~2012,~~of wejoint ~~entered~~venture ~~into~~transactions aon ~~new~~various ~~Consulting~~oil ~~Agreement~~leases with Mr. Daniel (Allen) Page ~~which replaced the earlier agreement dated March 1~~, 2011. The terms of this agreement are described earlier in this report under Part III, Item 10. Directors, Executive Officers and Corporate Governance. At December 31, 2012 we owed Mr. Page $31,149 accrued consulting fees under this agreement, net of payments of $4,851 during 2012.including:

	•	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 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.

During 2014 we were also a party to several additional transactions with Mr. Daniel (Allen) Page, including:

•

Mr. Daniel (Allen) Page also provides a secured line of credit to us which is described earlier in this report under Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Secured Line of Credit with Mr. Daniel (Allen) Page. During 2013 we paid Mr. Page $15,100 of interest under this secured credit line. At December 31, 2013 we owed Mr. Daniel (Allen) Page $180,000 principal and $0 of accrued but unpaid interest. In April 2013 we entered into a Security Agreement with Mr. Daniel (Allen) Page pursuant to which we granted him a security interest in all of our assets to ensure the repayment of the secured credit line which is described in greater detail earlier in this report; and

•

On August 15, 2012, effective July 1, 2012, we entered into a new Consulting Agreement with Mr. Daniel (Allen) Page which replaced the earlier agreement dated March 1, 2011. The terms of this agreement are described earlier in this report under Part III, Item 10. Directors, Executive Officers and Corporate Governance. At December 31, 2014 we owed Mr. Page $56,819 accrued consulting fees under this agreement, net of payments of $17,330 during 2014.

•

On September 17, 2013, we provided Mr. Page with the full time use of a company-owned vehicle as additional compensation for an initial cost of $12,000. We are responsible for 100% of the costs to maintain this vehicle.

As these transactions were not negotiated on an arms-length basis, there are no assurances that the terms of these transactions are as fair to our company as we might receive from an unrelated third party.

Director Independence

Mr. McNeil is considered “independent” within the meaning of meaning of Rule 5605 of the NASDAQ Marketplace Rules.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.

The following table shows the fees that were billed for the audit and other services provided by Liggett, Vogt and Webb P.A. in ~~2012~~2014 and ~~Sherb~~ ~~& Co~~2013.~~, LLP for 2011.~~

	2012		2011
	2014		2013
Audit Fees	$	34,000	$	34,000
Audit-Related Fees		0		0
Tax Fees		3,500		3,500
All Other Fees		0		0
Total	$	37,500	$	37,500

Audit Fees — This category includes the audit of our annual financial statements, review of financial statements included in our Quarterly Reports on Form 10-Q and services that are normally provided by the independent registered public accounting firm in connection with engagements for those fiscal years. This category also includes advice on audit and accounting matters that arose during, or as a result of, the audit or the review of interim financial statements.

Audit-Related Fees — This category consists of assurance and related services by the independent registered public accounting firm that are reasonably related to the performance of the audit or review of our financial statements and are not reported above under “Audit Fees.” The services for the fees disclosed under this category include consultation regarding our correspondence with the Securities and Exchange Commission and other accounting consulting.

Tax Fees — This category consists of professional services rendered by our independent registered public accounting firm for tax compliance and tax advice. The services for the fees disclosed under this category include tax return preparation and technical tax advice.

All Other Fees — This category consists of fees for other miscellaneous items.

Our Board of Directors has adopted a procedure for pre-approval of all fees charged by our independent registered public accounting firm. Under the procedure, the Board approves the engagement letter with respect to audit, tax and review services. Other fees are subject to pre-approval by the Board, or, in the period between meetings, by a designated member of Board. Any such approval by the designated member is disclosed to the entire Board at the next meeting. The audit and tax fees paid to the auditors with respect to ~~2012~~2014 and 2013 were pre-approved by the entire Board of Directors.

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.

Exhibit No.	Description
3.1	Restated Certificate of Incorporation (1)
3.2	Certificate of Designation of Series A Preferred Stock (2)
3.3	Amended and Restated By-Laws (2)
3.4	Certificate of Ownership merging TN-K Energy Group Inc. into Digital Lifestyles Group, Inc. (13)
4.1	Specimen stock certificate for common stock (2)
4.2	Convertible Promissory Note dated April 1, 2005 issued to Alloy Marketing and Promotions, LLC (19)
4.3	Form of convertible promissory note issued to Mr. L.E. Smith in September 2005 (3)
4.4	Form of common stock purchase warrant issued to Mr. L.E. Smith in connection with convertible promissory note (3)
4.5	Form of $250,000 principal amount 7.5% convertible promissory note issued to Mr. Dan Page in April 2007 (6)
4.6	Form of warrant issued to Mr. Dan Page in connection with $250,000 principal amount 7.5% convertible promissory note issued in April 2007 (5)
4.7	Amendment to Convertible Line of Credit Note (6)
4.8	Second Amendment to Convertible Line of Credit Note dated May 1, 2009 (7)
4.9	Third Amendment to Convertible Line of Credit dated December 8, 2009 (19)
4.10	Fourth Amendment to Convertible Line of Credit Note Agreement with Dan Page dated June 29, 2010 (15)
4.11	Form of Fifth Amendment Convertible Line of Credit Note Agreement with Dan Page dated December 31, 2010 (17)
4.12	Form of Class A Warrant (9)
4.13	Form of convertible promissory note issued to Mr. Robert Wood (3)
4.14	Form of common stock purchase warrant issued to Mr. Wood in connection with convertible promissory note (3)
4.15	Form of common stock purchase warrant issued to Westech Capital (4)
4.16	Form of common stock purchase warrant issued to Tejas Incorporated (18)
10.1	2004 Stock Incentive Plan (2)
10.2	Form of registration rights agreement in favor of each of Mr. L.E. Smith and Mr. Robert Wood (3)
10.3	Form of Registration Rights Agreement with Mr. Dan Page (5)
10.4	Employment Agreement with Ken Page (6)
10.5	Form of Amendment No. 1 to Employment Agreement with Ken Page (8)
10.7	2009 Equity Compensation Plan (8)
10.6	Form of Amendment to No. 2 to Employment Agreement with Ken Page (8)
10.8	Form of Assignment of Oil and Gas Lease (10)
10.9	Assignments of Oil and Gas Leases (11)
10.10	Assignment of Oil and Gas Lease dated February 2, 2010 by and between Mitchell Coomer, Travis Coomer, Americas Energy Company and TN-K Energy Group, Inc. (13)
10.11	Assignment of Oil and Gas Lease dated February 2, 2010 by and between Travis Coomer Drilling Co. and TN-K Energy Group, Inc. (13)
10.12	Assignment of Oil and Gas Lease (full checkerboard) dated February 2, 2010 by and between Mitchell Coomer and Travis Coomer and TN-K Energy Group, Inc. (18)
10.13	Registration Rights Agreement dated January 27, 2005 with Alloy Marketing and Promotions, LLC (18)

2426

10.7	2009 Equity Compensation Plan (8)
10.8	Form of Assignment of Oil and Gas Lease (10)
10.9	Assignments of Oil and Gas Leases (11)
10.10	Assignment of Oil and Gas Lease dated February 2, 2010 by and between Mitchell Coomer, Travis Coomer, Americas Energy Company and TN-K Energy Group, Inc. (13)
10.11	Assignment of Oil and Gas Lease dated February 2, 2010 by and between Travis Coomer Drilling Co. and TN-K Energy Group, Inc. (13)
10.12	Assignment of Oil and Gas Lease (full checkerboard) dated February 2, 2010 by and between Mitchell Coomer and Travis Coomer and TN-K Energy Group, Inc. (18)
10.13	Registration Rights Agreement dated January 27, 2005 with Alloy Marketing and Promotions, LLC (18)
10.14	Assignments of Oil and Gas Lease dated May 6, 2010 by and between Mitchell Coomer and Travis Coomer and TN-K Energy Group, Inc. (14)
10.15	Assignment dated September 17, 2010 from Overton Oil & Gas Corp. to TN-K Energy Group Inc. (16)
10.16	Assignment dated September 17, 2010 between TN-K Energy Group Inc. and King’s Oil, LLC. (16)
10.17	Guaranteed Contract dated September 17, 2010 between TN-K Energy Group Inc. and King’s Oil, LLC. (16)
10.18	Form of Consulting Agreement dated March 31, 2011 with Dan Page (21)
10.19	Security Agreement dated as of October 2, 2012 by and between Daniel Allen Page and TN-K Energy Group Inc.
10.20	Contract For Sale of Oil & Gas Leasehold Estate dated February 3, 2012 by and between Travis Coomer, Mitchell Coomer, Anthony Franklin, TN-K Energy Group Inc., as Sellers, and Texas Mineral Properties, LLC, d/b/a BSAG Properties, LTD. as Buyer (20)
10.21	Oil and Gas Lease Assignment dated April 12, 2012 for the Clark Brothers Lease. (20)
10.22	Oil and Gas Lease Assignment dated April 12, 2012 for the Simmons lease and the Blaydes lease (20)
10.23	Oil and Gas Lease Assignment dated April 12, 2012 for the Ervin lease. (20)
10.24	Oil and Gas Lease Assignment dated April 12, 2012 for the Hickerson lease (20)
16.1	Letter dated October 24, 2012 from Sherb & Co., LLP (22)
23.1	Consent of Lee Keeling & Associates, Inc. *
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 *
99.1	Reserve Report of Lee Keeling & Associates, Inc. at December 31, ~~2012~~2014 *
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 **

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.

** In accordance with Regulation S-T, the XBRL-formatted interactive data files that comprise Exhibit 101 in this Annual Report on Form 10-K shall be deemed “furnished” and not “filed”.

(1)	Incorporated by reference to the Annual Report on Form 10-K for the year ended December 31, 2004.
(2)	Incorporated by reference to the Annual Report on Form 10-K for the year ended December 31, 2003.
(3)	Incorporated by reference to the Current Report on Form 8-K as filed on October 4, 2005.
(4)	Incorporated by reference to the Current Report on Form 8-K as filed on September 15, 2004.
(5)	Incorporated by reference to the Current Report on Form 8-K as filed on April 26, 2007.
(6)	Incorporated by reference to the Current Report on Form 8-K as filed on October 9, 2007.
(7)	Incorporated by reference to the Current Report on Form 8-K as filed on August 31, 2009.
(8)	Incorporated by reference to the Current Report on Form 8-K as filed on October 5, 2009.
(9)	Incorporated by reference to the Current Report on Form 8-K as filed on October 19, 2009.
(10)	Incorporated by reference to the Current Report on Form 8-K as filed on November 12, 2009.
(11)	Incorporated by reference to the Current Report on Form 8-K as filed on December 8, 2009.
(12)	Incorporated by reference to the Current Report on Form 8-K as filed on January 26, 2010.
(13)	Incorporated by reference to the Current Report on Form 8-K as filed on February 8, 2010.
(14)	Incorporated by reference to the Current Report on Form 8-K as filed on May 12, 2010.
(15)	Incorporated by reference the Quarterly Report on Form 10-Q for the period ended June 30, 2010.
(16)	Incorporated by reference to the Current Report on Form 8-K as filed on September 23, 2010.
(17)	Incorporated by reference to the Current Report on Form 8-K as filed on December 20, 2010.
(18)	Incorporated by reference to the Annual Report on Form 10-K for the year ended December 31, 2009.
(19)	Incorporated by reference to the Annual Report on Form 10-K for the year ended December 31, 2010.
(20)	Incorporated by reference to the Current Report on Form 8-K as filed on April 23, 2012.
(21)	Incorporated by reference to the Quarterly Report on Form 10-Q for the period ended September 30, 2012.
(22)	Incorporated by reference to the Current Report on Form 8-K as filed on October 25, 2012.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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.
April 15, 2013	By:	/s/ Ken Page
May 26, 2015	By:	/s/ Ken Page
		Ken Page, Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant in the capacities and on the dates indicated.

Name	Positions	Date
/s/ Ken Page	Chief Executive Officer, President, Secretary,	~~April~~May 1526, ~~2013~~2015
Ken Page	Director, Principal Executive Officer and Principal Financial and Accounting Officer
	Principal Financial and Accounting Officer
/s/ Brad McNeil	Director	May 26, 2015
/s/ Brad McNeil	Director	April 15, 2013
Brad McNeil

2628

Index of Exhibits

10.19	Security Agreement dated as of October 2, 2012 by and between Daniel Allen Page and TN-K Energy Group Inc.
23.1	Consent of Lee Keeling & Associates, Inc. *
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 *
99.1	Reserve Report of Lee Keeling & Associates, Inc. at December 31, ~~2012~~2014 *

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.

** In accordance with Regulation S-T, the XBRL-formatted interactive data files that comprise Exhibit 101 in this Annual Report on Form 10-K shall be deemed “furnished” and not “filed”.

TN-K ENERGY GROUP INC

CONTENTS

	Page
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM – LIGGETT, VOGT & WEBB, P.A.	F-2
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM - SHERB & CO, LLP	F-3
FINANCIAL STATEMENTS	F-3
FINANCIAL STATEMENTS
Balance Sheets	F-4
Statements of Operations	F-5
Statements of Stockholders’ Deficit	F-6
Statements of Cash Flows	F-6
Statements of Cash Flows	F-7
Statements of Stockholders’ Deficit	F-7
NOTES TO THE FINANCIAL STATEMENTS	F-8

~~F-1~~30

Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders

TN-K Energy Group, Inc.

We have audited the accompanying balance ~~sheet~~sheets of TN-K Energy Group, Inc. as of December 31, ~~2012~~2014 and 2013 and the related statements of operations, stockholders’ deficit, and cash flows for each of the ~~year~~years then ended December 31, ~~2012~~2014 and 2013. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our ~~audit~~audits.

We conducted our ~~audit~~audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our ~~audit~~audits provides a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, ~~2012~~2014 and 2013, and the results of its operations and cash flows for each of the ~~year~~years then ended December 31, ~~2012~~2014 and 2013, in conformity with generally accepted accounting principles in the United States.

The accompanying consolidated financial statements have been prepared assuming that TN-K Energy Group, Inc. will continue as a going concern. As more fully described in Note 1, the Company has incurred recurring operating losses and will have to obtain additional financing to sustain operations. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. Management’s plans in regard to these matters are also described in Note 1. The financial statements do not include any adjustments to reflect the possible effects on the recoverability and classification of assets or the amounts and classification of liabilities that may result from the outcome of this uncertainty.

/s/ Liggett, Vogt & Webb, P.A.

LIGGETT, VOGT & WEBB, P.A.

Certified Public Accountants

New York, New York

~~April~~May 1229, ~~2013~~2015

F-2

~~Report~~TN-K ofEnergy ~~Independent~~Group ~~Registered~~Inc ~~Public~~Balance ~~Accounting Firm~~Sheets

Board of Directors and Stockholders

				December 31,			December 31,
				2014			2013

ASSETS:
CURRENT ASSETS:
	Cash and cash equivalents			$	157,830		$	514,003
	Accounts receivable				17,572			17,318
		TOTAL CURRENT ASSETS			175,402			531,321


OIL AND GAS PROPERTY (Successful efforts method), at cost					1,546,885			1,691,756

EQUIPMENT, net of depreciation					95,846			122,105
OTHER ASSETS					42,000			42,000

TOTAL ASSETS				$	1,860,133		$	2,387,182


LIABILITIES AND STOCKHOLDERS' DEFICIT:
	CURRENT LIABILITIES:
	Accounts payable			$	2,888,728		$	2,889,819
	Accrued expenses				550,655			558,167
	Convertible note payable - related party				170,000			180,000

			TOTAL CURRENT LIABILITIES		3,609,383			3,627,986

	LONG TERM LIABILITIES:
	Asset retirement obligation				33,240			31,640
	Deferred income taxes payable				285,097			285,097
			TOTAL LONG TERM LIABILITIES		318,337			316,737

TOTAL LIABILITIES					3,927,720			3,944,723

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				13,601,316			13,437,513
	Accumulated deficit				(16,814,185	)		(16,140,336	)

TOTAL STOCKHOLDERS' DEFICIT					(2,067,587	)		(1,557,541	)

TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT				$	1,860,133		$	2,387,182

~~TN-K~~See ~~Energy~~accompanying ~~Group,~~notes ~~Inc~~to financial statements.

We have audited the accompanying balance sheet of TN-K Energy Group, Inc. as of December 31, 2011 and the related statements of operations, stockholders’ deficit, and cash flows for the year ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2011, and the results of its operations and cash flows for the year ended December 31, 2011, in conformity with generally accepted accounting principles in the United States.

/s/ Sherb & Co., LLP

SHERB & CO, LLP

Certified Public Accountants

New York, New York

April 13, 2012

F-3

~~Balance~~TN-K ~~Sheets~~Energy Group, Inc. Statements of Operations

		December 31,				December 31,
				For the Year Ended December 31,
		2012				2011
				2014				2013
ASSETS:
Revenue:
CURRENT ASSETS:
	Oil sales			$	69,674			$	156,767
Cash and cash equivalents		$	486,464			$	140,658
	Well Services				-				29,594
Accounts receivable-related party			-				1,083
	Well Equipment Rental				14,431				-
Accounts receivable			24,895				54,504
	Sale of oil and gas leases				111,500				398,250
TOTAL CURRENT ASSETS			511,359				196,245
		Total Revenue			195,604				584,611
OIL AND GAS PROPERTY (Successful efforts method), at cost			1,923,659				1,553,646
Expense:
EQUIPMENT, net of depreciation			117,965				166,765
	Oil lease operating expense				196,632				221,313
OTHER ASSETS			42,000				64,000
	Cost of oil and gas leases sold				64,439				37,494
TOTAL ASSETS		$	2,594,983			$	1,980,656
	Sales, general and administrative				416,474				240,890
LIABILITIES AND STOCKHOLDERS' DEFICIT:
	Impairment of developed properties				177,516				253,682
CURRENT LIABILITIES:
		Total Operating Expenses			855,061				753,379
Accounts payable		$	2,933,743			$	3,336,876
		(Loss) From Operations			(659,457	)			(168,768	)
Accrued expenses			539,802				1,365,353
Other Income (Expense):
Liquidated damages			-				742,684
	Interest expense				(14,424	)			(15,100	)
Convertible note payable - related party			180,000				180,000
	Other income				31				26
Convertible - notes payable			-				650,000
		Total Other Income (Expense)			(14,393	)			(15,074	)
TOTAL CURRENT LIABILITIES			3,653,545				6,274,913
Loss before taxes					(673,849	)			(183,842	)
LONG TERM LIABILITIES:
	Income taxes				-				-
Asset retirement obligation			30,040				48,860
Net Loss				$	(673,849	)		$	(183,842	)
Deferred income taxes payable			285,097				-
Basic Loss per common share				$	(0.02	)		$	-
Derivative and warrant liabilities			-				1,164,899
Diluted Loss per common share				$	(0.02	)		$	-
TOTAL LONG TERM LIABILITIES			315,137				1,213,759
Weighted average number of common shares outstanding -
STOCKHOLDERS' DEFICIT:
	Basic				38,176,085				38,176,085
Preferred stock, $.01 par value, 5,000,000 shares authorized, none issued, and outstanding			-				-
	Diluted				38,176,085				38,176,085
Common stock, $.03 par value, 100,000,000 shares authorized, 38,176,085 and 37,888,939 issued and outstanding, respectively			1,145,282				1,136,668
Additional Paid - In Capital			13,437,513				13,289,251
Accumulated deficit			(15,956,494	)			(19,933,935	)
TOTAL STOCKHOLDERS' DEFICIT			(1,373,699	)			(5,508,016	)
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT		$	2,594,983			$	1,980,656

See accompanying notes to financial statements.

F-4

~~Statement~~TN-K Energy Group Inc Statements of ~~Operations~~Cash Flows

		Year Ended December 31,
				For the Year Ended December 31,
		2012				2011
				2014				2013
Revenue:
Cash Flow From Operating Activities:
Commission		$	316,667			$	-
Net Income / (Loss)				$	(673,849	)		$	(183,842	)
Oil sales			204,962				753,320
Adjustments to Net Income
Finders Fee			75,000				66,500
	Depreciation and depletion				216,293				235,009
Well Services and rental			1,275				50,371
	Impairment loss on developed oil property				177,516				253,682
Sale of oil and gas leases			1,285,600				1,011,229
	Change in fair fair of asset retirement obligation				1,600				1,600
Total revenue			1,883,504				1,881,420
	Equity based compensation				163,803				-
Expense:
Adjustments to reconcile Net Loss to Net Cash Used by Operating Activities:
Oil lease operating expense			250,463				530,830
	Changes in operating assets and liabilities:
Cost of oil and gas leases sold			463,972				857,179
		Accounts receivable			(254	)			7,577
Sales, general and administrative			283,567				354,074
		Sale of oil and gas rights			61,476				37,500
Impairment of developed properties			216,739				299,750
		Accounts payable and accrued expenses			(8,603	)			(25,459	)
Total operating expenses			1,214,741				2,041,833
Net Cash Provided by (Used by) Operating Activities					(62,019	)			326,067
Income / (Loss) from operations			668,763				(160,413	)
Cash Flow From Investing Activities:
Other income (expense):
		Purchase and development of oil and gas rights			(284,155	)			(271,731	)
Gain on derivatives			1,164,899				289,136
		Purchase of fixed assets			-				(26,797	)
Gain on write off off accounts payable			359,826				1,380,645
Net Cash Used by Investing Activities					(284,155	)			(298,528	)
Gain on Debt Relief			1,342,684				-
Cash Flow From Financing Activities:
Liquidated damages			742,684				(108,000	)
		Payment on convertible note payable-related party			(10,000	)			-
Interest expense			(16,318	)			(143,770	)
Net Increase (Decrease) In Cash and Cash Equivalents					(356,173	)			27,539
Total other income (expense)			3,593,775				1,418,011
Cash and cash equivalents at beginning of period					514,003				486,464
Net income before taxes			4,262,538				1,257,598
Cash and cash equivalents at end of period				$	157,830			$	514,003
Income taxes			285,097				-
Supplemental cash flow information:
Net Income		$	3,977,441			$	1,257,598
Cash paid for interest				$	20,033			$	15,100
Basic income per common share		$	0.10			$	0.03
Cash paid for income taxes				$	-			$	-
Diluted income per common share		$	0.10			$	0.03
Weighted average number of common shares outstanding -
Basic			38,153,997				39,884,163
Diluted			39,393,527				40,639,848

See accompanying notes to financial statements.

F-5

~~Statement~~TN-K Energy Group Inc Statements of ~~Cash~~Changes ~~Flows~~in Stockholders’ Deficit Years ended December 31, 2014 and 2013

	Years Ended December 31,
	Preferred Stock						Common Stock
	2012			2011
	Shares Par Value $0.01			Amount			Shares Par Value $0.03		Amount		Additional Paid-In Capital		Accumulated Deficit			Total Stockholders' Deficit
Cash Flow From Operating Activities:
Balance at December 31, 2012	$	-			-		$	38,176,085	$	1,145,282	$	13,437,513	$	(15,956,494	)	$	(1,373,699	)
Net income	$	3,977,441		$	1,257,598
Net loss		-			-			-		-		-		(183,842	)		(183,842	)
Adjustments to net income
Balance at December 31, 2013		-			-			38,176,085		1,145,282		13,437,513		(16,140,336	)		(1,557,541	)
Depreciation and depletion		257,281			530,830
Issuance of stock options												163,803					163,803
Impairment loss on developed oil property		216,739			299,750
Net loss		-			-			-		-		-		(673,849	)		(673,849	)
Contributed services		19,076
Balance at December 31, 2014	$	-			-			38,176,085	$	1,145,282	$	13,601,316	$	(16,814,185	)	$	(2,067,587	)
Change in fair fair of asset retirement obligation		(18,820	)
Change in fair value of derivative and liquidating damages liabilities		(1,907,583	)		(181,136	)
Gain on writeoff of notes payable and accrued interest		(1,702,511	)		(1,380,646	)
Gain on sale of oil and gas leases, after tax		(536,531	)		-
Adjustments to reconcile net income to net cash provided by operating activities:
Changes in operating assets and liabilities:
Accounts receivable		1,083			24,523
Accounts receivable - related party		29,609			-
Accounts payable and accrued expenses		(19,375	)		175,930
Net Cash Provided by Operating Activities		316,409			726,849
Cash Flow From Investing Activities:
Purchase and development of oil and gas rights		(365,309	)		(333,169	)
Refund of asset retirement deposits		22,000			-
Sale of oil and gas rights		400,000			857,179
Purchase of fixed assets		(27,294	)		(44,079	)
Net Cash Provided by Investing Activities		29,397			479,931
Cash Flow From Financing Activities:
Repayment of loan payable		-			(1,012,622	)
Repayment of notes payable-related party		-			(220,000	)
Net Cash (Used by) Financing Activities		-			(1,232,622	)
Net increase (decrease) in cash		345,806			(25,843	)
Cash and cash equivalents at beginning of period		140,658			166,501
Cash and cash equivalents at end of period	$	486,464		$	140,658
Supplemental cash flow information:
Cash paid for interest	$	16,318		$	55,680
Cash paid for taxes	$	-		$	-
Non-cash financing activities:
Equity issued for debt and interest	$	71,800		$	-
Contribution of accrued salary	$	66,000
Settlement of pending ESOP claims	$	-		$	6,207,000

See accompanying notes to financial statements.

F-6

TN-K Energy Group Inc

Statement of Changes in Stockholders’ Deficit

Years ended December 31, 2012 and 2011

	Preferred Stock				Common Stock
	Shares Par Value $0.01		Amount		Shares			Par Value $0.03			Additional Paid-In Capital			Accumulated Deficit			Unearned ESOP shares			Total Stockholders' Deficit
Balance at December 31, 2010		-	$	-		41,131,178		$	1,233,935		$	19,398,984		$	(21,191,533	)	$	(6,207,000	)	$	(6,765,614	)
ESOP settlement						(3,242,239	)		(97,267	)		(6,109,733	)		-			6,207,000			0
Net income		-		-		-			-			-			1,257,598			-			1,257,598
Balance at December 31, 2011		-		-		37,888,939			1,136,668			13,289,251			(19,933,935	)		-			(5,508,016	)
Conversion of notes papyable and interest into stock						287,146			8,614			63,186									71,800
Contribution of salary and accrued salary												85,076									85,076
Net income		-		-		-			-			-			3,977,441			-			3,977,441
Balance at December 31, 2012		-	$	-		38,176,085		$	1,145,282		$	13,437,513		$	(15,956,494	)	$	-		$	(1,373,699	)

See accompanying notes to financial statements.

F-7

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION.

Organization

TN-K Energy Group Inc. is an independent energy company engaged in the acquisition , development and sale 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.

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 $(12,~~373~~067,~~699~~587) as of December 31, ~~2012~~2014. 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 United States generally accepted accounting principles (“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 ~~of the fair value of the derivative liabilities; • 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.

FFair Value — The carrying amounts reported in the balance sheets for cash, and accounts receivable approximate fair value because of the immediate or short-8term 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.

F-7

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

~~Fair~~The ~~Value~~Company —utilizes ~~The~~the ~~carrying~~methods ~~amounts~~of ~~reported~~fair value measurement as described in ~~the~~ASC ~~balance~~820 ~~sheets~~to ~~for~~value ~~cash,~~its financial assets and ~~accounts~~liabilities. ~~receivable~~As ~~approximate~~defined in ASC 820, fair value ~~because~~is ofbased on the ~~immediate~~price orthat ~~short-term~~would ~~maturity~~be ofreceived ~~these~~to ~~financial~~sell ~~instruments.~~an ~~Predominately~~asset ~~most~~or ofpaid ~~the~~to ~~payables~~transfer ~~are~~a ~~the~~liability ~~results~~in ofan ~~operations~~orderly ~~and~~transaction ~~financings~~between ofmarket ~~our~~participants ~~prior~~at ~~business~~the ~~which~~measurement ~~ceased~~date. ~~operations~~In inorder ~~2005,~~to asincrease aconsistency ~~result~~and ofcomparability ~~the~~in ~~undercapitalized~~fair ~~nature~~value ofmeasurements, ~~our~~ASC ~~Company~~820 ~~and~~establishes ~~the~~a ~~age~~fair ofvalue ~~these~~hieracy ~~delinquent~~that ~~payables,~~prioritizes weobservable ~~are~~and ~~unable~~unobservable toinputs ~~determine~~used ~~the~~to measure fair value ofinto ~~these~~three ~~payables.~~broad levels, which are described below:

~~Accounts~~• ~~Receivable~~Level ~~and~~1: ~~Credit~~Quoted ~~Policies~~prices —(unadjusted) Wein ~~have~~active ~~certain~~markets ~~trade~~that ~~receivables~~are ~~consisting~~accessible ofat ~~oil~~the ~~and~~measurement ~~gas~~date ~~sales~~for ~~obligations~~assets ~~due~~or ~~under normal trade terms~~liabilities. ~~Our~~The ~~management~~fair ~~regularly~~value ~~reviews~~hierarchy ~~trade~~gives ~~receivables and reduces~~ the ~~carrying~~highest ~~amount~~priority byto aLevel ~~valuation~~1 ~~allowance~~inputs. ~~that~~• ~~reflects~~Level ~~management’s~~2: ~~best~~Observable ~~estimate~~prices ofthat ~~the~~are ~~amount~~based ~~that~~on ~~may~~inputs not bequoted ~~collectible.~~on Atactive ~~December 31~~markets, ~~2012~~but ~~and~~corroborated ~~2011,~~by ~~management~~market ~~had~~data. ~~determined~~• noLevel ~~allowance~~3: ~~for~~Unobservable ~~uncollectible~~inputs ~~receivables~~are ~~was~~used ~~necessary.~~when Atlittle ~~December~~or ~~31,~~no ~~2012~~market ~~and~~data ~~2011~~is weavailable. ~~had~~The ~~accounts~~fair ~~receivable~~value ~~and~~of ~~receivables~~hierarchy ~~from~~gives the ~~sale~~lowest ofpriority ato ~~partial~~Level ~~interest~~3 ~~in oil wells of $24,895 and $55,585, respectively~~inputs.

~~Asset~~Accounts ~~Retirement~~Receivable ~~Obligations~~and —Credit ~~When~~Policies we— ~~incur~~We anhave ~~obligation~~certain ~~for~~trade ~~future~~receivables ~~asset~~consisting ~~retirement~~of ~~costs,~~oil ~~we record as a liability~~ and asgas asales ~~cost~~obligations ofdue ~~the~~under ~~acquired~~normal ~~asset~~trade ~~the present value of the estimated future asset retirement obligation~~terms. ~~For~~Our ~~example,~~management ~~when~~regularly wereviews ~~drill~~trade areceivables ~~well, we record a liability~~ and anreduces ~~asset cost for~~ the ~~present~~carrying ~~value~~amount ofby ~~estimated~~a ~~costs~~valuation weallowance ~~will~~that ~~incur~~reflects ~~at the end of the well~~management’s ~~life~~best toestimate ~~plug~~of the ~~well,~~amount ~~remove~~that ~~surface~~may ~~equipment~~not ~~and~~be ~~provide restoration of the well site’s surface~~collectible. ~~Over~~At ~~time,~~December ~~accretion of the liability is recognized as an operating expense~~31, 2014 and ~~the~~2013, ~~capitalized~~management ~~cost~~had isdetermined ~~amortized~~no ~~over~~allowance ~~the~~for ~~expected~~uncollectible ~~useful~~receivables ~~life~~was ~~of the related asset~~necessary. ~~Our~~At ~~asset~~December ~~retirement obligations (“ARO”) relate primarily to the plugging~~31, ~~dismantlement,~~2014and ~~removal~~2013, ~~site~~we ~~reclamation~~had ~~and~~accounts ~~similar~~receivable ~~activities of our oil~~ and ~~gas~~receivables ~~properties.~~from ~~Due to~~ the ~~small~~sale ~~amount~~ of ~~such~~a ~~monies~~partial ~~related~~interest toin ~~the~~oil ~~asset~~wells ~~retirement obligations as~~ of ~~December 31~~$17,572 ~~2012~~ and ~~December 31~~$17, ~~2011~~318, ~~this amount is included in accrued expenses on the balance sheet~~respectively.

~~The~~Asset ~~following~~Retirement ~~table~~Obligations ~~reflects~~— When we incur an obligation for future asset retirement costs, we record as a liability and as a cost of the ~~change~~acquired inasset ~~ARO~~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 ~~years~~present ~~ended~~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. Due to the small amount of such monies related to the asset retirement obligations as of December 31, ~~2012:~~2014 and December 31, 2013, this amount is included in accrued expenses on the balance sheet.

	2012			2011
Asset retirement obligation beginning of period	$	48,860		$	46,590
Liabilities incurred		0			0
Liabilities settled		(23,180	)		0
Accretion		4,360			2,270
Revisions in estimated liabilities		-			-
Asset retirement obligation end of period	$	30,040		$	48,860
Current portion of obligation end of period	$	-		$	-

The following table reflects the change in ARO for the years ended December 31, 2014:

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 December 31, 2012 and 2011, 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.

	2014		2013
Asset retirement obligation beginning of period	$	31,640	$	30,040
Liabilities incurred		0		0
Liabilities settled		0		0
Accretion		1,600		1,600
Revisions in estimated liabilities		-		-
Asset retirement obligation end of period	$	33,240	$	31,640

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 December 31, 2014 and 2013, 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.

F-98

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

as of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

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. Commission and finder’s fee revenues were recorded upon the culmination of the sale of oil well interests between the third parties

Major Customers — During the years ended December 31, ~~2012~~2014 and ~~2011~~2013, we had two customers, 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.

~~Derivative~~Net ~~Financial~~Loss ~~Instruments~~Per -Share — ~~Our~~Basic ~~derivative~~net ~~financial~~income ~~instruments~~(loss) inper ~~the~~share ~~past~~is ~~consist~~computed ofby ~~embedded~~dividing ~~and~~net ~~free-standing~~income ~~derivatives~~(loss) ~~related~~attributable ~~primarily~~ to ~~the~~common ~~Alloy~~stockholders ~~Marketing~~by ~~and Promotions, LLC promissory note. The embedded derivatives include~~ the ~~conversion~~weighted ~~features,~~number ~~and~~of ~~liquidated~~common ~~damages~~shares ~~clauses~~outstanding induring the ~~registration rights agreements~~period. InAny ~~addition,~~common ~~under~~shares ~~the~~issued ~~accounting~~as ~~provisions, "Accounting for Derivative Financial Instruments Indexed to, and Potentially Settled in,~~ a ~~Company’s~~result ~~Own~~of ~~Stock,"~~ the ~~Company~~exercise isof ~~required to classify certain other non-employee~~ stock options and warrants ~~(free-standing~~would ~~derivatives)~~come asfrom ~~liabilities.~~newly ~~The~~issued ~~accounting~~common ~~treatment~~shares offrom ~~derivative~~our ~~financial~~remaining ~~instruments~~authorized ~~requires~~shares. ~~that~~For the ~~Company~~year ~~record~~ended ~~the~~December ~~derivatives~~31, ~~and~~2013, ~~related~~there ~~warrants~~were at3,393,000 ~~their~~stock ~~fair~~options ~~values~~outstanding asand $180,000 of ~~the~~convertible ~~inception~~debt, ~~date~~excluded offrom the ~~agreement~~computation ~~and~~of atdilutive ~~fair~~securities ~~value~~ as ofthe ~~each~~effect ~~subsequent~~would ~~balance~~have ~~sheet~~been ~~date~~anti-dilutive. ~~The~~For ~~fair~~the ~~value~~year ofended ~~all derivatives at~~ December 31, ~~2012~~2014, ~~and~~there ~~December~~were 313,215,000 ~~2011~~stock ~~totaled~~options $0outstanding and $1170,~~164,899,~~000 ~~respectively. Any change in fair value~~ of ~~these~~convertible ~~instruments will be recorded as non-operating~~debt, ~~non-cash~~excluded ~~income~~from ~~or expense at each reporting date. If~~ the ~~fair~~computation ~~value~~ of ~~the~~dilutive ~~derivatives~~securities isas ~~higher at~~ the ~~subsequent~~effect ~~balance~~would ~~sheet~~have ~~date,~~been ~~the Company will record a non~~anti-~~operating, non-cash charge~~dilutive. ~~If the fair value of the derivatives is lower at the subsequent balance sheet date, the Company will record non-operating, non-cash income.~~

At December 31, 2012 and 2011, derivatives were valued primarily using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of 179%, risk free interest rate of 1.00%, and expected life of three to five years.

The accounting guidance establishes a fair value hierarchy based on whether the market participant assumptions used in determining fair value are obtained from independent sources (observable inputs) or reflect the Company's own assumptions of market participant valuation (unobservable inputs). A financial instrument's categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The accounting guidance establishes three levels of inputs that may be used to measure fair value:

F-10

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, 2012 and 2011 and for the Years Ended December 31, 2012 and 2011

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

• Level 1—Quoted prices in active markets that are unadjusted and accessible at the measurement date for identical, unrestricted assets or liabilities; • Level 2—Quoted prices for identical assets and liabilities in markets that are inactive; quoted prices for similar assets and liabilities in active markets or financial instruments for which significant inputs are observable, either directly or indirectly; or • Level 3—Prices or valuations that require inputs that are both unobservable and significant to the fair value measurement.

The Company considers an active market to be one in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis, and views an inactive market as one in which there are few transactions for the asset or liability, the prices are not current, or price quotations vary substantially either over time or among market makers. Where appropriate the Company's or the counterparty's non-performance risk is considered in determining the fair values of liabilities and assets, respectively.

	Fair Value Measurements at Reporting Date Using
Description	Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Derivative securities – December 31, 2011		$	-	$	-		$	1,164,899
Derivative securities – December 31, 2012		$	-	$	-		$	0

As a result of the Company and at the advice of counsel, determined that the remaining legacy convertible debt instruments were no longer enforceable due to the statute of limitations, hence has written such debt off as other income during the year ended December 31, 2012, the related derivative financial instruments were no longer valid as well. See Note 9: Gain on Write-Off Debt Relief, Liquidated Damages and Derivatives. As a result the remaining outstanding derivative liabilities have been written off as other income during the year ended December 31, 2012.

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. Diluted net income (loss) per share reflects per share amounts that would have resulted if dilutive potential common stock had been converted to common stock. Included in the dilutive securities are 3,402,211 of options and warrants and 980,794 shares issuable upon a conversion of $180,000 of debt outstanding.

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 2012 and 2011 consolidated financial statements have been reclassified to conform to the December 31, 2012 financial statement presentation. Such reclassifications have had no effect on net income.F-9

Recent Accounting Pronouncements- All 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.

F-11

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

as of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

Reclassification — Certain amounts in the 2014 and 2013 consolidated financial statements have been reclassified to conform to the December 31, 2014 financial statement presentation. Such reclassifications have had no effect on net income.

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.

ASU 2014 -15 issued August 2014

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.

NOTE 3 — OIL AND GAS PROPERTIES AND EQUIPMENT.

Oil and Gas Properties and equipment consisted of the following:

	December 31, 2012			December 31, 2011
	December 31, 2014			December 31, 2013
Oil and gas properties, successful efforts method
Unevaluated costs, not yet subject to amortization	$	1,~~392~~212,~~679~~701		$	~~549~~1,~~868~~325,405
Evaluated costs		1,~~246~~869,~~077~~537			1,~~277~~525,~~914~~122
Asset retirement costs		39,600			39,600
		2,678,356			1,867,382
		3,121,839			2,890,127
Well equipment, furniture and software		~~157~~183,~~309~~809			~~231~~183,~~309~~809
		2,835,665			2,098,691
		3,305,648			3,073,936
Less accumulated depreciation, depletion and amortization		(794,041	)		(378,280	)
Less accumulated depreciation, depletion, impairments and amortization		(1,662,916	)		(1,260,075	)
Oil and gas property and equipment	$	21,~~041~~642,~~624~~731		$	1,~~720~~813,~~411~~861

The changes to the aforementioned accounts are discussed hereafter. The single largest event occurred in April 2012 with the simultaneous sales and acquisition of varied oil well interests and equipment.

Unevaluated Oil Properties

Costs directly associated with the acquisition and evaluation of unproved properties is 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
	Net Costs Incurred
Year ended December 31, 2012	$	842,811
Year Incurred
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
Prior to 2009		-
	$	1,212,701
	$	1,392,679

Costs associated with unevaluated properties are primarily lease acquisition costs. At December 31, ~~2012~~2014 and December 31, ~~2011~~2013, we drilled 123 and 73 dry holes respectively and recorded an impairment expense of $~~216~~37,~~739~~145 and $~~299~~120,~~750~~557, associated with dry holes. Pending costs of $~~100,715~~0 and $301,~~165~~640 for wells-in-progress existed at December 31, ~~2012~~2014 and ~~2011~~2013, 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 and sales of oil properties~~F-10

On January 15, 2011 per a Memorandum of Understanding the Company sold 32.5% working and royalty interests to five individuals and/or entities in the Charles and Lynda Anderson Well # 10 for $42,000. Two of these purchasers are without any additional costs, while the other three are responsible for 36% of the future completion and operating costs.

F-12

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

OnAcquisitions ~~August 31, 2011 the Company entered into a 15% interest in an 75% working interest in De Loy Brow #10 in Clinton County, Kentucky pursuant to the terms of that certain Assignment of Interest in Oil~~ and ~~Gas~~sales ~~Lease dated August 31, 2011 by and between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company~~ of ~~$10. The~~oil ~~Company is responsible for 25% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 75% of such costs.~~properties

On ~~September~~January 2023, ~~2011~~2013, per a Memorandum of Understanding the Company ~~sold~~participated ~~22.5~~and permitted 25% working ~~and royalty~~ interests toas ~~four~~the ~~individuals~~operator ~~and/or entities~~ in the ~~Charles~~Betty ~~and~~McCoomas ~~Lynda Anderson~~ Well #7 11at ~~for~~the ~~$32,000.~~cost ~~Two~~ of ~~these purchasers are without any additional costs~~$18,500 ~~while~~and ~~the~~is ~~other two are~~ responsible for 3632% of the ~~future~~all ~~completion~~costs ~~and~~associated ~~operating~~with ~~costs~~the well.

On ~~September~~April 3017, ~~2011~~2013 per a Memorandum of Understanding the Company sold 3227.5% working and royalty ~~interests~~interest to ~~four~~two individuals and/or entities in the ~~Charles~~Millard ~~and~~Willis ~~Lynda Anderson~~ Well #1 13 for $3822,000. ~~Two~~and ofis ~~these purchasers are without any additional costs, while the other two are~~ responsible for 3635% of all the ~~future~~costs ~~completion~~associated ~~and~~with ~~operating~~the ~~costs~~well.

On ~~October~~April 1123, ~~2011~~2013, per a Memorandum of Understanding the Company ~~sold~~participated ~~36.5~~and permitted 60% working ~~and royalty~~ interests toas ~~three~~the ~~individuals~~operator ~~and/or entities~~ in the ~~Kenneth~~Millard ~~Nadeau~~Willis Well # 1 ~~for~~at ~~$12,000.~~the ~~Two~~cost of ~~these~~$18,500 ~~purchasers are responsible for 20% of the future completion~~ and ~~operating costs, while the other individual~~ is responsible for 2565% of the all costs associated with the well.

On ~~December~~May 616, ~~2011,~~2013 per Memorandum of Understanding the Company ~~entered~~sold ~~into~~27.5% aworking ~~series~~and ofroyalty ~~transactions~~interest ~~which~~to ~~has~~two ~~resulted~~individuals and/or entities in the ~~sale~~Millard ofWillis ~~rights~~Well ~~under~~#2 ~~the~~for ~~Charles~~$22,000 and ~~Lynda~~is ~~Anderson~~responsible ~~lease~~for ~~(the~~35% ~~“Anderson~~of ~~Lease”)~~all ~~covering~~the ~~approximately~~costs ~~200~~associated ~~acres~~with the well.

InOn ~~the~~May ~~first transaction~~16, ~~the Company sold its interest~~2013, ~~ranging~~per ~~from~~a ~~27.3%~~Memorandum toof ~~87.5%,~~Understanding in the ~~Anderson~~Company ~~Lease~~participated toand Kpermitted &60% Kworking ~~Acquisitions,~~interests ~~LLC~~as ~~for $910,000, including all existing wells on~~ the ~~leasehold~~operator ~~and~~in the ~~related~~Millard ~~production~~Willis ~~equipment,~~Well ~~subject~~#2 toat ~~certain~~the ~~exceptions.~~cost ~~The~~of ~~Company retained 5% royalty interest in all existing wells~~$18,500 and ~~after~~is Kresponsible ~~& K has recouped their initial investment, an additional 5% royalty interest will be granted~~ for ~~all originally existing wells. The Company also received a participation right up to 30~~65% ~~net~~of ~~revenue working interest in an additional 10 new wells. In~~ the ~~second~~all ~~transaction,~~costs associated with the ~~proceeds from the Anderson Lease, the Guaranteed Contract with King’s Oil, LLC was paid in full~~well.

On ~~December~~July 169, ~~2011,~~2013 per a Memorandum of Understanding the Company ~~negotiated~~sold ~~the~~37.5% ~~sale~~working ~~of a third party oil~~ and ~~gas~~royalty ~~lease,~~interest ~~known~~to astwo ~~the~~individuals ~~Roquel~~and/or ~~Chambers~~entities ~~lease,~~in ~~located bordering~~ the ~~county~~Millard ~~lines~~Willis ofWell ~~Clinton~~#3 ~~County, Kentucky and Pickett County, Tennessee, and is an approximate 300 acre oil lease,~~ for ~~a finder's fee of~~ $6530,000 and ais 5%responsible ~~overriding~~for ~~royalty interest and also received a participation right up to 30~~45% ~~net~~of ~~revenue~~all ~~working~~the ~~interest~~costs inassociated anwith ~~additional~~the ~~10 new wells and an option to drill an additional 10 wells~~well.

On ~~December~~July 219, ~~2011~~2013, per a Memorandum of Understanding the Company participated and permitted ~~12.5~~50% working ~~and royalty~~ interests as the operator in the ~~Ralph~~Millard ~~Robbins~~Willis Well #3 at nothe cost toof ~~the~~$18,500 ~~Company~~ and nois ~~additional~~responsible ~~future~~for ~~completion~~55% ~~and~~of ~~operating~~the all costs associated with the well.

On ~~January~~July 319, ~~2012,~~2013 per a Memorandum of Understanding the Company ~~negotiated~~sold ~~the~~37.5% ~~sales~~working ~~of third party oil~~ and ~~gas~~royalty ~~leases,~~interest ~~known~~to astwo ~~the~~individuals ~~Bayer, Smith, Endicott~~ and/or ~~Warren~~entities ~~leases, located~~ in ~~Overton~~the ~~County,~~Millard ~~Tennessee~~Willis ~~and~~Well ~~totals~~#4 ~~approximately 500 acres oil leases~~ for ~~a finder's fee of~~ $7530,000 and ais ~~9.5%~~responsible ~~overriding~~for ~~royalty interest in the existing production of 1 well and 10~~45% ~~overriding royalty interest in the balance~~ of ~~these~~all ~~leases and at no upfront cost to~~ the ~~Company and no additional future completion and operating~~ costs. ~~The~~associated ~~Company~~with ~~also~~the ~~received a drilling participation right of up to 30% net working interest in up to 10 additional new wells per lease~~well.

On ~~March~~July 29, ~~2012~~2013, per a Memorandum of Understanding the Company participated and permitted ~~27.5~~50% working interests as the operator in the ~~Willard~~Millard ~~Delk~~Willis Well #14 at the cost of $18,500 and is responsible for 3255% of the all costs associated with the well.

On ~~March~~September 711, ~~2012~~2013, ~~per~~the aCompany ~~Memorandum~~completed ofthe ~~Understanding~~sale ~~the~~to ~~Company~~Aquilo ~~permitted~~Resources, 25LLC of its 60% working and operating interests in the ~~Billy~~Millard ~~Duvall~~Willis Well #1 atfor ~~the~~a ~~cost~~cash payment of $16229,~~500~~250, ~~and~~which isincluded ~~responsible~~a ~~for~~commission ~~30%~~payment of ~~the~~$5,000 ~~all~~to ~~costs~~Beaver ~~associated with the well~~Excavating.

On ~~April~~September 1117, ~~2012~~2013, per ~~Memorandum~~a Bill of ~~Understanding~~Sale on the ~~Roquel Chambers lease, dated December 16, 2011, the~~ Company ~~opted~~purchased ~~into~~a ~~the~~truck ~~participation~~to ~~right~~add to ~~drill~~their ~~Chambers~~fleet ~~Well #001~~ for ~~30% working interest at the cost of~~ approximately $1112,~~000~~ ~~and is responsible for approximately 35% of the costs associated with the well~~000.

On ~~April~~September 1230, ~~2012,~~2013 ~~the~~per ~~Company~~Memorandum ~~entered~~of ~~into~~Understanding athe ~~35%~~Company ~~interest~~sold ~~in a 100~~37.5% working ~~interest~~and ~~lease~~royalty ~~named~~interest ~~the~~to ~~Teddy~~two ~~Hicks~~individuals ~~Lease between the Company~~ and/or ~~Mr.~~entities ~~Daniel~~in ~~(Allen)~~the ~~Page,~~Millard aWillis ~~related~~Well ~~party,~~#5 for ~~an initial cost to the Company of~~ $~~10. The lease is of approximately 70 acres~~30,000 ~~located~~and ~~in Clinton County, Kentucky. The Company~~ is responsible for 4245% of all the costs onassociated ~~this~~with ~~well and Mr. Daniel (Allen) Page is responsible for~~ the ~~remaining 58% of such costs~~well.

~~F-13~~On September 30, 2013, per a Memorandum of Understanding the Company participated and permitted 50% working interests as the operator in the Millard Willis Well #5 at the cost of $18,500 and is responsible for 55% of the all costs associated with the well.

On October 11, 2013 per Memorandum of Understanding the Company sold 37.5% working and royalty interest to two individuals and/or entities in the Millard Willis Well #7 for $30,000 and is responsible for 45% of all the costs associated with the well.

On October 11, 2013, per a Memorandum of Understanding the Company participated and permitted 50% working interests as the operator in the Millard Willis Well #7 at the cost of $18,500 and is responsible for 55% of the all costs associated with the well.

F-11

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

Asas of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

On ~~April~~October 1711, ~~2012~~2013, ~~the~~per ~~Company completed the sale to Texas Mineral Properties, LLC, d/b/~~a ~~BSAG~~Memorandum ~~Properties, LTD~~ of ~~its~~Understanding ~~27.5% working and operating interests in 738 acres in Green County, Kentucky known as~~ the ~~J.R.~~Company ~~and~~participated ~~Pansy Clark lease, which also included 42 oil wells~~ and apermitted ~~checkerboard lease. We acquired these various interests in 2009 and 2010. The Company retained a 2.5~~50% working ~~and operating~~ interests inas ~~all of~~ the ~~wells~~operator ~~whereby~~in the ~~27.5%~~Millard ~~working~~Willis ~~and~~Well ~~operating~~#7 ~~interests~~at ~~were~~the ~~sold.~~cost Asof ~~consideration~~$18,500 ~~for our working~~ and ~~operating~~is ~~interests,~~responsible ~~under~~for ~~the~~55% ~~terms~~ of the ~~Contract~~all ~~For~~costs ~~Sale~~associated ofwith ~~Oil~~the &well. ~~Gas Leasehold Estate we received:~~

•On aOctober ~~cash~~25, ~~payment~~2013, per a Bill of ~~$716,666.68~~Sale ~~(including~~the ~~commissions~~Company ofpurchased a new truck to add to their fleet for approximately $~~316~~15,~~667),~~ 500.

•On December 19, 2013, per a 5Memorandum of Understanding the Company participated and permitted 43.75% ~~overriding~~working ~~royalty~~interests ~~interest~~as ~~(ORI)~~the operator in the William Johnson Well #1 in Fentress County, Tennessee at the cost of ~~100%~~approximately ~~interest~~$16,500 and is responsible for 50% of the ~~entire~~all JRcosts ~~and~~associated ~~Pansy~~with ~~Clark~~the ~~checkerboard~~well. ~~lease~~The ~~which~~Company is ~~also~~responsible ~~referred~~for to50% asof the ~~Clark~~costs ~~Brothers~~on ~~lease,~~this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

•On January 4, 2014, per a Memorandum of Understanding the Company participated and permitted 87.5% ~~ORI~~working ofinterests ~~100%~~as ~~interest~~the operator in the ~~Simmons~~Todd ~~lease~~Anderson inWell ~~Green~~#4 ~~County~~at the cost of approximately $27,500 ~~Kentucky~~and ~~which~~is ~~presently~~responsible ~~has~~for 14100% ~~operating~~of ~~oil~~the ~~wells,~~all costs associated with the well.

•On aFebruary 5%16, ~~ORI~~2014, per a Memorandum of ~~100~~Understanding the Company participated and permitted 43.75% ~~interest~~working interests as the operator in the ~~Blaydes~~Gerald ~~lease~~Norrad inWell ~~Green~~#3 ~~County~~at the cost of approximately $15,000. ~~Kentucky~~The ~~which~~Company ~~presently~~is ~~has~~responsible ~~seven~~for ~~operating~~50% ~~oil~~of ~~wells,~~the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 50% of such costs.

•On aMarch 5%26, ~~ORI~~2014 per Memorandum of ~~100~~Understanding the Company sold 37.5% working and royalty interest to two individuals and/or entities in the ~~Ervin~~Millard ~~lease~~Willis inWell ~~Green~~#8 ~~County~~for approximately $12,000 ~~Kentucky~~and ~~which~~is ~~presently~~responsible ~~has~~for ~~five~~45% ~~operating~~of ~~oil~~all ~~wells,~~the ~~and~~costs associated with the well.

•On aMarch 5%31, ~~ORI~~2014, per a Memorandum of ~~100~~Understanding the Company participated and permitted 43.75% ~~interest~~working interests as the operator in the ~~Hickerson~~Alvin ~~lease~~Parrish Well #1 in ~~Green~~Clinton County, Kentucky ~~which~~at ~~presently~~the ~~has~~cost ~~three~~of ~~operating~~approximately ~~oil~~$16,500 ~~wells~~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 30permitted 43.75% ~~drilling~~working ~~participation~~interests ~~rights~~as the operator in ~~additional~~the ~~wells~~Lester toClark be#1 ~~drilled~~in onFentress County, Tennessee at the ~~Blaydes,~~cost ~~Ervin,~~of ~~Hickerson,~~approximately ~~Simmons~~$16,500 JRand ~~Clark~~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 ~~Pansy~~Mr. ~~Clark~~Daniel ~~leases~~(Allen) Page is responsible for the remaining 50% of such costs.

~~Under~~On ~~the~~May ~~terms~~29, 2014, per a Memorandum of Understanding the ~~Agreement,~~Company weparticipated ~~were~~and ~~responsible~~permitted ~~for~~43.75% aworking ~~pro-rata~~interests ~~share~~as ofthe operator in the ~~closing~~Alvin ~~costs~~Parrish Well #2 in Clinton County, ~~estimated~~Kentucky toat bethe cost of approximately $1216,~~000,~~500 and ~~the~~is ~~payment~~responsible for 50% of the all ~~personal~~costs ~~property~~associated ~~taxes~~with ~~related~~the towell. ~~oil~~The ~~produced~~Company byis usresponsible for 50% of the ~~current~~costs ~~tax~~on ~~year~~this upwell toand Mr. Daniel (Allen) Page is responsible for the ~~date~~remaining 50% of ~~closing~~such costs.

AsOn aJune ~~result~~4, of2014, ~~the~~per ~~aforementioned~~a ~~transaction~~Memorandum of ~~acquiring~~Understanding ~~these new interests in operating wells,~~ the Company ~~obtained~~participated anand ~~appraisal~~permitted of50% ~~such~~working ~~additional oil well~~ interests ~~acquired.~~as ~~The~~the ~~fair~~operator ~~value~~in of the ~~additional~~Millard ~~oil~~Willis ~~well~~Well ~~interests~~#8 ~~acquired~~at ~~were $862,370 plus~~ the ~~cash~~cost ~~consideration received~~ of $~~400~~18,~~000~~500 ~~aggregated to a sale of oil~~ and ~~gas~~is ~~lease~~responsible ~~revenue~~for 55% of ~~$1,262,370,~~the ~~which~~all ~~has been recorded as revenues. The~~ costs ~~attributed~~associated towith this transaction amounted to $415,538 of book value relinquished of oil and gas property value and $49,478 of recorded value of related equipment, which has been presented as a cost of oil and gas leases sold in the ~~amount of $465,016~~well.

On ~~April~~June 2430, ~~2012,~~2014 per Memorandum of Understanding on the ~~Roquel~~Company ~~Chambers~~sold ~~lease,~~37.5% ~~dated~~working ~~December~~and ~~16,~~royalty ~~2011,~~interest ~~the~~to ~~Company~~two ~~opted~~individuals ~~into~~and/or ~~the~~entities ~~participation~~in ~~right~~the toMillard ~~drill~~Willis ~~Chambers~~ Well #~~002~~9 for ~~30% working interest at the cost of approximately~~ $1135,000 and is responsible for ~~approximately 35~~45% of all the costs associated with the well.

On ~~May~~August 74, ~~2012~~2014, per a Memorandum of Understanding on the ~~Robert~~Company ~~Simmons~~participated ~~lease,~~and ~~dated~~permitted ~~December~~50% ~~16,~~working ~~2011,~~interests as the ~~Company~~operator ~~opted~~in ~~into~~ the ~~participation~~Millard ~~right~~Willis ~~to drill Simmons~~ Well ~~TNKY~~#~~0012~~9 ~~for 23.775% working interest~~ at the cost of ~~approximately~~ $1218,~~000~~500 and is responsible for ~~approximately 30~~55% of the all costs associated with the well.

On ~~May~~August 815, ~~2012~~2014, ~~per~~the aCompany ~~Memorandum~~entered ofinto ~~Understanding~~a ~~the~~50% ~~Company~~interest ~~permitted~~in 25an 87.5% working ~~interests~~interest inlease named the ~~Billy~~Johnny ~~Duvall~~Ringley ~~Well~~Lease #2between at the ~~cost~~Company ofand ~~$16~~Mr. Daniel (Allen) Page,~~500~~ ~~and~~a isrelated ~~responsible~~party, for ~~30%~~an ofinitial cost to the ~~all~~Company ~~costs~~of ~~associated~~$1,000. ~~with~~The ~~the~~lease ~~well~~is of approximately 68 acres, located in Cumberland County, Kentucky.

On ~~May~~August 2520, ~~2012~~2014, per a Memorandum of Understanding on the ~~Robert~~Company ~~Simmons~~participated ~~lease,~~in ~~dated~~20% ~~December~~working ~~16,~~interests ~~2011;~~in the ~~Company~~Kyle ~~opted~~Padgett ~~into~~well ~~the participation right to drill Simmons Well TNKY~~#~~0013~~7 ~~for 23.775% working interest~~ at the cost of ~~approximately~~ $124,~~000~~250 and is responsible for ~~approximately 30~~25% of the all costs associated with the well.

On ~~July~~September 108, ~~2012~~2014, ~~per Memorandum of Understanding on~~ the ~~Blaydes~~Company ~~lease,~~entered ~~dated~~into ~~December~~an ~~16,~~87.5% ~~2011,~~working ~~the~~interest ~~Company~~lease ~~opted~~named ~~into~~ the ~~participation~~William ~~right~~Warren toII ~~drill~~Lease ~~Blaydes~~between ~~#Coomer1~~the Company for ~~12.38%~~an ~~working~~initial ~~interest~~cost atto the ~~cost~~Company of ~~approximately~~ $~~6,000~~10. ~~and~~The lease is ~~responsible~~of ~~for~~ approximately ~~15%~~640 ofacres, ~~the~~located ~~costs~~in ~~associated~~Overton ~~with~~County, ~~the well~~Kentucky.

~~On July 10, 2012, per Memorandum of Understanding on the JR Clark lease, dated December 16, 2011, the Company opted into the participation right to drill JR Clark #W~~F-~~1 for~~ 12~~.38% working interest at the cost of approximately $6,000 and is responsible for approximately 15% of the costs associated with the well.~~

F-14

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

Asas of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

On ~~July~~September 108, ~~2012~~2014, per a Memorandum of Understanding on the ~~Pansy~~Company ~~Clark~~participated ~~lease,~~and ~~dated~~permitted ~~December~~43.75% ~~16,~~working ~~2011,~~interests as the ~~Company~~operator ~~opted~~in ~~into~~ the ~~participation~~Lester ~~right to drill Pansy~~ Clark #W-1 ~~for~~in ~~12.38%~~Fentress ~~working~~County, ~~interest~~Tennessee at the cost of approximately $616,~~000~~500 and is responsible for ~~approximately 15~~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 ~~July~~September 1026, ~~2012~~2014, per a Memorandum of Understanding on the ~~Pansy~~Company ~~Clark~~participated ~~lease,~~and ~~dated~~permitted ~~December~~43.75% ~~16,~~working ~~2011,~~interests as the ~~Company~~operator ~~opted~~in ~~into~~ the ~~participation~~David ~~right~~Wright toin ~~drill~~Fentress ~~Pansy~~County, ~~Clark~~Tennessee ~~#W-2 for 12.38% working interest~~ at the cost of approximately $616,~~000~~500 and is responsible for ~~approximately 15~~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 ~~July~~September 2730, ~~2012,~~2014 per a Memorandum of Understanding the Company ~~participated~~sold 50% working and ~~permitted~~royalty ~~25%~~interest ~~working~~to ~~interests~~four asindividuals ~~the~~and/or ~~operator~~entities in the ~~Teddy~~William ~~Hicks~~Warren II Well #1 atfor ~~the cost of~~ $1735,000 and is responsible for 3250% of ~~the~~ all the costs associated with the well.

On ~~July~~November 2718, ~~2012,~~2014 ,per ~~the~~Memorandum ~~Company~~of ~~entered~~Understanding ~~into~~the aCompany ~~85%~~sold ~~interest in a 100~~50% working ~~interest~~and ~~lease~~royalty ~~named~~interest ~~the~~to ~~Jimmie~~four individuals and/or ~~Linda~~entities ~~Irby~~in ~~Lease between~~ the ~~Company~~Billy ~~and~~Walker ~~Mr.~~Well ~~Daniel~~#1 ~~(Allen) Page~~for $35,000 aand ~~related~~is ~~party,~~responsible for an50% ~~initial~~of ~~cost~~all to the ~~Company~~costs ofassociated ~~$10.~~with ~~The~~the ~~lease is of approximately 31~~well.~~24 acres, located in Clinton County, Kentucky.~~

On August 21, 2012, per Memorandum of Understanding on the Chambers lease, dated December 16, 2011, the Company opted into the participation right to drill Chambers #27 for 30% working interest at the cost of approximately $6,000 and is responsible for approximately 30% of the costs associated with the well.

On August 22, 2012, per Memorandum of Understanding on the Robert Simmons lease, dated December 16, 2011; the Company opted into the participation right to drill Simmons Well W-1 for 15% working interest at the cost of approximately $12,000 and is responsible for approximately 15% of the costs associated with the well.

On August 27, 2012, per Memorandum of Understanding on the Bayer lease, dated January 31, 2012, the Company opted into the participation right to drill Bayer #10 for 30% working interest at the cost of approximately $9,500 and is responsible for approximately 30% of the costs associated with the well.

On September 15, 2012, per Memorandum of Understanding on the Charles and Linda Anderson lease, dated December 6, 2011, the Company opted into the participation right to drill Anderson #14 for 12.5% working interest at the cost of approximately $4,000 and is responsible for approximately 12.5% of the costs associated with the well.

On September 15, 2012, per Memorandum of Understanding on the Charles and Linda Anderson lease, dated December 6, 2011, the Company opted into the participation right to drill Anderson #15 for 30% working interest at the cost of approximately $4,000 and is responsible for approximately 30% of the costs associated with the well.

On September 24, 2012, the Company entered into an agreement for an 87.5% working interest in approximately 325 acres in Clinton County, Kentucky pursuant to the terms an Oil and Gas Lease dated September 24, 2012, by and between the Company and Millard Willis for an initial cost to the Company of $20,000. In accordance with the agreement, the Company is responsible for 100% of the costs on the Willis Lease.

On October 1, 2012, the Company entered into a 50% interest in a 87.5% working interest lease named the Gerald Norrad Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $10. The lease is of approximately 300 acres, located in Overton County, Tennessee.

On October 1, 2012, the Company entered into a 37.5% interest in a 75% working interest lease named the John Lee Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $10. The lease is of approximately 113 acres, located in Pickett County, Tennessee.

On October 1, 2012, the Company entered into a 25% interest in a 87.5% working interest lease named the Barclay Kirkland Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $10. The lease is of approximately 68 acres, located in Cumberland County, Kentucky.

On October 4, 2012, per a Memorandum of Understanding the Company participated and permitted 25% working interests as the operator in the Barclay Kirkland Well #1 in Cumberland County, Kentucky at the cost of approximately $15,500 and is responsible for 32% of the all costs associated with the well, pursuant to the terms of that certain Assignment of Interest in Oil and Gas Lease dated October 1, 2012 by and between the Company and Mr. Daniel (Allen) Page a related party for an initial cost to the

F-15

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, 2012 and 2011 and for the Years Ended December 31, 2012 and 2011

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

Company of $10. The Company is responsible for 32% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 68% of such costs.

On October 12, 2012, per a Memorandum of Understanding the Company participated and permitted 27.5% working interests as the operator in the William Bradley Well #3 at the cost of $18,500 and is responsible for 32% of the all costs associated with the well.

On October 15, 2012, per Memorandum of Understanding on the Chambers lease, dated December 16, 2011, the Company opted into the participation right to drill Chambers #W-1 for 15% working interest at the cost of approximately $6,000 and is responsible for approximately 15% of the costs associated with the well.

On October 23, 2012, per a Memorandum of Understanding the Company participated and permitted 43.75% working interests as the operator in the Gerald Norrad Well #1 at the cost of approximately $12,000 and is responsible for 50% of the all costs associated with the well.

On October 23, 2012, the Company entered into a 15% interest in an 75% working interest in John Lee Well #1 in Pickett County, Tennessee pursuant to the terms of that certain Assignment of Interest in Oil and Gas Lease dated October 1, 2012 by and between the Company and Mr. Daniel (Allen) Page a related party for an initial cost to the Company of $10. The Company is responsible for 25% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 75% of such costs.

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 the year ended December 31, 2012:

	Years Ended December 31
	2012		2011
Amortization of costs for evaluated oil properties	$	230,665	$	495,304
Depreciation of office equipment, furniture and software		26,616		35,526
Total DD&A expense	$	257,281	$	530,830

The resulting depletion for the year ended December 31, 2012 and 2011, respectively, 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.

InThe ~~April~~following ~~2007,~~table weshows ~~executed an agreement with Mr. Daniel (Allen) Page “Mr. Page” whereby we received $250,000 in funds to be advanced through a line of credit which was evidenced~~ by atype ~~convertible promissory note. The note bears interest at a rate~~ of ~~7.5%~~asset ~~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~~Depreciation, ~~unless~~Depletion itand isAmortization ~~converted~~(“DD&A”) orexpense ~~prepaid. Upon~~for ~~maturity or~~ the ~~conversion~~year ofended ~~the~~December ~~initial $250~~31,~~000~~ ~~principal~~2014 ~~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 27,2013:

F-16

	Years Ended December 31
	2014		2013
Amortization of costs for evaluated oil properties	$	190,035	$	212,352
Depreciation of office equipment, furniture and software		26,258		22,657
Total DD&A expense	$	216,293	$	235,009

The resulting depletion for the year ended December 31, 2014 and 2013, respectively, have been recorded under the caption heading “oil lease operating expense” on our Statement of Operations.

In April 2007, we executed an agreement with Mr. Daniel (Allen) Page “Mr. 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, and to extend the maturity date of the note to December 31, 2009. 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.

F-13

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

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

~~2007~~On December 8, 2009, Mr. Page ~~amended~~extended the ~~note~~due todate ~~provide~~of anthe ~~additional~~note ~~$100~~to June 30,~~000~~ of2010. The ~~working~~warrants ~~capital~~we towill usissue Mr. ~~Under~~Page ~~the~~will ~~terms~~expire offour ~~the~~years ~~amendment,~~from the ~~additional~~date ~~$100~~of issuance,~~000~~ iswhich ~~convertible~~shall ~~into~~be ~~shares~~deemed ofto ~~our~~be ~~common~~on ~~stock~~the atearlier aof ~~price~~(i) ~~per~~the ~~share~~maturity ~~equal~~date toof ~~$0.18.~~the Asnote; ~~consideration~~(ii) ~~for~~the ~~this~~date ~~increase~~on ofwhich ~~availability under~~ the ~~credit~~funds ~~line,~~are atadvanced ~~such~~in ~~time~~full asand ~~the~~owing ~~note~~by ~~matures~~us; or he(iii) ~~converts~~ the ~~additional~~date ~~$100,000~~on ~~into~~which ~~common stock,~~ we ~~agreed~~elect to ~~issue~~pay ~~him~~off athe ~~warrant~~note toin ~~purchase~~full ~~shares~~during ofthe ~~common~~term. We ~~stock~~agreed ~~equal~~ to ~~20%~~register offor resale the ~~total~~ shares tounderlying ~~be issued upon~~ the ~~conversion~~convertible ofnote ~~that~~and ~~portion~~warrants, ofbut ~~the~~we ~~note~~have ~~with~~not anfiled ~~exercise~~the ~~price~~required ofregistration $0statement.18 ~~per share.~~ On ~~May~~June 129, ~~2009~~2010, weMr. ~~entered~~Page ~~into~~extended athe ~~second~~due ~~amendment~~date of the note to ~~provide~~December ~~for an additional $50~~31,~~000~~ of2010. ~~working~~Effective ~~capital~~December to13, us2010, ~~bringing~~ the ~~total~~Company ~~amount~~entered ~~available~~into ~~under~~a ~~the~~Fifth ~~credit~~Amendment ~~line~~ to ~~$400,000, and to extend~~ the ~~maturity~~Convertible ~~date~~Line of ~~the~~Credit ~~note~~Note towith ~~December~~Mr. ~~31,~~Daniel ~~2009.~~(Allen) ~~Under~~Page ~~the~~pursuant ~~terms~~to ofwhich ~~the~~he ~~amendment,~~extended the ~~additional~~due ~~$50,000~~date ~~is convertible into shares~~ of ~~our~~all ~~common~~amounts ~~stock~~due atunder athe ~~price~~Convertible ~~per~~Line ~~share~~of ~~equal~~Credit to ~~$0.12.~~December As31, ~~consideration~~2011. ~~for~~The ~~this~~Convertible ~~extension,~~Line ~~upon maturity~~ of ~~the~~Credit ~~note~~is ornow atdue ~~such~~on ~~time~~demand. asIn heApril ~~converts~~2012, the ~~note~~Company weentered ~~agreed~~into ~~to issue him~~ a ~~warrant~~Security toAgreement ~~purchase~~with ~~shares~~Mr. ofPage ~~common~~pursuant ~~stock equal~~ to ~~20%~~which ofit ~~the~~granted ~~total~~him ~~share~~a ~~amount~~security ~~issued~~interest ~~upon~~in ~~conversion~~all of the ~~note,~~Company’s ~~with~~assets anas ~~exercise~~collateral ~~price~~for ofthe ~~$0.12~~amounts ~~per~~due ~~share,~~under ~~solely~~the asConvertible itLine ~~relates~~of ~~to this additional $50,000~~Credit.

OnAt December 831, ~~2009,~~2014 ~~Mr.~~and ~~Page extended the due date of the note to June 30~~2013, ~~2010. The warrants~~ we ~~will~~owed ~~issue~~ Mr. Page ~~will~~$170,000 ~~expire~~and ~~four years from the date of issuance~~$180,000, ~~which~~respectively ~~shall be deemed to be on the earlier~~ of ~~(i)~~principal ~~the maturity date of the note; (ii) the date on which the funds are advanced in full~~ and ~~owing~~approximately by$0 ~~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~~$455, ~~but~~respectively ~~we have not filed the required registration statement. On June 29, 2010, Mr. Page extended the due date~~ of ~~the~~accrued ~~note~~but tounpaid ~~December~~interest ~~31,~~under ~~2010.~~this ~~Effective~~credit ~~December 13, 2010, the Company entered into a Fifth Amendment to the Convertible Line of Credit Note with~~ line. Mr. Daniel ( Allen ) Page ~~pursuant~~a toprincipal ~~which~~stockholder ~~he extended the due date~~ of ~~all~~our ~~amounts~~Company, ~~due~~is ~~under~~ the ~~Convertible~~father ~~Line~~ of ~~Credit~~Mr. toKen ~~December 31~~Page, ~~2011.~~currently ~~The~~our ~~Convertible~~sole ~~Line~~officer ofand ~~Credit~~a ismember ~~now~~of ~~due~~our onBoard ~~demand~~of Directors. In ~~April~~We ~~2012,~~have ~~the~~also ~~Company~~ entered into a ~~Security~~number ~~Agreement~~of joint ventures with Mr. Page. ~~pursuant~~See toNote ~~which~~7 it– ~~granted~~Related ~~him~~Party ~~a security interest in all of the Company’s assets as collateral for the amounts due under the Convertible Line of Credit~~Transactions.

At December 31, 2012 and 2011, we owed Mr. Page $180,000 and $180,000, respectively of principal and approximately $455 and $0, respectively of accrued but unpaid interest under this credit line. Mr. Daniel ( Allen ) Page a principal stockholder 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. Page. See Note 7 – Related Party Transactions.

On April 1, 2005, we issued to Alloy Marketing and Promotions, LLC ("Alloy") an unsecured subordinated convertible promissory note in the principal amount of approximately $600,000 in payment of services provided to us by Alloy in 2004. The note matured upon demand by Alloy and could have been converted into shares of our common stock at any time after April 1, 2005 at a conversion price equal to 75% of fair market value of the common stock, defined as the lesser of (i) the average of the closing prices of the common stock for the five trading days immediately prior to the first to occur of (A) the date on which we include the registration of the resale of the common stock issuable upon conversion of the note in a registration statement filed with the Securities and Exchange Commission and (B) any date on which Alloy delivers to us a notice of conversion, or (ii) the closing price of the common stock for the trading day immediately prior to the first to occur of such dates. The note is in default. In connection with the subordinated convertible promissory note, we entered into a registration rights agreement with Alloy, pursuant to which we agreed to use our commercially reasonable efforts to file with the SEC a registration statement for offerings to be made on a continuous basis pursuant to Rule 415 under the Securities Act of 1933, as amended, with respect to the resale of the shares of common stock issuable upon the conversion of the note. We were obligated to pay Alloy a cash fee, as liquidated damages, equal to 1.50% of the original principal amount of the note for each thirty day period, beginning April 1, 2005, until the registration statement was declared effective. We would also have to make similar payments if the registration statement, after it is declared effective, ceases to be effective for more than twenty consecutive calendar days or more than thirty days in the aggregate during a year, or the common stock is not listed or quoted or is suspended from trading on any trading market for three consecutive trading days, and such suspension shall not have been lifted within thirty days or the common stock is not listed on another trading market. As a result of the Company and at the advice of counsel, determined that the remaining legacy convertible debt instruments were no longer enforceable due to the statue of limitations, hence has recognized a gain on forgiveness of debt during the year ended December 31, 2012, the related derivative financial instruments were no longer valid as well. As a result the remaining outstanding derivative liabilities have been written off as other income during the year ended December 31, 2012.

On October 28, 2005, we executed a convertible promissory note in the principal amount of approximately $50,000 with Mr. Robert H. Woods, Jr. under the terms of a convertible promissory note which bears interest at 7% per annum and is convertible into shares of our common stock at a conversion price of $0.25 per share, was due in October 2006. The purchaser was also issued corresponding five warrants to purchase 40,000 shares of our common stock common stock at an exercise price of $0.25 per share which expired in October 2010. In connection with both the convertible note and the warrants, we entered into a registration rights agreement with the purchaser whereby we agreed to register for resale the shares underlying the convertible note and warrants.

F-17

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, 2012 and 2011 and for the Years Ended December 31, 2012 and 2011

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

On January 19, 2012, Mr. Woods converted his original note dated October 28, 2005 issued in the principal amount of $50,000 and had an outstanding balance of approximately $21,800 in accrued interest. The conversion price of $0.25 issued 287,146 shares of common stock.

At December 31, 2012 and 2011, we had accrued $0 and $742,684, respectively of liquidated damages as interest expense under this agreement. Under the provisions of the accounting guidance for, “Accounting for Contingencies” and “Accounting for Registration Payment Arrangements”.

Convertible notes payable and loans payable are summarized as follows:

	December 31, 2012		December 31, 2011
	December 31, 2014		December 31, 2013
Convertible note payable to a third party with an interest rate of 7% per annum due October 27, 2006	$	-	$	50,000
Convertible line of credit note payable to a related party with an interest rate of 7.5% per annum, secured, due on demand	$	170,000	$	180,000
Convertible line of credit note payable to a related party with an interest rate of 7.5% per annum, secured, due on demand		180,000		180,000
	$	170,000	$	180,000
Convertible note payable to Alloy, default interest rate of 18% per annum, payable upon demand		-		600,000
	$	180,000	$	830,000

NOTE 5 — INCOME TAXES.

We account for income taxes under the accounting guidance, “Accounting for Income Taxes,” which provides for an asset and liability approach in accounting for income taxes. Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences, using currently enacted tax laws, attributable to temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts calculated for income tax purposes.

Income tax expenses and effective income tax rates for the years ended December 31, ~~2012~~2014 and ~~2011~~2013 consist of the following:

	2012			2011
	2014			2013
Current taxes (federal and state benefit)	$	1(258,~~631,~~000	)	$	~~481~~(71,000	)
Permanent differences		~~(731~~66,000	)		~~(69,000~~0	)
Valuation allowance (NOL utilized)		(615,000	)		(412,000	)
Valuation allowance	$	192,000		$	71,000
Income tax expense (reduction)	$	285,000		$	0
Income (loss) before income taxes	$	(673,849	)	$	(183,842	)
Income (loss) before income taxes	$	4,262,538		$	1,257,598
Effective income tax rate		0	%		0	%
Effective income tax rate		7	%		0	%

F-1814

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 5 — INCOME TAXES (continued).

The effective income tax rate for the years ended December 31, ~~2012~~2014 and ~~2011~~2013 differ from the U.S. Federal statutory income tax rate as follows:

	2012			2011
	2014			2013
Federal statutory income tax rate		34	%		34	%
State income taxes, net of federal benefit		45	%		45	%
Permanent differences		(1710	%)		(5-	%)
Valuation allowance		(1429	%)		(3339	%)
Effective income tax rate		70	%		0	%

For federal income tax purposes, exploration and production companies usually deduct when incurred all intangible costs of drilling and completing wells. However, such companies are allowed the annual option of capitalizing portions of such costs and amortizing the capitalized costs over sixty months or over oil and gas reserves. We anticipate that amortization of the capitalized intangible costs will not significantly reduce future percentage depletion, which current tax law generally limits to the respective producing property’s income net of the amortization.

A 50% or more change in ownership of the Company over a three year period may result in a limitation as the portion of the net operating losses to be used in any given year. We may have triggered a limitation of the use of our net operating losses under IRC Section 382. We have yet to make such determination if in fact our portion of our net operating losses have been limited by past ownership changes.

The Company has net operating loss carryforwards as of December 31, ~~2012~~2014 and ~~2011~~2013 of $4243.64 million and $4542.~~1million~~6 million, respectively. These net operating loss carryforwards expire at various dates through ~~2032~~2034. The related deferred tax assets of $16.64 million and $1716.34 million have been fully reserved, primarily due to the lack of recurring income from operations. ~~The Company has a deferred tax liability of $.3 million arising from the book gain for the fair value of oil wells acquired in the April 2012 transaction.~~

NOTE 6 — STOCKHOLDERS’ ~~EQUITY~~DEFICIT.

Common Stock

In August 2011, there were 3,242,239 shares of common stock returned to treasury as a result of a final determination by the ESOP Plan’s trustee, that such shares were in fact unearned. In addition the $6,207,000 recorded as unearned ESOP shares has been applied to additional paid in capital and common stock for the return of such shares.

On January 19, 2012, Robert H. Woods, Jr. converted his original note dated October 28, 2005 issued in the principal amount of $50,000 and had an outstanding balance of approximately $21,800 in accrued interest. The conversion price of $0.25 issued 287,146 shares of common stock.

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.

Stock Options

The 2004 Plan was approved by our stockholder in May 2004. No award could be granted under the 2004 Plan subsequent to the 10^th 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.

FIn 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-19qualified 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.

F-15

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 6 — ~~STOCKHOLDERS~~STOCKHOLDER’S DEFICIT ~~EQUITY~~ (continued).

In September 2010, 3,000,000 options exercisable at $0.20 a share held by Mr. Ken Page, expired. 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 0%, annual volatility of 234%, risk free interest rate of 0%, 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, 2010		4,557,664		$	0.31
Outstanding at December 31, 2012		3,393,000		$	0.31
Granted		-			0.00
Exercised		-			0.00
Expired or cancelled		-			0.00
Outstanding at December 31, 2011		4,557,664		$	.31
Outstanding at December 31, 2013		3,393,000		$	0.31
Granted		-1,560,000			-0.00
Exercised		-			-0.00
Expired or cancelled		(1,~~164~~738,~~664~~000	)		0.1700
Outstanding at December 31, 2012		3,393,000		$	.48
Outstanding at December 31, 2014		3,215,000		$	0.31

The following table summarizes information about options outstanding and exercisable at December 31, ~~2012~~2014:

		Options Outstanding and exercisable		~~Options Outstanding and exercisable~~
		Number Outstanding		~~Number Outstanding~~	Weighted- Average Remaining Life In Years		~~Weighted- Average Remaining Life In Years~~	Weighted- Average Exercise Price		~~Weighted- Average Exercise Price~~	Number Exercisable		~~Number Exercisable~~
Range of exercise prices:
$.01	to	$0.24			180,000			2.75		$	0.12			180,000
$0.01 to $0.24			1,560,000			4.5		$	0.16			1,560,000
$0.25	-	$0.50			3,133,000			1.95			0.37			3,133,000
$0.25 - $0.50			1,575,000			0.95			0.30			1,575,000
$0.51	-	$1.00			80,000			4.08		$	0.56			80,000
$0.51 - $1.00			80,000			2.08			0.56			80,000
					3,393,000					$	0.31			3,393,000
			3,215,000					$	0.31			3,215,000

The compensation expense attributed to the issuance of the options and warrants will be recognized as they vest / earned. These stock options and warrants are exercisable for five to ten years from the grant date. The unamortized compensation expense attributed to the unvested options as of December 31, 2014 was $149,389.

The intrinsic value of these options and warrants at December 31, ~~2012~~2014 and ~~2011~~2013 was $~~342,910~~0 and $473,~~467~~600, respectively.

Unearned ESOP Shares

On December 1, 1999, we established a leveraged ESOP that covered all employees who completed 1,000 or more hours of service in a Plan year. To establish the plan, the ESOP borrowed $10,000,000 from Mr. Teng, then our majority stockholder, which we then used to purchase all of our outstanding preferred stock (a total of 1,350,000 shares) from Mr. Teng at the then estimated fair value, $7.41 per share. The preferred stock was convertible into common stock at an exchange rate of 1 share of preferred stock to 3.12828 shares of common stock, and in September 2004, the ESOP converted all of its preferred stock to common stock. We received no funds from the formation of the ESOP; however, we were required to record the ESOP's liability on our books as we had guaranteed the ESOP debt (see below), in accordance with the accounting guidance, "Employers' Accounting for Employee Stock Ownership Plans." Under the accounting guidance, we recorded an unearned employee benefit expense related to the cost basis of unreleased shares (determined based on the portion of the ESOP loan obligation not yet repaid by the ESOP – see below), and, as such, we recorded it as a reduction to stockholders' equity, "Unearned ESOP shares."

In connection with the conversion of preferred stock to common stock by our LAN Plus Employee Stock Ownership Plan (the “ESOP”) in September 2004, we issued the ESOP 4,253,567 shares of our common stock. Of the 4,253,567 shares which are issued and outstanding in the name of the ESOP, we were previously advised by the ESOP’s trustee that 1,011,328 of those shares were earned by the plan participants and the balance of 3,242,239 shares represent unearned shares.

F-20

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, 2012 and 2011 and for the Years Ended December 31, 2012 and 2011

NOTE 6 — STOCKHOLDERS’ EQUITY (continued).

In August 2011 we completed the process of cancelling the unearned shares and returned to the status of authorized but unissued stock, and delivering a certificate to the trustee representing the earned shares. The accounting for the cancellation and return to treasury of the unearned shares of 3,242,239, was to apply the recorded value of $6,207,000 attributed to such unearned shares to additional paid in capital and to the extent par value for the common stock. In the event a terminated ESOP participant desires to sell his or her shares of our common stock, under the terms of the ESOP we may be required to purchase the shares from the participant at their fair market value.

NOTE 7 — RELATED PARTY TRANSACTIONS.

The Company has 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~~May ~~2009~~2014, this employment agreement was amended to reduce the monthly salary to be $43,~~167.67~~500 a month and anthe ~~additional~~Company ~~120,000~~opting ~~options~~to ~~were~~pay ~~issued~~health ~~with~~insurance anin ~~exercise~~the ~~price~~amount of $0524.~~25,~~02. ~~vesting~~In 10addition,~~000~~ ~~options~~on ~~monthly~~June ~~commencing in September 2009. On December 14~~27, ~~2010~~2014 our Board of Directors granted Mr. Ken Page five year non-qualified options under to purchase 1,~~500~~560,000 shares of our common stock at an exercise price of $0.3016 per share. The ~~options~~Options were valued using the Black-Scholes Option Pricing Model with the following assumptions: dividend yield of 0%, annual volatility of ~~407~~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.

~~During~~On ~~2012~~December 19, Mr2013, per a Memorandum of Understanding the Company participated and permitted 43.75% ~~Ken~~working ~~Page~~interests ~~forgave~~as ~~accrued~~the ~~salary~~operator ~~due~~in the William Johnson Well #1 in Fentress County, Tennessee at the ~~amount~~cost of approximately $8516,~~076,~~500 ~~which~~and ~~had~~is ~~been~~responsible ~~accrued~~for ~~pursuant~~50% toof the ~~terms~~all costs associated with the well. The Company is responsible for 50% of ~~his~~the ~~employment~~costs ~~agreement~~on this well and Mr. ~~Such~~Daniel ~~monies~~(Allen) ~~have~~Page ~~been~~is ~~recorded~~responsible asfor athe ~~contribution~~remaining to50% ~~capital~~of such costs.

On ~~October~~February 1516, ~~2010~~2014, ~~the~~per ~~Company~~a ~~entered~~Memorandum ~~into~~of aUnderstanding ~~50%~~the ~~interest~~Company inparticipated anand 87permitted 43.575% working ~~interest~~interests inas ~~Robbins~~the ~~Well~~operator #2 in ~~Overton County, Tennessee pursuant to~~ the ~~terms~~Gerald ofNorrad ~~that~~Well ~~certain~~#3 ~~Assignment~~at ~~of Interest in Oil and Gas Lease dated October 15, 2010 by and between~~ the ~~Company and Mr. Daniel A. Page for an initial~~ cost ~~to the Company~~ of approximately $015,000. 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 August 31, 2011, the Company entered into a 15% interest in an 75% working interest in De Loy Brow #10 in Clinton County, Kentucky pursuant to the terms of that certain Assignment of Interest in Oil and Gas Lease dated August 31, 2011 by and between the Company and Mr. Daniel (Allen) Page a related party for an initial cost to the Company of $10. The Company is responsible for 25% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 75% of such costs.F-16

On April 12, 2012, the Company entered into a 35% interest in a 100% working interest lease named the Teddy Hicks Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $10. The lease is of approximately 70 acres, located in Clinton County, Kentucky. The Company is responsible for 42% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 58% of such costs.

On July 27, 2012, the Company entered into a 85% interest in a 100% working interest lease named the Jimmie and Linda Irby Lease between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $10. The lease is of approximately 31.24 acres, located in Clinton County, Kentucky.

On December 09, 2011, the Company made payments of approximately $300,000 towards accrued interest and principle reduction of the outstanding notes payable due to Mr. Daniel (Allen) Page and accrued consulting expenses. At December 31, 2012 and 2011, we owed Mr. Daniel (Allen) Page $180,000 and $180,000, respectively of principal and approximately $455 and $0, respectively of accrued but unpaid interest under this credit line.

In July 2012, the Company has entered into a one year consulting arrangement for services to be rendered from time to time by Mr. Daniel (Allen) Page who is also a principal stockholder of the Company and the father of the Company’s CEO for an annual fee of $40,000, which has since been extended annually. At December 31, 2012 and 2011 we owed Mr. Daniel (Allen) Page $31,149 and $0, respectively of accrued consulting expenses.

F-21

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 7 — RELATED PARTY TRANSACTIONS (continued).

On ~~October~~March 131, ~~2012~~2014, ~~the~~per ~~Company~~a ~~entered~~Memorandum ~~into~~of aUnderstanding ~~37.5%~~the ~~interest~~Company inparticipated aand permitted 43.75% working ~~interest~~interests ~~lease~~as ~~named~~ the ~~John~~operator ~~Lee~~in ~~Lease~~the ~~between~~Alan ~~the~~Parrish ~~Company~~Well ~~and~~#1 ~~Mr.~~in ~~Daniel~~Clinton ~~(Allen) Page~~County, aKentucky ~~related~~at ~~party~~the cost of approximately $16,500 ~~for~~and anis ~~initial~~responsible ~~cost~~for to50% of the ~~Company~~all ofcosts ~~$10~~associated with the well. The ~~lease~~Company is responsible for 50% of ~~approximately~~the ~~113~~costs ~~acres,~~on ~~located~~this inwell ~~Pickett~~and ~~County,~~Mr. ~~Tennessee~~Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On ~~October~~May 19, ~~2012~~2014, ~~the~~per ~~Company~~a ~~entered~~Memorandum ~~into~~of aUnderstanding ~~25%~~the ~~interest~~Company inparticipated aand 87permitted 43.575% working ~~interest~~interests ~~lease~~as ~~named~~the operator in the ~~Barclay~~Lester ~~Kirkland~~Clark ~~Lease~~#1 ~~between~~in ~~the~~Fentress ~~Company~~County, ~~and~~Tennessee ~~Mr.~~at ~~Daniel~~the ~~(Allen)~~cost ~~Page~~of approximately $16,500 aand ~~related~~is ~~party,~~responsible for an50% ~~initial~~of ~~cost~~the toall ~~the~~costs ~~Company~~associated ofwith ~~$10~~the well. The ~~lease~~Company is responsible for 50% of ~~approximately~~the 68costs ~~acres,~~on ~~located~~this inwell ~~Cumberland~~and ~~County,~~Mr. ~~Kentucky~~Daniel (Allen) Page is responsible for the remaining 50% of such costs.

On ~~October~~May 429, ~~2012~~2014, per a Memorandum of Understanding the Company participated and permitted 2543.75% working interests as the operator in the ~~Barclay~~Alan ~~Kirkland~~Parrish Well #12 in ~~Cumberland~~Clinton County, Kentucky at the cost of approximately $1516,500 and is responsible for 3250% of the all costs associated with the well~~, pursuant to the terms of that certain Assignment of Interest in Oil and Gas Lease dated October 1, 2012 by and between the Company and Mr~~. ~~Daniel (Allen) Page a related party for an initial cost to the Company of $10.~~ The Company is responsible for 3250% of the costs on this well and Mr. Daniel (Allen) Page is responsible for the remaining 6850% of such costs.

On ~~October~~August 2315, ~~2012~~2014, the Company entered into a 1550% interest in an 7587.5% working interest inlease ~~John~~named ~~Lee Well #1 in Pickett County, Tennessee pursuant to~~ the ~~terms~~Johnny ofRingley ~~that certain Assignment of Interest in Oil and Gas~~ Lease ~~dated October 1, 2012 by and~~ between the Company and Mr. Daniel (Allen) Page, a related party, for an initial cost to the Company of $101,000. The ~~Company~~lease is ~~responsible for 25%~~ of ~~the~~approximately ~~costs~~68 onacres, ~~this~~located ~~well~~in ~~and~~Cumberland ~~Mr.~~County, ~~Daniel (Allen) Page is responsible for the remaining 75% of such costs~~Kentucky.

At December 31, 2014 and December 31, 2013 we owed Mr. Page $170,000 and $180,000, respectively of principal and approximately $0 and $0, respectively of accrued but unpaid interest under this credit line. At December 31, 2014 and December 31, 2013 we owed Mr. Page $51,768 and $56,820, respectively of accrued consulting expenses.

NOTE 8 — 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.

NOTE 9 ─ ~~GAIN~~SUBSEQUENT ~~ON WRITE-OFF OF DEBT RELIEF, LIQUIDATED DAMAGES AND DERIVATIVES~~EVENTS.

~~Through~~On ~~December~~January ~~31, 2012 the Company recorded a gain on debt relief of $~~1,~~342,684,~~ a2015 ~~gain~~per onMemorandum ~~liquidated damages~~ of ~~$742,683~~Understanding ~~and a gain on derivatives of $1,164,899. Based upon~~ the ~~opinions of counsel, the~~ Company ~~has~~sold ~~recorded~~50% aworking ~~write-off~~and ofroyalty ~~the~~interest ~~Alloy promissory note attributed~~ to ~~our~~two ~~operations~~individuals ~~which~~and/or ~~were~~entities ~~discontinued~~ in ~~2005. The Company no longer reflects~~ the ~~liability~~Millard ~~represented~~Willis byWell ~~this contractual payable on its balance sheet based on the six-year statute of limitations under Delaware state~~ #10 ~~Del.~~for ~~C. 8109~~$35,000 ~~which~~and ~~requires~~is anresponsible ~~action~~for to50% ~~enforce a promissory note to be commenced within six (6) years~~ of all the ~~date~~costs ofassociated ~~cause~~with ~~of action accrued, of~~ the ~~State of Delaware~~well. .

InOn ~~addition~~January ~~during~~2, ~~the~~2015 ~~year~~per ~~ended~~Memorandum ~~December~~of ~~31,~~Understanding ~~2012,~~ the Company ~~recorded~~sold a50% ~~$359,826~~working ~~gain~~and onroyalty ~~the~~interest ~~write-off~~to oftwo ~~certain~~individuals ~~legacy~~and/or ~~payables~~entities ~~which~~in the ~~statute~~Johnny ofRingley ~~limitations~~Well ~~has~~#1 ~~expired~~for ~~relating~~$35,000 ~~the~~and ~~collectability~~is ofresponsible ~~these~~for ~~payables~~50% ~~attributed~~of toall ~~discontinued~~the ~~operations~~costs ofassociated ~~several~~with ~~years~~the ~~ago~~well.

~~In the year ended December 31, 2011 the Company recorded a gain on accounts payable of $1,380,645. Based upon the opinions of counsel, the Company has recorded a write~~F-off of the payables attributed to our operations which were discontinued in 2005. At December 31, 2011, the Company no longer reflects the liability represented by this contractual payable on its balance sheet based on the six-year statute of limitations under Section 4.16.080(3) of the Revised Code of the State of Washington.17

While the Company took these actions based upon an opinion of counsel it received that the statute of limitations would apply thereby making the contracts unenforceable and therefore uncollectable, there can be no assurances that these vendor may not raise exceptions to this interpretation which would toll the statute of limitations based on the uncertainty of case law in this area and the particular factual circumstances applicable to such vendor.

F-22

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 9 ─ SUBSEQUENT EVENTS (continued).

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 $35,000 and is responsible for 50% of all the costs associated with the well.

NOTE 10 — INFORMATION REGARDING PROVED OIL AND GAS RESERVES (UNAUDITED).

The Company continues to operate through its oil production in ~~2012~~2014 and some limited amounts of exploration. The information presented below regarding the Company’s proved developed producing reserves, proved developed and proved undeveloped reserves were prepared by independent petroleum engineering consultants. All reserves are located within the continental United States.

As at December 31, ~~2012~~2014 and ~~2011~~2013 the oil reserves consisted of the following;

~~Estimated Remaining Reserves at December 31,~~

Estimated Remaining Reserves at December 31,

2012

2011

2014

2013

~~Gross~~

Gross

~~Net~~

Net

~~Future Net Revenues~~

Future Net Revenues

~~Gross~~

Gross

~~Net~~

Net

~~Future Net Revenues~~

Future Net Revenues

Reserve Classification

~~Oil (Bbls)~~

Oil (Bbls)

~~Oil (Bbls)~~

Oil (Bbls)

~~Total ($)~~

Total ($)

~~Discount @ 10% ($)~~

Discount @ 10% ($)

~~Oil (Bbls)~~

Oil (Bbls)

~~Oil (Bbls)~~

Oil (Bbls)

~~Total ($)~~

Total ($)

~~Discount @ 10% ($)~~

Discount @ 10% ($)

Proved Developed

Producing

~~144~~54,~~159~~417

103,~~095~~409

~~832~~287,~~142~~328

~~486~~139,~~372~~923

43105,~~892~~487

97,~~544~~572

~~348~~638,~~910~~664

~~335~~354,~~433~~631

Non-producing

511,~~996~~645

32,~~819~~393

~~216~~169,~~600~~577

~~164~~90,~~173~~799

2920,~~516~~301

43,~~939~~585

~~286~~248,~~216~~566

~~216~~159,~~497~~183

Sub-total

~~150~~66,~~155~~062

135,~~914~~802

1456,~~048,742~~905

~~650~~230,~~545~~722

73125,~~408~~788

1411,~~483~~157

~~635~~887,~~126~~230

~~551~~513,~~930~~814

Proved Undeveloped

7512,~~595~~249

83,~~640~~644

~~534~~176,~~282~~213

~~347~~98,~~838~~819

4243,~~171~~740

210,~~109~~387

~~169~~532,~~984~~966

~~129~~317,~~941~~173

Total Proved

~~225~~78,~~750~~311

229,~~554~~446

1633,~~583,024~~118

~~998~~329,~~383~~541

~~115~~169,~~579~~528

1621,~~592~~544

~~805~~1,~~110~~420,196

~~681~~830,~~871~~987

Probable

~~156~~58,~~675~~335

3712,~~068~~753

2829,~~295,729~~066

1442,~~459,237~~527

4364,~~985~~346

213,~~200~~528

~~177~~838,~~183~~440

~~133~~490,~~771~~102

Possible

~~236~~148,~~445~~327

6838,~~039~~011

42,~~143~~423,~~719~~731

21,~~510~~199,~~875~~111

37214,~~512~~440

560,~~479~~324

~~218~~3,~~952~~899,959

~~146~~2,~~082~~153,055

Total All Reserves

~~618~~284,~~870~~973

~~127~~60,~~661~~210

83,~~022~~885,~~472~~915

41,~~968~~971,~~495~~179

~~197~~448,~~076~~314

2495,~~271~~396

16,~~201~~158,~~245~~595

~~961~~3,~~724~~474,144

Present worth discounted at 10% (PV-10 Value) is the estimated present worth of the future net revenues from our proved developed producing reserves before income taxes, discounted at 10% per annum. PV-10 Value is considered a non-GAAP financial measure under SEC regulations because it does not include the effects of future income taxes, as is required in computing the standardized measure of discounted future net cash flows. PV-10 Value is widely used by security analysts and investors when evaluating oil and natural gas companies. Because many factors that are unique to each individual company impact the amount of future income taxes to be paid, the use of a pre-tax measure provides greater comparability of assets when evaluating companies. PV-10 Value is computed on the same basis as the standardized measure of discounted future net cash flows but without deducting income taxes.

F-2318

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 10 — INFORMATION REGARDING PROVED OIL AND GAS RESERVES (UNAUDITED) (continued).

Estimated net quantities of proved developed and undeveloped reserves of oil and gas for the year ended December 31, ~~2012~~2014 and ~~2011~~2013 are presented in table below.

	Oil (BBLS)			Gas (MCF)
Beginning of year – January 1, 2011		126,676			-
Beginning of year – January 1, 2013		127,661			-
Provisions of previous quantity estimates		9(15,~~848~~966	)		-
Extensions, discoveries and improved recoveries		~~8,140~~-			-
Acquisitions		-
Sales of reserves in place		(~~115~~14,~~267~~632	)		-
Production		(41,~~926~~667	)		-
End of year – December 31, 2011		24,471			0
End of year – December 31, 2013		95,396			0
Provisions of previous quantity estimates		85(34,~~285~~406	)		-
Extensions, discoveries and improved recoveries		-			-
A Acquisitions		30,537			-
Acquisitions		-			-
Sales of reserves in place		~~(10,941~~-	)		-
Production		~~(1,691~~780	)		-
End of year – December 31, 2012		127,661			0
End of year – December 31, 2014		60,210			0
Proved developed reserves at December 31, 2011		24,471			0
Proved developed reserves at December 31, 2013		11,157			0
Proved developed reserves at December 31, 2012		127,661			0
Proved developed reserves at December 31, 2014		5,802			0

STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES

Future net cash flows presented below are computed using year-end prices and costs. Future corporate overhead expenses and interest expense have not been included.

	2012			2011
	2014			2013
Future cash inflows	$	115,~~577~~388,~~548~~279		$	28,~~017~~969,~~062~~100
Future costs:
Production		(1716,~~551,432~~955	)		(~~606~~1,~~475~~277,187	)
Development		(1583,~~574,050~~500	)		(~~128~~1,~~850~~194,134	)
Future income tax expense		(~~429~~201,~~595~~909	)		(80339,~~492~~186	)
		8,022,471			1,201,245
		3,885,915			6,158,593
Future net cash flows
10% discount factor		(31,~~053~~914,~~976~~735	)		(~~239~~2,~~521~~684,451	)
Standardized measure of discounted future net cash flows relating to proved reserves	$	41,~~968~~971,~~495~~180		$	~~961~~3,~~724~~474,142

The principal sources of changes in the standardized measure of discounted future net cash flows during the year ended December 31, ~~2012~~2014 and ~~2011~~2013 are as follows:

	2012			2011
	2014			2013
Beginning balance	$	~~961~~3,~~724~~474,142		$	4,~~878~~968,~~646~~495
Sales, net of production costs		(~~185~~63,~~164~~075	)		(~~640~~155,~~931~~199	)
Net changes in prices and production costs		~~183,972~~(936	)		~~168~~5,~~177~~551
Sales of minerals in place		~~(420,814~~-	)		(~~857~~37,~~179~~500	)
Acquisitions		~~862,369~~-			-
Development costs incurred during the year		~~365~~283,~~309~~804			~~333~~271,~~169~~731
Changes in estimated future development costs		1(610,~~445,200~~634	)		(~~275~~379,~~800~~916	)
Revisions in previous quantity estimates		(1,~~310~~247,~~624~~110	)		(21,~~771~~530,~~386~~743	)
Accretion of discount		96272,~~172~~266			~~106~~422,~~858~~132
Change in income taxes		~~349~~(137,~~103~~277	)		20(90,~~170~~409	)
Change in other					-
Ending balance	$	1,971,180		$	3,474,142
Ending balance	$	4,968,495		$	961,724

F-2419

TN-K ENERGY GROUP INC.

NOTES TO FINANCIAL STATEMENTS

As of December 31, ~~2012~~2014 and ~~2011~~2013 and for the Years Ended December 31, ~~2012~~2014 and ~~2011~~2013

NOTE 10 — INFORMATION REGARDING PROVED OIL AND GAS RESERVES (UNAUDITED) (continued).

The standardized measure of discounted future net cash flows relating to proved oil and gas reserves and the changes in standardized measure of discounted future net cash flows relating to proved oil and gas reserves were prepared in accordance with the provisions of the accounting guidance. Future cash inflows were computed by applying current prices at year-end to estimated future production. Future production and development costs (including the estimated asset retirement obligation) are computed by estimating the expenditures to be incurred in developing and producing the proved oil and gas reserves at year-end, based on year-end costs and assuming continuation of existing economic conditions. Future income tax expenses are calculated by applying appropriate year-end tax rates to future pretax cash flows relating to proved oil and gas reserves, less the tax basis of properties involved and tax credits and loss carryforwards relating to oil and gas producing activities. Future net cash flows are discounted at the rate of 10% annually to derive the standardized measure of discounted future cash flows. This calculation procedure does not necessarily result in an estimate of the fair market value of the Company’s proved oil and gas properties. All new well interest acquired, sold and drilled in 2014 were exploratory and have yet to consummate any production of oil.

F-2520

Filing Compare · TN-K ENERGY GROUP INC.