northtexas.htm

0001096906-15-000404.txt : 20150417 0001096906-15-000404.hdr.sgml : 20150417 20150416174620 ACCESSION NUMBER: 0001096906-15-000404 CONFORMED SUBMISSION TYPE: 10-K PUBLIC DOCUMENT COUNT: 13 CONFORMED PERIOD OF REPORT: 20141231 FILED AS OF DATE: 20150417 DATE AS OF CHANGE: 20150416 FILER: COMPANY DATA: COMPANY CONFORMED NAME: North Texas Energy, Inc. CENTRAL INDEX KEY: 0001514994 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 274556048 STATE OF INCORPORATION: NV FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K SEC ACT: 1934 Act SEC FILE NUMBER: 333-178251 FILM NUMBER: 15776141 BUSINESS ADDRESS: STREET 1: 5057 KELLER SPRINGS ROAD, SUITE 300 CITY: ADDISON STATE: TX ZIP: 75001 BUSINESS PHONE: 469-718-5572 MAIL ADDRESS: STREET 1: 5057 KELLER SPRINGS ROAD, SUITE 300 CITY: ADDISON STATE: TX ZIP: 75001 10-K 1 northtexas.htm NORTH TEXAS ENERGY, INC. 10K 2014-12-31 northtexas.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

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

For the fiscal year ended: December 31, 2014

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

For the transition period from _____________________________ to _____________________________________________

Commission file number: 333-178251

NORTH TEXAS ENERGY, INC.

(Exact name of registrant as specified in its charter)

NEVADA	27-4556048
State or other jurisdiction of incorporation or organization	(I.R.S. Employer Identification Number)

5057 KELLER SPRINGS ROAD, SUITE 300, ADDISON, TEXAS	75001
(Address of principal executive offices)	(Zip Code)

Registrant's telephone number, including area code:	469-718-5572

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

Title of each class	Name of each exchange on which registered

COMMON	NONE

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

(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 [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. [ ] 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 report), and (2) has been subject to such filing requirements for the past 90 days. [X] Yes [ ] No

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of 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.[ ]

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

Large accelerated filer [ ]	Accelerated filer [ ]

Non-accelerated filer [ ]	Smaller reporting company [X]

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act): [ ] Yes [X] No

As of April 14, 2015, 6,519,815 shares of common stock, $0.00001 par value per share, were outstanding.

PART I

Item 1. Business.

Business Overview and Capital Fund Raising

North Texas Energy, Inc. (“NTE”, “the Company”, “we”) is a non-traditional producer of crude oil. The Company acquires oil and gas leases with non-functioning wells and uses Enhanced Oil Recovery Methods (“EOR”) to bring wells back into production. The Company currently holds oil and gas leases in Milam County, Texas of which it holds one-hundred percent of the working interest. In order to execute its business plan to recover the oil and gas reserves on its leased property, the Company prepared and filed an S-1 Registration Statement for the sale of two million shares of its common stock. The price of the common shares was set at $2.00 per share. The registration statement became effective on March 29, 2013. The sale of the common shares was and is being conducted without an underwriter.

The Company's S-1 Registration Statement became effective on March 29, 2013. Beginning in June 2013 and through December 31, 2013, the Company issued 346,765 shares registered in the stock offering. The shares were sold at the offering price of $2.00 per share yielding to the Company an equity capital infusion of $693,530. The Company also issued 1,500 shares of restricted stock for cash at $1.00 per share to a private party. The total stock sales combined netted the Company $695,030 in capital infusion prior to December 31, 2013. The Company continues to issue shares of its common stock in accordance with the registration statement and will continue until all of the 2,000,000 shares are sold. During 2014, the Company sold an additional 307,800 shares of common stock at $2.00 per share for cash proceeds of $615,600.

NTE is an Enhanced Oil Recovery (“EOR”) company. EOR is a term used to describe a variety of methods by which oil reserves are recovered from existing oil fields that were not completely exhausted using standard methods. We are not an “exploration company” in the sense that our business and our methods do not involve an attempt to explore for new oil reserves but rather to exploit existing known oil fields using other than “standard” recovery methods. In simplified terms, the “standard” methods of producing oil and natural gas from its location in natural reservoirs in the earth is to drill a relief (well) into the reservoir and allow the reservoir's crude oil to surface because of the natural pressure that exists in the reservoir structure underground. Once a well is finished and well casing is in place, the oil and natural gas will surface under its own pressure or with a small amount of suction introduced into the well. As the oil surfaces so does the natural gas. The gas and oil are separated and stored or delivered directly to market.

Enhanced Oil Recovery methods identify the process(s) by which substantial amounts of oil and gas that remain in a field reservoir, after standard recovery methods are exhausted, can be recovered using a variety of methods of enhancing the natural pressure in a reservoir or using some other method to release additional trapped oil in the reservoir. EOR allows for the recovery of significantly more oil from the same field by introducing additional pressure or other geological changes in the reservoir. The original well, well casing and well head equipment, are used in the process.

NTE initially uses an EOR method called “microbial injection” to induce pressure in its oil field reservoirs and allow for the remaining oil reserves to be recovered. Microbial injection is the process by which nutrients or compounds are injected into an oil field to allow for the natural enhancement of the movement and release of the oil out of the reserve. According to the U.S. Department of Energy Fossil Energy report on Oil and Natural Technologies “Enhanced Oil Recovery” Conventional primary and secondary recovery operations often leave two-thirds of the oil in the reservoir at the time of abandonment. Enhanced oil recovery methods have the potential for recovering much of the remaining oil. - U.S. DOE. The concept is to use natural environmental reactions to improve the recovery of oil trapped in porous media in the reservoir or without sufficient pressure to allow the oil and gas to be expressed normally from the reservoir to above ground. In each different oil field, the method by which EOR can be successful is dependent on the oil field and reservoir structure. The uniqueness of each field may involve unique EOR methods which can be any combination of methods involving the use of expertise in the disciplines of geology, chemistry, and microbiology as well as fluid mechanics and a variety of engineering applications.

Corporate History and Background

The Company was organized in Nevada in January 2011. We are a combination of two companies, each originally founded for the same purpose. The predecessor to NTE is Remington Oil & Gas, Inc., a Nevada corporation, and its predecessor is Remington Oil & Gas LLC., a Texas Limited Liability Company. During 2009, Remington Oil & Gas, LLC acquired oil field leases in North Texas, in Upshur country. In January 2010, Remington Oil & Gas, Inc. acquired all of the outstanding ownership interests of Remington Oil & Gas, LLC. In the process, Remington Oil & Gas, Inc. acquired the oil and gas leases in North Texas that had been previously assigned to Remington Oil & Gas, LLC. Effective in January 2011, North Texas Energy, Inc. acquired Remington Oil & Gas, Inc. through a Purchase and Sale Agreement. The Purchase and Sale Agreement transferred title of Remington’s well-head equipment to North Texas Energy, Inc. and provided for the acquisition of all of the outstanding shares of Remington Oil & Gas, Inc. by North Texas Energy, Inc. in a one-for-one share exchange.

Properties

The Company has leased property in Milam County Texas. The lease consists of 11 existing producing wells and started to produce crude oil since December 2013. The lease also consists of three existing wells that the Company plans to use for injection. Because the Company currently has only insignificant production, none of the reserves were classified as proved as of December 31, 2014. The reserves disclosed in Exhibit 99.1 are a restatement of the reserves disclosed in the 2013 10-K and a disclosure of the additional reserves acquired during the 2014 calendar year.

Oil and Gas Properties, Wells, Operations and Acreage

The following table sets forth information relating to our principal properties as of December 31, 2014:

										2014 Net Production
	Net acreage		Average working interest %			Gross producing wells		Net Possible /Probable reserves (bbls)		Oil (bbls)		Natural Gas (mcf)
Milam County, Texas		223		100	%		11		1,800,429		1,062		-

Reserve Estimates-Oil and Gas Reserves

	Oil
	(bbls)
Reserve category
Probable Undeveloped Non-Producing Reserves
Milam County, Texas		803,937
Possible Undeveloped Non-Producing Reserves
Milam County, Texas		996,492
Total Undeveloped Non-Producing Reserves		1,800,429

Due to the inherent uncertainties and the limited nature of reservoir data, reserves are subject to change as additional information becomes available. The estimates of reserves are based on various assumptions, including those prescribed by the SEC, and are inherently imprecise. Although we believe these estimates are reasonable, actual reserves may vary substantially from these estimates.

We recategorized our reserves from proved to unproved due to the current production levels. Reserves will become proved when production is increased

Oil and Gas Production, Production Prices and Production Costs

The following table sets forth certain information regarding the production volumes, average prices received and average production costs associated with our sales of gas and oil for each of the three years ended December 31, 2014:

	Year Ended December 31,
	2014		2013		2012
Net Production:
Oil (Bbls):
Milam County, Texas		1,062		120		-
Average oil sales price($ per Bbl):
Milam County, Texas		88.43		-		-
Average production costs ($ per Bbl):
Milam County, Texas		93.67		-		-

Drilling and other Exploratory and Development Activities

The Company is an oil and gas producing company that currently has no exploration activities. The Company is an oil and gas producing company that attempts to produce crude oil from existing wells on its leased properties. However, beginning in 2015 in the first quarter the Company plans to drill and complete at least one new well on its leased properties in order to apply new drilling and recovery technology to its efforts in recovering the estimated reserves in its leased properties

Present Activities

As disclosed earlier, the Company plans to drill new wells on its current leases in 2015 and has refurbished several shut-in wells on its leased oil and gas properties. As of December 31, 2013, the Company had refurbished a total of 6 wells that it has on its Balch Lease. Late in December of 2013, those six wells began producing small amounts of crude oil. The Company refurbished an additional 5 wells in 2014 and has a total of 11 operational wells on its properties.

Delivery Commitments

The Company has no contractual commitments to deliver or sell any oil or gas production from its leased oil and gas properties as of the date of this report or at December 31, 2014.

Operations

The Company began the year with oil and gas leases secured in Milam County Texas. In Milam County (Balch Lease) the Company had 11 installed wells that had been shut-in because the wells were producing large amounts of paraffin with the oil they produced. The Company's production plan was to introduce a process called “Microbial Enhanced Oil Recovery” or MEOR. This process introduces microbial materials into the well geology enhancing the production of oil that previously was prevented by the status of the geological structure. We introduced the technology in six wells on the Balch lease that we planned to bring into production. The outcome was that the Microbial Enhancement thinned the paraffin significantly enough to allow oil production to begin again in six wells as of December 31, 2013

Once the MEOR concept was proven, we began the development of the lease property including the installation of new storage tanks, land clearing, fencing, electrical power, flow lines, pumping equipment, oil separation and collection equipment and improved down-hole production equipment to further enhance production. So, by December 31, 2013 we had proved our MEOR concept, installed a production infrastructure and brought six wells into production.

In the month of December 2013 we produced approximately 120 barrels of oil from the refurbished wells on the Balch Lease. As of this reporting date, the Company had a total of eleven producing wells on its Balch Lease. The Company furthered its development of its oil and gas leased properties started from 2014 by introducing the MEOR technology into wells and the geology on leases it acquired after December 31, 3013.

Development Plans

Plans are to bring all of the wells on all of the leased property into production within 2 years. The Company has a total of 18 wells in place on a total of 227 gross well acres. The Company acquired oil and gas leases adjacent to the Balch Lease described as the “McGregor Lease” in July of 2013. The McGregor lease totals 35 gross well acres and has three installed wells. All of the McGregor wells will be treated with the MEOR technology, refurbished and brought on-line in the first half of 2014. The Company acquired additional leases adjacent to the Balch Lease after December 31, 2013. Those leases are the “Cromwell” and “Hicks” leases and contain 123 and 87 gross well acres with 6 and 5 installed wells, respectively. The Company is currently treating and bringing on-line wells on those properties. The Company plans on having all 18 of its installed wells treated and producing within 2 years. Additionally, the Company is planning in 2015 to drill new wells on its leased properties in order to maximize its recovery of the crude oil demonstrated to be contained in the reservoir on its leased properties.

Employees

As April 15, 2015, we have 1 full-time employee and 1 part-time employee. The employees are not covered by a collective bargaining agreement, and we do not anticipate that any of our future employees will be covered by such agreements. We engage consultants on an as-needed basis for operation.

Regulatory Matters

The oil and gas industry is subject to regulation by numerous national, state and local governmental agencies and departments. Compliance with these regulations is often difficult and costly and noncompliance could result in substantial penalties and risks. The failure to comply with the statutes, rules and regulations could result in the imposition of fines and penalties and the suspension or cessation of operations in affected areas. We routinely obtain permits for our facilities and operations in accordance with the applicable laws and regulations on an ongoing basis. There are no known issues that have a significant adverse effect on the permitting process or permit compliance status of any of our facilities or operations.

The ultimate financial impact of environmental laws and regulations is neither clearly known nor easily determined as new standards are enacted and new interpretations of existing standards are rendered. Environmental laws and regulations are expected to have an increasing impact on our operations. In addition, any non-compliance with such laws could subject us to material administrative, civil or criminal penalties, or other liabilities. Potential permitting costs are variable and directly associated with the type of facility and its geographic location.

Item 1a. Risk Factors.

As a smaller reporting Company the company is not required to report on Risk Factors in its Annual Report to Shareholders.

Item 1b. Un-Resolved Staff Comments.

The Company has no disclosures responsive to this item 1b.

Item 2. Properties.

The Company has oil and gas leases in Milam County, Texas on which it is producing crude oil. As of this report date the Company has 11 wells on its properties in Milam County (including 6 operating wells in Balch Lease that began producing crude oil in December 2013). The Company has 3 wells on its McGregor Lease that it plans to refurbish and bring into production before 2015. The Company’s leases cover 338 well acres.

On December 18, 2013, the Company's oil and gas leases in Upshur County, Texas expired and it does not intend to pursue renewing those leases. However, the Company does intend to pursue leases contiguous to its currently held leases in Milam County. In that regard, the Company has taken a one-time write down of its unproved properties in the amount of $1,238,887 for the year ended December 31, 2013.

In its newly issued Petroleum Engineer's Report dated December 31, 2014 the Company is reporting; Probable Undeveloped and Non-producing reserves of approximately 803,937 stock tank barrels, Possible Undeveloped Non-Producing reserves of approximately 996,492 stock tank barrels. The Company has no proved reserves as of December 31, 2014.

Item 3. Legal Proceedings.

The Company is not a party to nor is it aware of any significant legal proceeding that would negatively affect its operation or financial condition.

Item 4. Mine Safety Disclosures

The Company has no disclosures responsive to this item 4.

PART II

Item 5. Market for Registrant's Common Equity, Related Stockholder Matters

Market Information

The Company's registration statement of its common stock for sale became effective on March 29, 2013. The Company is not employing an underwriter to assist it in the sale of the common shares. The shares are being sold by and through the Company's CEO, Kevin Jones.

During the year ended December 31, 2014, the Company has sold and issued common stock to private parties totaling 287,800 common shares of registered stock for a total of $575,600. All of the sales were made on the efforts of the Company's CEO, Kevin Jones, with private parties. There is no ready public trading market for the Company's common shares. Even though the shares sold are not restricted and are “free trading shares”, the Company has not listed its shares for sale on any stock exchange as of the date of this report. So, there is no method of trading electronically for the shares. However, the Company intends to seek a market maker and file the necessary documents to meet the necessary requirements to obtain a listing and develop a public market for its common stock as well as make arrangements for electronic trading of the shares. Until that time no public market for trading the Company's stock exists.

Holders

As of April 15, 2015, there were approximately 208 shareholders of record of our common stock.

Dividends

No dividends were paid during the years ended December 31, 2014 and 2013. The payment of future cash dividends will depend upon, among other things, our financial condition, funds from operations, the level of our capital and development expenditures, our future business prospects, contractual restrictions and any other factors considered relevant.

Recent sales of unregistered securities

During the year ended December 31, 2013, the Company sold 1,500 shares to an individual for $1,500 cash.

Item 6. Selected Financial Data.

As a Smaller Reporting Company the Company is not required to make disclosures related to this item 6.

Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Overview

North Texas Energy, Inc. is in its exploration stage. The results of operations show how capital intensive and profitless the oil and gas production business is at start up. The progress so far has been limited by severely limited access to working capital. One of the most important economic factors in the U.S economy is the successful exploration and production of crude oil and natural gas. North Texas Energy, Inc. is committing its business and resources to the production of crude oil and natural gas that remains in geological formations in oil fields that have been previously explored and have produced significant amounts of crude oil already. Data and research produced by the Department of Energy indicates that additional significant reserves of crude oil and natural gas remain in fields that were once productive in the past. In recent years and with the price of crude oil steady at about seventy-four dollars per barrel (since 2008), new production methods have emerged as cost-effective in recovering the substantial remaining oil that has not been recovered using standard methods. North Texas Energy, Inc. entered into the business of recovering oil in previously drilled and producing fields in 2009 by acquiring oil and natural gas leases in north Texas. The Company’s predecessor operated in year 2010 for a short period of time. During that time, the Company had access to private capital from sales of common stock to shareholders. The capital from investment by private shareholders was limited and sales were terminated late in 2010. The funds invested at that time were used mainly to begin the process of refurbishing wells and preparing well head installations for re-use. The short operations history shows that without on-going sources of working capital, the initial cost of getting wells and drill bores functional to begin the process of recovering oil that remains in the geological formation will not be met and significant delays in recovering the remaining oil would occur.

Results of Operations

For the years ended December 31, 2014, the Company had a net loss of $327,393 compared to a net loss of $1,567,380 for the year ended December 31, 2013. The significant portion of the loss in 2013 comes from the impairment expense taken as a result of the Company's lease expirations on its unproved oil and gas properties. This loss was represented by a non-cash one time charge to record the loss of the properties by virtue of the lease expiration and totaled $1,238,887.

Revenues

For the year ended December 31, 2014, and 2013, the Company had revenues of $70,615 and $0, respectively, from the sales of crude oil. The Company started to produce crude oil from December 2013 and had its first sale in January 2014.

Operating expenses

For the year ended December 31, 2014, the Company had an operating expenses of $398,008 compared to $1,566,694 for the year ended December 31, 2013. The Company recorded a non-cash one time impairment of oil and gas properties of $1,238,887 during the year ended December 31, 2013 as discussed above. For the years ended December 31, 2014 and 2013, the Company has lease operating expense of $96,856 and $0, respectively. The increase of lease operating expense is mainly because the Company started to produce in December 2013.

Liquidity

The Company began selling its common shares in accordance with its registration statement which became effective on March 29, 2013. On March 29, 2014, the Company filed an amendment of its Prospectus that relates to the common stock sales extending the time past the original one year sales period. The Company will continue to sell shares as allowed and use those funds for the further development of its oil and gas properties. The Company believes that it can continue to sell its common stock and use those funds as well as the funds it generates from crude oil production to continue its operations.

The Company has no immediate sources of debt or equity funding that is not related to the offering of its shares. The Company believes it can avoid accumulating debt or using other non-traditional forms of financing to provide liquidity.

At December 31, 2014, our cash and cash equivalents balance was $92,426.

Net cash used in operating activities was $282,903 for the year ended December 31, 2014, compared to $298,119 for the year ended December 31, 2013.

Net cash used in investing activities was $291,195 for the year ended December 31, 2014, compared to $364,338 for the year ended December 31, 2013. The Company made less payment to purchase oil and gas properties in 2014.

Net cash provided by financing activities for the year ended December 31, 2014 was $615,600 compared to $713,381 for the year ended December 31, 2013. During the year ended December 31, 2014 and 2013, the Company received proceeds from sale of common stock of $615,600 and $695,030, respectively.

Without additional investment capital from shareholders or other sources, the Company has no short term source of liquidity. In order to bring wells on-line and produce crude oil to bring to market, significant amounts of working capital will be needed to continue. Accordingly, the Company plans to systematically bring wells on-line that have the greatest initial production possibility as capital is available. The Company’s illiquid financial position could cause it to not be able to start producing oil in the near future unless working capital from the offering or some other source of short term liquidity is developed.

Management does not believe that the Company’s current capital resources will be sufficient to fund its operating activity and other capital resource demands during the next year. Our ability to continue as a going concern is contingent upon our ability to obtain capital through the sale of equity or issuance of debt, and ultimately attaining profitable operations. There is no assurance that we will be able to successfully complete any one of these activities.

Trends

The Company began producing crude oil in small quantities in December 2013 and had crude oil in its storage tanks at December 31, 2013 with an approximately sales value of $11,780 (valued at $98.17 per barrel). That value is based on the daily price of West Texas Intermediate Crude Oil on December 31, 2013. Subsequent to December 31, 2013, the Company has sold that oil and is now producing more in small quantities from its producing wells on the Balch Lease. During 2014 the Company recovered and sold an additional 1,062 barrels of oil from its Balch Lease.

In 2015 the Company plans to complete the necessary technology treatments (MEOR) and refurbishments to a total of 25 installed wells. Those would include: 11 total wells on its Balch Lease, 3 wells on its McGregor Lease, 6 wells on its Cromwell Lease and 5 wells on its Hicks lease.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements or guarantees of third party obligations at December 31, 2014.

Critical Accounting Policies

The following describes the critical accounting policies used in reporting our financial condition and results of operations. In some cases, accounting standards allow more than one alternative accounting method for reporting. Such is the case with accounting for oil and gas activities described below. In those cases, our reported results of operations would be different should we employ an alternative accounting method.

Oil and Gas Properties

The Company uses the full cost method of accounting for exploration and development activities as defined by the SEC. Under this method of accounting, the costs for unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. Capitalized costs include lease acquisition, geological and geophysical work, delay rentals, costs of drilling, completing and equipping the wells and any internal costs that are directly related to acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or other disposition of oil and gas properties are generally treated as a reduction in the capitalized costs of oil and gas properties, unless the impact of such a reduction would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.

The Company categorizes its full cost pools as costs subject to amortization and costs not being amortized. The sum of net capitalized costs subject to amortization, including estimated future development and abandonment costs, are amortized using the unit-of-production method.

Oil and gas properties include costs that are excluded from capitalized costs being amortized. These amounts represent costs of investments in unproved properties. The Company excludes these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. All costs excluded are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the costs subject to amortization.

Recent Accounting Pronouncements

In August 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-15, Presentation of Financial Statements – Going Concern. The Update provides U.S. GAAP guidance on management’s responsibility in evaluating whether there is substantial doubt about a company’s ability to continue as a going concern and about related footnote disclosures. For each reporting period, management will be required to evaluate whether there are conditions or events that raise substantial doubt about a company’s ability to continue as a going concern within one year from the date the financial statements are issued. The amendments in this Update

are effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. The Company is currently evaluating the effects of ASU 2014-15 on the consolidated financial statements.

The Company does not believe that any other recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the accompanying financial statements.

Item 8. Financial Statements and Supplementary Data.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

North Texas Energy, Inc.

Addison, Texas

We have audited the accompanying consolidated balance sheets of North Texas Energy, Inc. as of December 31, 2014 and 2013, and the related consolidated statements of operations, shareholders’ equity and cash flows for each of the years then ended. North Texas Energy, Inc.’s management is responsible for these financial statements. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our 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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of North Texas Energy, Inc. as of December 31, 2014 and 2013, and the results of its operations and its cash flows for the periods described above in conformity with accounting principles generally accepted in the United States of America.

The accompanying consolidated financial statements have been prepared assuming that North Texas Energy, Inc. will continue as a going concern. As discussed in Note 3 to the consolidated financial statements, North Texas Energy, Inc. has suffered losses from operations and has not secured sufficient funding for its operations. These factors raise substantial doubt about its ability to continue as a going concern. Management’s plans in regard to these matters are also described in Note 3. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/s/ GBH CPAs, PC

GBH CPAs, PC

www.gbhcpas.com

Houston, Texas

April 15, 2015

NORTH TEXAS ENERGY, INC.
CONSOLIDATED BALANCE SHEETS


	December 31,			December 31,
	2014			2013
Assets
Current assets
Cash	$	92,426		$	50,924
Inventory		-			1,013
Accounts receivable		5,369			-
Total current assets		97,795			51,937
Oil and gas properties, full cost method
Costs subject to amortization		-			1,147,903
Costs not being amortized		1,398,782			-
Accumulated depletion, depreciation and amortization		(2,934	)		(313)
Total oil and gas properties, full cost method		1,395,848			1,147,590

Total assets	$	1,493,643		$	1,199,527


Liabilities and shareholders' equity
Current liabilities
Accounts payable and accrued liabilities	$	110,521		$	123,050
Common stock payable		40,000			-
Accrued lease liabilities		65,881			65,881
Total current liabilities		216,402			188,931

Asset retirement obligations		44,282			25,844

Total liabilities		260,684			214,775

Commitments and contingencies

Shareholders' equity
Common stock, $0.00001 par value, 100,000,000 shares authorized, 6,467,065 and 6,179,265 shares issued, respectively		65			62
Additional paid-in capital		2,986,107			2,410,510
Accumulated deficit		(1,753,213	)		(1,425,820)
Total shareholders' equity		1,232,959			984,752

Total liabilities and shareholders' equity	$	1,493,643		$	1,199,527

See notes to the consolidated financial statements.

NORTH TEXAS ENERGY, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

	For the Year Ended
	December 31,
	2014			2013

Revenues	$	70,615		$	-

Operating expenses:
Lease operating expense		96,856			-
Depletion and accretion		5,443			12,381
Impairment of oil and gas properties		-			1,238,887
Legal and professional fees		88,916			145,204
General and administrative expenses		206,793			170,222
Total operating expenses		398,008			1,566,694

Net operating loss		(327,393	)		(1,566,694	)

Interest expense		-			(686)

Net loss	$	(327,393	)	$	(1,567,380	)

Basic and diluted loss per common share	$	(0.05	)	$	(0.26	)

Weighted average number of common shares outstanding - basic and diluted		6,328,533			5,976,117

See notes to the consolidated financial statements.

NORTH TEXAS ENERGY, INC.
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY


	Common Stock				Additional Paid-In		Accumulated			Total Shareholders'
	Shares		Amount		Capital		Deficit			Equity

Balance, December 31, 2012		5,831,000	$	58	$	1,697,133	$	141,560		$	1,838,751

Capital contribution		-		-		18,351		-			18,351

Issuance of common stock for cash		348,265		4		695,026		-			695,030

Net loss		-		-		-		(1,567,380	)		(1,567,380	)

Balance, December 31, 2013		6,179,265	$	62	$	2,410,510	$	(1,425,820	)	$	984,752

Issuance of common stock for cash		287,800		3		575,597		-			575,600

Net loss		-		-		-		(327,393	)		(327,393	)

Balance, December 31, 2014		6,467,065	$	65	$	2,986,107	$	(1,753,213	)	$	1,232,959

See notes to the consolidated financial statements.

NORTH TEXAS ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Year Ended
	December 31,
	2014			2013

Cash Flows From Operating Activities:
Net loss	$	(327,393	)	$	(1,567,380	)
Adjustments to reconcile net loss to net cash from operating activities:
Depletion, accretion and impairment expense		5,443			1,251,581
Changes in operating assets and liabilities:
Accounts receivable		(5,369	)		-
Inventory		1,013			(1,013	)
Accounts payable and accrued liabilities		43,403			18,693
Net Cash Used in Operating Activities		(282,903	)		(298,119	)

Cash Flows From Investing Activities:
Payments for proved oil and gas properties		(291,195	)		(364,338	)
Net Cash Used in Investing Activities		(291,195	)		(364,338	)

Cash Flows From Financing Activities:
Capital contributions		-			18,351
Proceeds from sale of common stock		615,600			695,030
Net Cash Provided by Financing Activities		615,600			713,381

Net increase in cash		41,502			50,924
Cash at beginning of year		50,924			-
Cash at end of year	$	92,426		$	50,924

Supplemental Cash Flow Information
Cash paid for interest	$	-		$	686
Cash paid for income taxes	$	-		$	-
Noncash investing activities:
Asset retirement cost	$	15,616		$	2,509
Payable for purchase of oil and gas properties	$	55,932		$	76,041

See notes to the consolidated financial statements.

NORTH TEXAS ENERGY, INC.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

Note 1 - Business and Organization

North Texas Energy, Inc. (“the Company”) was incorporated in the State of Nevada on January 12, 2011. The Company intends to focus on re-entering non-producing oil fields and re-starting production with existing wells. On February 25, 2011, the Company entered into a Purchase and Sale Agreement with Remington Oil & Gas, Inc. (“Remington”) to acquire Remington’s interest in an oil and gas lease in Upshur and Milam County, Texas along with wellhead equipment and certain lease obligations.

Note 2 - Summary of Significant Accounting Policies

Basis of Presentation

These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) and include the accounts of the Company and those of its wholly owned subsidiary. All significant intercompany accounts and transactions have been eliminated.

Cash and Cash Equivalents

Cash equivalents are highly liquid investments with an original maturity of three months or less.

Accounts Receivable

Accounts receivable are stated at the historical carrying amount net of write-offs and allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximates fair value because of the short-term nature of the instruments.

The Company's reported balance of accounts receivable, net of allowance for doubtful accounts, represents management's estimate of the amount that ultimately will be realized in cash. The Company reviews the adequacy of the allowance for doubtful accounts on an ongoing basis, using historical payment trends, the age of the receivables and knowledge of the individual customers or joint interest owners. When the analysis indicates, management increases or decreases the allowance accordingly. However, if the financial condition of our customers were to deteriorate, additional allowances might be required.

Inventory

From time to time, crude oil production volumes may be stored as inventory and sold at a later time. Inventory is carried at the lower of production cost or market value. The first-in, first-out method is used for the crude oil inventory. As of December 31, 2013, inventory consisted of crude oil. There was no inventory as of December 31, 2014.

Oil and Gas Properties

The Company uses the full cost method of accounting for exploration and development activities as defined by the U.S. Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs for unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. Capitalized costs include lease acquisition, geological and geophysical work, delay rentals, costs of drilling, completing and equipping the wells and any internal costs that are directly related to acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or other disposition of oil and gas properties are generally treated as a reduction in the capitalized costs of oil and gas properties, unless the impact of such a reduction would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.

Oil and gas properties include costs that are excluded from capitalized costs being amortized. These amounts represent costs of investments in unproved properties. The Company excludes these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. All costs excluded are reviewed annually to determine if impairment has occurred. The amount of any impairment is transferred to the costs subject to amortization.

Ceiling Test and Impairment

Under the full cost method of accounting, a ceiling test is performed each quarter for proved properties. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X. The ceiling test determines a limit, on a country-by-country basis, on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization and impairment(“DD&A”) and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) with consideration of price change only to the extent provided by contractual arrangement, discounted at 10%, net of related tax effects. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated DD&A. The Company has no proved properties subject to the full cost ceiling test as of December 31, 2014.

Asset Retirement Obligations

Asset retirement obligations (“ARO”) represent the future abandonment costs of tangible assets such as platforms, wells, service assets, pipelines, and other facilities. The fair value of a liability for an asset's retirement obligation is recorded in the period in which it is incurred if a reasonable estimate of fair value can be made, and that the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, an adjustment is made to the full cost pool, with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. The ARO assets, which are carried on the balance sheet as part of the full cost pool, will be included in our amortization base for the purposes of calculating depreciation, depletion and amortization expense. For the purposes of calculating the ceiling test, the future cash outflows associated with settling the ARO liability is included in the computation of the discounted present value of estimated future net revenues.

Revenue Recognition

The Company recognizes sales revenues for crude oil based on the amount sold to purchasers when delivery to the purchaser has occurred and title has transferred. This occurs when a tanker lifting has occurred.

Income Taxes

Deferred income taxes are provided on a liability method whereby deferred tax assets and liabilities are established for the difference between the financial reporting and income tax basis of assets and liabilities as well as operating loss and tax credit carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.

Realization of deferred tax assets is dependent upon sufficient future taxable income during the period that deductible temporary differences and carry-forwards are expected to be available to reduce taxable income. At December 31, 2014 and 2013, the Company has recorded a 100% valuation allowance as management believes it is likely that no deferred tax assets will be realized.

At December 31, 2014, the Company had net operating loss carry forwards of approximately $800,000 that will expire between 2031 through 2034.

Net Income (Loss) Per Share

Basic net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted-average number of common and common equivalent shares outstanding during the period. Common share equivalents included in the diluted computation represent shares issuable upon assumed exercise of stock options and warrants using the treasury stock and “if converted” method. For periods in which net losses are incurred, weighted average shares outstanding is the same for basic and diluted loss per share calculations, as the inclusion of common share equivalents would have an anti-dilutive effect. As of December 31, 2014 and 2013, there were no potentially dilutive shares.

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at year-end and the reported amounts of revenues and expenses during the year and the reported amount of proved natural gas and oil reserves. Management bases its estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments that are not readily apparent from other sources. Actual results could differ from these estimates and changes in these estimates are recorded when known.

Subsequent Events

The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration.

Recently Issued Accounting Pronouncements

Note 3 - Going Concern

As shown in the accompanying financial statements, the Company has incurred losses from operations, has not generated significant revenue and has not secured continuous funding for the operation of its oil and gas producing activities. These factors raise substantial doubt about the Company’s ability to continue as a going concern. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern. In addition to the offering of securities for sale to the public, the Company currently is diligently searching for other short-term and long-term sources of liquidity for its producing operations.

Note 4 – Oil and Gas Properties, Full Cost Method

The Company’s oil and gas properties at December 31, 2014 and 2013 are located in the State of Texas in the United States and are all in Milam County.

During 2014, the Company transferred $1,395,848 from costs subject to amortization to unproved properties as the wells were only producing insignificant volumes of crude oil. During 2013, the Company had transferred $1,147,903 of oil and gas properties to costs subject to amortization from unproved properties.

During the year ended December 31, 2014, the Company added two additional oil and gas leases known as the “Hicks” and “Cormwell” leases. The added leases contain a total of five wells of which two are on the Hicks lease and there are on the Cormwell lease. The wells on the Hicks and Cormwell leases were in operation during 2014. The Company paid $6,133 and $8,720, respectively, as cash consideration for the acquisition of the leases.

On October 10, 2014, the Company also entered into a lease agreement to lease an additional 221 acres in Milam County (“Wadlington” lease). The Company paid $11,083 for the Wadlington lease and is still in the process of obtaining the drilling permit.

For the year ended December 31, 2014, the Company invested $235,263 in the development of its oil and gas infrastructure and wells and the acquisition of new lease properties. For the year ended December 31, 2013, the Company invested $440,379 in the development of its oil and gas infrastructure and wells. In the month of December 2013, the Company produced approximately 120 barrels of oil from the refurbished wells on the Balch Lease which is included in inventory at December 31, 2013.

On December 18, 2013, the Company's oil and gas leases on its Upshur County Texas properties expired. The Company recorded an impairment expense of $1,238,887 related to the expired leases.

Note 5 – Accrued Lease Liabilities

The Company has an accrued lease liability to KADs Oil, Inc., the lessor of the Company’s leases in both Upshur and Milam County, Texas. As a result of the Purchase and Sale Agreement with Remington, the Company assumed the leasehold obligation of $50,000. Payments are to be made when oil and gas is recovered and delivered to market at the rate of 25% of the sale price after all operating expenses. No payment has been made as of December 31, 2014.

On May 10, 2011, the Company entered into an oil, gas and mineral lease agreement for its oil and gas properties located in Milam County, Texas. Pursuant to the lease agreement, the Company will pay the lessor $15,881 for the lease which is recorded as an accrued leasehold liability on the Company’s balance sheets at December 31, 2014 and 2013.

Note 6 – Asset Retirement Obligation

The following table provides a reconciliation of the changes in the estimated present value of asset retirement obligations.

	December 31, 2014			December 31, 2013


Beginning asset retirement obligation	$	25,844		$	54,709
Change of estimate		(2,645	)		(2,509	)
Addition		18,260			-
Disposal of leases		-			(38,737	)
Accretion expense		2,823			12,381
Ending asset retirement obligation	$	44,282		$	25,844

Note 7 – Equity

During the year ended December 31, 2014, the Company issued 287,800 common shares for $575,600 cash. The Company also received $40,000 cash for sale of 20,000 common shares which have not been issued. During the year ended December 31, 2013, the Company issued 348,265 common shares for $695,030 cash.

Note 8 – Related Party Transactions

During the years ended December 31, 2014 and 2013, the Company’s Chief Executive Officer, Mr. Kevin Jones, contributed $0 and $18,351, respectively, to the Company.

Note 9 – Subsequent Events

Subsequent to December 31, 2014, the Company issued 52,750 common shares for $105,500 cash.

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

Not applicable.

Item 9A. Controls and Procedures

Disclosure Controls and Procedures

Under the supervision and with the participation of our management, including our principal executive and principal financial officers, we conducted an evaluation as of December 31, 2014 of the effectiveness of the design and operation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended. Based on this evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were not effective as of December 31, 2014.

Management’s Annual Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. Under the supervision and with the participation of management, including our principal executive and principal financial officers, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the “2013 COSO Framework”). Based on this evaluation under the COSO Framework, management concluded that our internal control over financial reporting was not effective as of December 31, 2014. Such conclusion reflects the lack of accounting experience of our now principal financial officer and a lack of segregation of duties. Until we are able to remedy these material weaknesses, we are relying on third party consultants to assist with financial reporting.

This annual report does not include an attestation report of our registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by our registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit smaller reporting companies to provide only management’s report in this annual report.

Changes in Internal Control Over Financial Reporting

There was no change in our internal control over financial reporting during the fourth quarter of 2014 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART III

Item 10. Directors, Executive Officers and Corporate Governance.

Executive Officers

Our executive officers as of December 31, 2014, and their ages and positions as of that date, are as follows:

Name	Age		Position
Kevin Jones		52	Chairman, Chief Executive Officer and Director
Sanah Marah		36	Chief Financial Officer

Kevin Jones

Mr. Jones is the founder of North Texas Energy, Inc. and holds BS, MS degrees, and PhD (ABD) in Physics. For nearly two years, early 1997 through late 1999, Mr. Jones served as a risk project manager for SRS Technologies. In late 1999, Mr. Jones joined General Dynamics where he served as a project manager and later a program manager for various defense related programs until late 2009. In late 2009, Mr. Jones joined ManTech International where he served as a program manager until he began serving full time as the CEO of North Texas Energy, Inc. in March 2012. Mr. Jones began serving as the director of North Texas Energy, Inc. in January 2011. None of Mr. Jones’ previous employers have any connection with North Texas Energy, Inc. He served as the initial Secretary for the Board of Directors of Remington Oil & Gas, Inc. for two months, January and February of 2010.

For the past 15 years, Mr. Jones has worked in program management and project management capacities. He managed $3 million to $50 million programs from inception to completion. Mr. Jones has managed programs and projects for the Missile Defense Agency, the Department of Defense (Army, Navy, and Marines), and the Department of Homeland Security. As a program manager, he was responsible for the executive management of a program (and it associated projects) and ensured the program ran effectively and efficiently. He managed the development and implementation of the programmatic scope, management plans, management schedules, life cycle and logistics cost analyses, cost trade-off analysis, and programmatic risk management assessments.

Mr. Jones has simultaneously managed disparate programs whereby different management techniques were brought to bear in totally different ways to obtain the desired results. He has built and led successful professional operations and he has turned dysfunctional operations into efficient cost productive programs.

Sanah Marah

Mr. Sanah Marah Jr. has been a Finance and Accounting Professional for the last 13 years. He attended the prestigious University of London and holds a Business and Finance degree and also attended LeTourneau University and graduated with a B.A. Accounting. He is a practicing Chartered Management Accountant, or C.M.A.

For the past 5 years, he served in two professional roles in which he managed budgets and projects ranging from $100 million to $800 million. In 2009, Mr. Marah joined the Accounting Team at Greyhound Lines Inc.’s (First Group America FGA Parent Company) corporate office in Dallas, Texas where his main focus was Inventory Management for all the U.S. and Canadian Operations and currently holds the position of Senior Accountant. He effectively managed all aspects of U.S. and Canadian Operations area including, Fuel, Oil, Tires, Engine and Cores. Components of these included Bus Refurbishment Project costing close to $200 million including budget and cash flow projections and spending. Before joining Greyhound Lines Inc., Mr. Marah pursued his private practice and he consulted with several companies including, Ascent Capital Group and J.F. Entertainment. As a Finance Consultant, he performed all finance and accounting roles from payables, receivables, cash management, budgeting & forecasting, inventory management, merger and acquisitions, fixed assets management and payroll.

Prior to private practice, Mr. Marah worked at Dean Foods Company, the largest Dairy Producer and Manufacturer in the U.S. In his tenure between 2003 and 2007, he focused on the inter-company reconciliations and eliminations for 45 entities. As a Senior Accountant, he introduced a cashless inter-company confirmation process between sister companies. During the same period, he performed Sarbanes-Oxley (SOX) implementation and testing to ensure proper internal controls. His last project before leaving was to ensure proper data integration and chart of accounts conversion to a new platform while constantly managing the Internal Financial Reporting for four divisions and the reconciliation of the financials between the General Ledger and Hyperion.

Earlier in his career, Mr. Marah was an International Accounting Analyst for Blockbuster's Corporate Office in Dallas Texas. In that capacity, he was responsible for the consolidations and eliminations of all the international operations in Europe, Latin America and Asia. He ensured minimal currency exposure and liabilities with the use of his hedging techniques. In addition, he created commentary on profit and loss fluctuations for each global region and reconciled statements from foreign GAAP to U.S. GAAP.

Mr. Marah began providing professional services to the Company on a part-time basis in January 2011.

No Officer or Director has been or is subject to any legal proceeding as identified in Regulation S-K Item 401(f)

Item 11. Executive Compensation.

The following table sets forth information concerning the total compensation paid or accrued by us during the fiscal years ended December 31, 2014 and 2013 to all individuals that served as our principal executive and principal financial officers or acted in a similar capacity for us at any time during the fiscal years ended December 31, 2014 and 2013.

SUMMARY COMPENSATION TABLE

Name and Principal Position	Year	Salary($)	Bonus($)	Stock Award($)	Option Award($)	Non-Equity Incentive Plan($)	All Other Compensation ($)
Kevin Jones, CEO	2014 2013	43,348 -	- -	- -	- -	- -	- -
Sanah Marah, CFO	2014 2013	1,000 -	- -	- -	- -	- -	- -

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

The following table sets forth information with respect to the beneficial ownership of our common stock known by us as of April 15, 2015 by:

• each person or entity known by us to be the beneficial owner of more than 5% of our common stock;

• each of our directors and executive officers; and

• all of our directors and executive officers as a group.

Class of Stock	Name & Address of Owner		Number of Shares				Portion of Class (%)
Common	Kevin Jones, CEO and Director 5057 Keller Springs Road, Suite 300 Addison, Texas 75001			5,000,000				76.07	%

Item 13. Certain Relationships and Related Transactions, and Director Independence.

During the years ended December 31, 2014 and 2013, the Company’s Chief Executive Officer, Mr. Kevin Jones, contributed $0 and $18,351, respectively, to the Company.

Item 14. Principal Accounting Fees and Services.

The following table sets forth the fees billed by our principal independent accountants for each of our last two fiscal years for the categories of services indicated.

	2014		2013

Audit Fees	$	46,165	$	21,000
Audit Related Fees		-		-
Tax Fees		-		-
All Other Fees		-		-

Audit fees: Consists of fees billed for the audit of our annual financial statements and review of our interim financial information and services that are normally provided by the accountant in connection with year-end and quarter-end statutory and regulatory filings or engagements.

Audit-related fees: Consists of fees billed for services relating to review of other regulatory filings including registration statements, periodic reports and audit related consulting.

Tax fees: Consists of professional services rendered by our principal accountant for tax compliance, tax advice and tax planning.

Other fees: Other services provided by our accountants.

EXHIBIT INDEX

EXHIBIT NUMBER	DESCRIPTION OF EXHIBIT

2.2	Purchase and Sales Agreement (Previously filed 2/23/2012)

3.1	Articles of Incorporation of North Texas Energy, Inc. (Previously filed 12/30/2011)

3.2	By-Laws of North Texas Energy, Inc. (Previously filed 12/30/2011)

31.1	Certification of Principal Executive Officer, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2	Certification of Principal Financial and Accounting Officer, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

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

32.2	Certification of Principal Financial and Accounting Officer, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

99.1	Reserve Report

99.2	M W Balch Lease and New Diana Field 3-year EUR (Previously filed 5/16/2012)

101 INS	XBRL Instance Document*

101 SCH	XBRL Schema Document*

101 CAL	XBRL Calculation Linkbase Document*

101 DEF	XBRL Definition Linkbase Document*

101 LAB	XBRL Labels Linkbase Document*

101 PRE	XBRL Presentation Linkbase Document*

* The XBRL related information in Exhibit 101 shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to liability of that section and shall not be incorporated by reference into any filing or other document pursuant to the Securities Act of 1933, as amended, except as shall be expressly set forth by specific reference in such filing or document.

SIGNATURES

Pursuant to the requirements of the Securities Act of 1933, the registrant has duly caused this annual report to be signed on its behalf by the undersigned, thereunto duly authorized in the City of Dallas, State of Texas, on April 16, 2015.

Dated: April 16, 2015	North Texas Energy, Inc.

	By: /s/ Kevin Jones
	Kevin Jones
	Chief Executive Officer and Director

NORTH TEXAS ENERGY, INC.

Pursuant to the requirements of the Securities Act of 1933, as amended, this Registration Statement has been signed by the following persons in the capacities indicated on April 16, 2015.

Signature	Title	Date

/s/ Kevin Jones	Chief Executive Officer and Director	April 16, 2015
Kevin Jones	(Principal Executive Officer)



/s/ Sanah Marah	Chief Financial Officer	April 16, 2015
Sanah Marah	(Principal Financial and Accounting Officer)

EX-31.1 2 northtexasexh311.htm CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER, PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002. northtexasexh311.htm

Exhibit 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER PURSUANT TO 18U.S.C SECTION 1350 AS ADOPTED

PURSUANT TO SECTION 302 OF THE SARBANES-OXELY ACT OF 2002

I, Kevin Jones, certify that:

1. I have reviewed this report on Form 10-K of North Texas Energy, Inc. for the fiscal year ended December 31, 2014.

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

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

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

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

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

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

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

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

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

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

/s/ Kevin Jones

Kevin Jones

President and Chief Executive Officer

(Principal Executive Officer)

Date: April 16, 2015

EX-31.2 3 northtexasexh312.htm CERTIFICATION OF PRINCIPAL FINANCIAL AND ACCOUNTING OFFICER, PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002. northtexasexh312.htm

Exhibit 31.2

CERTIFICATION OF PRINCIPAL FINANCIAL AND ACCOUNTING OFFICER

PURSUANT TO 18 U.S.C SECTION 1350 AS ADOPTED

PURSUANT TO SECTION 302 OF THE SARBANES-OXELY ACT OF 2002

I, Sanah Marah, certify that:

1. I have reviewed this report on Form 10-K of North Texas Energy, Inc. for the fiscal year ended December 31, 2014.

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

/s/ Sanah Marah

Sanah Marah

Chief Financial Officer

(Principal Financial and Accounting Officer)

Date: April 16, 2015

EX-32.1 4 northtexasexh321.htm CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER, PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002. northtexasexh321.htm

Exhibit 32.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER, PURSUANT TO

18 U.S.C. SECTION 1350,AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report of North Texas Energy, Inc. a Texas corporation (the “Company”), on Form 10-K for the period ended December 31, 2014 as filed with the Securities and Exchange Commission (the “Report”), I, Kevin Jones, President and Chief Executive Officer of the Company, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350), that to my knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Kevin Jones

Kevin Jones

President and Chief Executive Officer

(Principal Executive Officer)

Date: April 16, 2015

EX-32.2 5 northtexasexh322.htm CERTIFICATION OF PRINCIPAL FINANCIAL AND ACCOUNTING OFFICER, PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002. northtexasexh322.htm

Exhibit 32.2

CERTIFICATION OF PRINCIPAL FINANCIAL AND ACCOUNTING OFFICER, PURSUANT TO

18 U.S.C. SECTION 1350,AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report of North Texas Energy, Inc. a Delaware corporation (the “Company”), on Form 10-K for the period ended December 31, 2014 as filed with the Securities and Exchange Commission (the “Report”), I, Sanah Marah, Chief Financial Officer of the Company, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350), that to my knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Sanah Marah

Sanah March

Chief Financial Officer

(Principal Financial and Accounting Officer)

April 16, 2015

EX-99.1 6 northtexasexh991.htm RESERVE REPORT northtexasexh991.htm

Exhibit 99.1

John M. Durkee, PE 4915 South Newport Avenue Tulsa, Okla. 74105-4619

voice 918-381-9292 fax 918-742-0624

North Texas Energy Corporation

Milam County Lease Group

Reserve Analysis for

December 31, 2014

Prepared

John M. Durkee, PE

December 31, 2014

Mr. Kevin Jones, CEO/Director

North Texas Energy, Inc.

5057 Keller Springs Road, Suite 300

Addison, Texas 75001

Re: Reserve Analysis, Milam County Lease Group, 223.37 acres +/-, All Located in the Jose Leal Six League Grant Survey, Milam County, Texas

Dear Mr. Jones:

At your request, I have examined the data contained in North Texas Energy’s well record files, reserve reports prepared previously by me and others, public records, the Railroad Commission’s database, the NRIS database, and my private files. This report will supersede all previous plans, projections, reserve reports, responses or communications relating to this matter.

I certify that I am a Consulting Petroleum Engineer, registered with the State of Oklahoma, State Board of Registration for Professional Engineers and Land Surveyors, Number 14481 and that I hold no equity position in the Company.

Purpose

The purpose of this report is to state that North Texas Energy had no ‘Proved’ reserves. The effective date of this report is December 31, 2014

The Company

North Texas Energy, Inc. is an ‘Enhanced Oil Recovery’ company whose primary function is to increase the ultimate recovery of oil and gas from the wells it presently owns or will drill or acquire in the future in order to maximize value to it’s stockholders.

At this time the registrant has no ‘Proved’ reserves. The probable reserves projected are all located in the state of Texas. North Texas Energy owns 100% working interest in 223.37 acres with fourteen unproductive oil wells, zero productive oil wells and zero productive gas wells. The reserves disclosed in this engineering report are a restatement of the reserves disclosed in the 2013 10K and a disclosure of the additional reserves acquired during the 2014 calendar year. All (100%) of the registrant's reserves are covered by this report and all are located in the state of Texas.

NTE uses methods endorsed by the DOE that unlock oil that was previously unmovable. These techniques are proprietary and for the most part are low impact upon the surface of the land. NTE’s locations utilize a small footprint of a few hundred square feet rather that the several acres typically lost to use by the surface owner.

Strategy

The company will use proprietary tools, technologies and the experience of the management team and consultants to find and extract oil from reservoirs, to differentiate between projects suitable for the application of proven techniques and to monitor new exploration and recovery technology for successful proof of concept.

Tactics

The company will acquire existing production projects, productive and non-productive leases and will enter into joint ventures with other operators that add necessary project acreage or improve the likelihood of a projects’ success.

Sources of Data and Assumptions

Information and data for the analysis of this acreage are from electric logs, drillers’ logs, completion and production reports obtained from the Texas Railroad Commission (RRC), IHS Energy Corporation, Dwight’s database, The Texas Well Log Libraries, the NRIS database, published reports, public well records of ongoing operations in the area and my private files.

This data was probabilistically used to evaluate the Minerva-Rockdale reservoir formation and field production history to estimate the level of potentially moveable oil and the likelihood of recovering any of that oil. There are no ‘Proved’ reserves identified by this report.

Maps of structure and zone thickness have been revised based upon the logs run at the time of the Mechanical Integrity Test. Sand thickness originally thought to be a net fifteen feet of oil sand has proved to be as much as sixty feet. Production from this interval has little water even though the additional sand thickness is deeper and lower structurally than most of the wells that are now producing, indicating the relative lack of an oil water contact in the Minerva sand in the immediate area.

Volumetrics were computed by standard formulae and have been adjusted for criteria discussed with engineers of the US Securities and Exchange Commission. North Texas Energy’s stated purpose is to be an enhanced recovery oil producer. It’s focus is on recovering the oil other companies gave up on decades ago because it was too difficult or impossible to produce with technology existing at the time.

The Microbial Enhanced Oil Recovery technique is now in use on this group of leases. In a report conducted by the DOE and the Venezuelan Ministry of Energy and Mines, concluded that, “MEOR has two distinct advantages: 1) microbes do not consume large amounts of energy, and 2) the use of microbes is not dependent on the price of crude oil, as compared with other EOR processes. Because microbial growth occurs at exponential rates, it is possible to produce large amounts of useful products rapidly from inexpensive and/or renewable resources. Thus, MEOR has the potential to be more cost-effective than other EOR processes.”

Test results of the first oil and water production samples have been received. Paraffin was measured at 11.9% rather that the 4.8% referenced in the Austral Engineering Report. This would substantiate the notation that only 40,000 barrels of the estimated 12.58 MMBO original oil in place in this part of the Minerva Rockdale field was produced by primary production techniques, since the reservoir would have rapidly healed itself through coagulation of the paraffin.

An inspection trip to the Balch lease indicated that the infrastructure necessary to operate has been installed: a new tank battery, new heater/treater, new flow lines, new electric lines and associated switchgear, cement pads for new pumping units, new tubing, rods and well plumbing. The four wells of the first test phase were all pumping and putting oil into the oil tanks and water into the water tank. This demonstrates that NTE has a thorough grasp of the equipment and operational considerations necessary to operate an oilfield and effectively produce oil.

As testing and logging of old wells progresses and continued efforts toward returning abandoned wells to production demonstrate the validity of calculations of theoretical original oil in place and the effectivness of the enhanced recovery techniques, those projected barrels are now starting to be counted as stock tank barrels produced.

Regulation, Risk and Uncertainy

EOR and production operations are subject to various types of regulation at the federal, state and local levels. The regulations include maintaining bonding requirements to rework or operate wells, defining potential well locations, specifying well casing integrity, plugging and abandoning well statutes, and the surface use and restoration of properties on which wells are operated. Operations are also subject to various conservation laws and regulations. These include the regulation of spacing or proration of wells (the density of wells in a given field). In addition, state conservation laws establish maximum rates of production from oil and natural gas wells. The effect of these regulations is to limit the amounts of crude oil and natural gas that can be produced from the Company’s wells.

Because federal, state and local statutes, rules, and regulations undergo constant review and often are amended, expanded, and reinterpreted, it is difficult to predict the future cost or impact of regulatory compliance. However, thoroughly understanding and adhering to federal, state, and local regulations will greatly reduce the operational costs associated with operating an oil and gas company.

The process of estimating oil and natural gas reserves is complex, requiring significant decisions and assumptions in the evaluation of available geological, engineering, and economic data for each reservoir. As a result, the estimates are inherently imprecise evaluations of reserve quantities and could materially affect the quantity and value of the reported reserves. Actual future production of recoverable oil and gas reserves may vary substantially from those assumed in the estimates.

Reserve Potential of North Texas Energy, Inc. as of December 31, 2014

Estimated Net Reserves and Income Data

Certain Leasehold Interests of North Texas Energy – Total Net Direct Interests

As of December 31, 2014

Net Remaining Reserves	Proved Developed Producing		Proved Undeveloped Non-Producing		Total Proved

Oil/Condensate STBO		0		0		0
Gas – MMCF		0		0		0

Income Data (M$)
Future Gross Revenue		0		0		0
Deductions		0		0		0
Future Net Income (FNI)		0		0		0

Discounted FNI @ 10%		0		0		0

Summary & Conclusions

The oil reservoirs under an oil lease are somewhat like a savings account where the contents have no financial worth. The value of the account is determined by how rapidly the contents are being depleted. Production during the testing phase is small and erratic with minimal depletion occuring, Therefore it’s value approaches zero and no proved reserves exist.

In the ‘Probable Undeveloped Non-producing’ category and based upon the thirty percent of ‘Original Oil In Place’ standard used by most reservoir engineers for estimating actual producable oil by conventional and secondary production techniques, the OOIP for the leases presently owned by North Texas Energy appears to have been 4,017,585 reservoir barrels; of these barrels 2,869,704 are bound to sand grains or chemically bonded to shales and are not movable by conventional technology.

Applying the formation volume factor to reservoir barrels to account for shrinkage as the barrel changes location from several atmospheres of pressure in the reservoir to the surface results in 998,158 stock-tank barrels of crude oil being the original reserves available for production before initial drilling. From this must be deducted the 6,020 barrels of oil sold through December 31, 2014. This leaves 992,138 stock-tank barrels of crude oil as the gross reserves remaining to the mineral estate in this category.

Deducting the Royalty payable to the Mineral Owners results in 803,937 stock tank barrels of crude oil being the net reserves remaining in the ‘Probable Undeveloped Non-producing’ category to North Texas Energy.

In addition, there appear to be 996,492 stock-tank barrels of crude oil in the ‘Possible Undeveloped Non-producing’ reserve category based upon future development drilling of the leases.

It is the opinion of the author, that the Company’s Plan, as summarized in this Report, has a reasonable opportunity of commercial success.

Qualifications

Mr. Durkee is a Consulting Petroleum Engineer, registered with the State of Oklahoma, State Board of Registration for Professional Engineers and Land Surveyors, number 14481. He has initiated projects through geological and satellite studies, managed drilling and completion programs and operated oil and gas producing properties. He has designed and operated gas pipelines, an LPG extraction plant and several waterfloods, MEOR and polymer floods throughout the Mid-continent region.

He is native to the city of Tulsa and has been the operator of wells in Texas and Oklahoma since 1972.

Consent

John M. Durkee has consented to the inclusion of this Report in the Annual filing in the form and context in which it appears and has not withdrawn this consent before lodgment of the relevant registration statement with the U. S. Securities and Exchange Commission (SEC).

A copy of this report was given to and reviewed by North Texas Energy, Inc. for comment on any factual errors; however, the analysis and conclusions contained herein are those of the author alone.

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10-K 2014-12-31 false NORTH TEXAS ENERGY, INC. 0001514994 --12-31 6519815 0 Smaller Reporting Company Yes No No 2014 FY

Note 1 - Business and Organization   North Texas Energy, Inc. (the Company) was incorporated in the State of Nevada on January 12, 2011. The Company intends to focus on re-entering non-producing oil fields and re-starting production with existing wells. On February 25, 2011, the Company entered into a Purchase and Sale Agreement with Remington Oil & Gas, Inc. (Remington) to acquire Remingtons interest in an oil and gas lease in Upshur and Milam County, Texas along with wellhead equipment and certain lease obligations.

Note 2 - Summary of Significant Accounting Policies   Basis of Presentation   These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (GAAP) and include the accounts of the Company and those of its wholly owned subsidiary. All significant intercompany accounts and transactions have been eliminated.   Cash and Cash Equivalents   Cash equivalents are highly liquid investments with an original maturity of three months or less.   Accounts Receivable   Accounts receivable are stated at the historical carrying amount net of write-offs and allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximates fair value because of the short-term nature of the instruments.   The Company's reported balance of accounts receivable, net of allowance for doubtful accounts, represents management's estimate of the amount that ultimately will be realized in cash. The Company reviews the adequacy of the allowance for doubtful accounts on an ongoing basis, using historical payment trends, the age of the receivables and knowledge of the individual customers or joint interest owners. When the analysis indicates, management increases or decreases the allowance accordingly. However, if the financial condition of our customers were to deteriorate, additional allowances might be required.   Inventory   From time to time, crude oil production volumes may be stored as inventory and sold at a later time. Inventory is carried at the lower of production cost or market value. The first-in, first-out method is used for the crude oil inventory. As of December 31, 2013, inventory consisted of crude oil. There was no inventory as of December 31, 2014.   Oil and Gas Properties   The Company uses the full cost method of accounting for exploration and development activities as defined by the U.S. Securities and Exchange Commission (SEC). Under this method of accounting, the costs for unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. Capitalized costs include lease acquisition, geological and geophysical work, delay rentals, costs of drilling, completing and equipping the wells and any internal costs that are directly related to acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or other disposition of oil and gas properties are generally treated as a reduction in the capitalized costs of oil and gas properties, unless the impact of such a reduction would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.   The Company categorizes its full cost pools as costs subject to amortization and costs not being amortized. The sum of net capitalized costs subject to amortization, including estimated future development and abandonment costs, are amortized using the unit-of-production method.   Oil and gas properties include costs that are excluded from capitalized costs being amortized. These amounts represent costs of investments in unproved properties. The Company excludes these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. All costs excluded are reviewed annually to determine if impairment has occurred. The amount of any impairment is transferred to the costs subject to amortization.   Ceiling Test and Impairment   Under the full cost method of accounting, a ceiling test is performed each quarter for proved properties. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X. The ceiling test determines a limit, on a country-by-country basis, on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization and impairment(DD&A) and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) with consideration of price change only to the extent provided by contractual arrangement, discounted at 10%, net of related tax effects. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated DD&A. The Company has no proved properties subject to the full cost ceiling test as of December 31, 2014.   Asset Retirement Obligations   Asset retirement obligations (ARO) represent the future abandonment costs of tangible assets such as platforms, wells, service assets, pipelines, and other facilities. The fair value of a liability for an asset's retirement obligation is recorded in the period in which it is incurred if a reasonable estimate of fair value can be made, and that the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, an adjustment is made to the full cost pool, with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. The ARO assets, which are carried on the balance sheet as part of the full cost pool, will be included in our amortization base for the purposes of calculating depreciation, depletion and amortization expense. For the purposes of calculating the ceiling test, the future cash outflows associated with settling the ARO liability is included in the computation of the discounted present value of estimated future net revenues.   Revenue Recognition   The Company recognizes sales revenues for crude oil based on the amount sold to purchasers when delivery to the purchaser has occurred and title has transferred. This occurs when a tanker lifting has occurred.   Income Taxes   Deferred income taxes are provided on a liability method whereby deferred tax assets and liabilities are established for the difference between the financial reporting and income tax basis of assets and liabilities as well as operating loss and tax credit carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.   Realization of deferred tax assets is dependent upon sufficient future taxable income during the period that deductible temporary differences and carry-forwards are expected to be available to reduce taxable income. At December 31, 2014 and 2013, the Company has recorded a 100% valuation allowance as management believes it is likely that no deferred tax assets will be realized.   At December 31, 2014, the Company had net operating loss carry forwards of approximately $800,000 that will expire between 2031 through 2034.   Net Income (Loss) Per Share   Basic net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted-average number of common and common equivalent shares outstanding during the period. Common share equivalents included in the diluted computation represent shares issuable upon assumed exercise of stock options and warrants using the treasury stock and if converted method. For periods in which net losses are incurred, weighted average shares outstanding is the same for basic and diluted loss per share calculations, as the inclusion of common share equivalents would have an anti-dilutive effect. As of December 31, 2014 and 2013, there were no potentially dilutive shares.   Use of Estimates   The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at year-end and the reported amounts of revenues and expenses during the year and the reported amount of proved natural gas and oil reserves. Management bases its estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments that are not readily apparent from other sources. Actual results could differ from these estimates and changes in these estimates are recorded when known.   Subsequent Events   The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration.   Recently Issued Accounting Pronouncements   In August 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-15, Presentation of Financial Statements Going Concern. The Update provides U.S. GAAP guidance on managements responsibility in evaluating whether there is substantial doubt about a companys ability to continue as a going concern and about related footnote disclosures. For each reporting period, management will be required to evaluate whether there are conditions or events that raise substantial doubt about a companys ability to continue as a going concern within one year from the date the financial statements are issued. The amendments in this Update is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. The Company is currently evaluating the effects of ASU 2014-15 on the consolidated financial statements.   The Company does not believe that any other recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the accompanying financial statements.

Note 3 - Going Concern   As shown in the accompanying financial statements, the Company has incurred losses from operations, has not generated significant revenue and has not secured continuous funding for the operation of its oil and gas producing activities. These factors raise substantial doubt about the Companys ability to continue as a going concern. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern. In addition to the offering of securities for sale to the public, the Company currently is diligently searching for other short-term and long-term sources of liquidity for its producing operations.

Note 4 Oil and Gas Properties, Full Cost Method   The Companys oil and gas properties at December 31, 2014 and 2013 are located in the State of Texas in the United States and are all in Milam County.   During 2014, the Company transferred $1,395,848 from costs subject to amortization to unproved properties as the wells were only producing insignificant volumes of crude oil. During 2013, the Company had transferred $1,147,903 of oil and gas properties to costs subject to amortization from unproved properties.   During the year ended December 31, 2014, the Company added two additional oil and gas leases known as the Hicks and Cormwell leases. The added leases contain a total of five wells of which two are on the Hicks lease and there are on the Cormwell lease. The wells on the Hicks and Cormwell leases were in operation during 2014.  The Company paid $6,133 and $8,720, respectively, as cash consideration for the acquisition of the leases.   On October 10, 2014, the Company also entered into a lease agreement to lease an additional 221 acres in Milam County (Wadlington lease). The Company paid $11,083 for the Wadlington lease and is still in the process of obtaining the drilling permit.   For the year ended December 31, 2014, the Company invested $235,263 in the development of its oil and gas infrastructure and wells and the acquisition of new lease properties. For the year ended December 31, 2013, the Company invested $440,379 in the development of its oil and gas infrastructure and wells. In the month of December 2013, the Company produced approximately 120 barrels of oil from the refurbished wells on the Balch Lease which is included in inventory at December 31, 2013.   On December 18, 2013, the Company's oil and gas leases on its Upshur County Texas properties expired. The Company recorded an impairment expense of $1,238,887 related to the expired leases.

Note 5 Accrued Lease Liabilities   The Company has an accrued lease liability to KADs Oil, Inc., the lessor of the Companys leases in both Upshur and Milam County, Texas. As a result of the Purchase and Sale Agreement with Remington, the Company assumed the leasehold obligation of $50,000. Payments are to be made when oil and gas is recovered and delivered to market at the rate of 25% of the sale price after all operating expenses. No payment has been made as of December 31, 2014.   On May 10, 2011, the Company entered into an oil, gas and mineral lease agreement for its oil and gas properties located in Milam County, Texas. Pursuant to the lease agreement, the Company will pay the lessor $15,881 for the lease which is recorded as an accrued leasehold liability on the Companys balance sheets at December 31, 2014 and 2013.

Note 6 Asset Retirement Obligation   The following table provides a reconciliation of the changes in the estimated present value of asset retirement obligations.     <div align="center"> <table border="0" cellspacing="0" cellpadding="0" width="80%" style='width:80.0%'> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;padding:0in 0in 1.5pt 0in'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0in 0in 1.5pt 0in'>   </td> <td width="15%" colspan="2" valign="bottom" style='width:15.62%;border:none;border-bottom:solid black 1.5pt;padding:0'> December 31, 2014 </td> <td width="0%" valign="bottom" style='width:.9%;padding:0in 0in 1.5pt 0in'></td> <td width="0%" valign="bottom" style='width:.66%;padding:0in 0in 1.5pt 0in'></td> <td width="16%" colspan="2" valign="bottom" style='width:16.26%;border:none;border-bottom:solid black 1.5pt;padding:0'> December  31, 2013 </td> <td width="0%" valign="bottom" style='width:.66%;padding:0in 0in 1.5pt 0in'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="15%" colspan="2" valign="bottom" style='width:15.62%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.9%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="16%" colspan="2" valign="bottom" style='width:16.26%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="15%" colspan="2" valign="bottom" style='width:15.62%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.9%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="16%" colspan="2" valign="bottom" style='width:16.26%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:#CCEEFF;padding:0'> Beginning asset retirement obligation </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.28%;background:#CCEEFF;padding:0'> 25,844 </td> <td width="0%" valign="bottom" style='width:.9%;background:#CCEEFF;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.9%;background:#CCEEFF;padding:0'> 54,709 </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:white;padding:0'> Change of estimate </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;background:white;padding:0'> (2,645 </td> <td width="0%" valign="bottom" style='width:.9%;background:white;padding:0'> ) </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;background:white;padding:0'> (2,509 </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'> )  </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:white;padding:0'> Addition </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;background:white;padding:0'> 18,260 </td> <td width="0%" valign="bottom" style='width:.9%;background:white;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;background:white;padding:0'> - </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:#CCEEFF;padding:0'> Disposal of leases </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:#CCEEFF;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;background:#CCEEFF;padding:0'> - </td> <td width="0%" valign="bottom" style='width:.9%;background:#CCEEFF;padding:0'></td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:#CCEEFF;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;background:#CCEEFF;padding:0'> (38,737 </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'> ) </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:white;padding:0in 0in 1.5pt 0in'> Accretion expense </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0in 0in 1.5pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.34%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'> 2,823 </td> <td width="0%" valign="bottom" style='width:.9%;background:white;padding:0in 0in 1.5pt 0in'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0in 0in 1.5pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.36%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'> 12,381 </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0in 0in 1.5pt 0in'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'> Ending asset retirement obligation </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.34%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.28%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'>  44,282 </td> <td width="0%" valign="bottom" style='width:.9%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.36%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.9%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'> 25,844 </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> </tr> </table> </div>

Note 7 Equity   During the year ended December 31, 2014, the Company issued 287,800 common shares for $575,600 cash. The Company also received $40,000 cash for sale of 20,000 common shares which have not been issued. During the year ended December 31, 2013, the Company issued 348,265 common shares for $695,030 cash.

Note 8 Related Party Transactions   During the years ended December 31, 2014 and 2013, the Companys Chief Executive Officer, Mr. Kevin Jones, contributed $0 and $18,351, respectively, to the Company.

Note 9 Subsequent Events   Subsequent to December 31, 2014, the Company issued 52,750 common shares for $105,500 cash.

Basis of Presentation   These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (GAAP) and include the accounts of the Company and those of its wholly owned subsidiary. All significant intercompany accounts and transactions have been eliminated.

Cash and Cash Equivalents   Cash equivalents are highly liquid investments with an original maturity of three months or less.

Accounts Receivable   Accounts receivable are stated at the historical carrying amount net of write-offs and allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximates fair value because of the short-term nature of the instruments.   The Company's reported balance of accounts receivable, net of allowance for doubtful accounts, represents management's estimate of the amount that ultimately will be realized in cash. The Company reviews the adequacy of the allowance for doubtful accounts on an ongoing basis, using historical payment trends, the age of the receivables and knowledge of the individual customers or joint interest owners. When the analysis indicates, management increases or decreases the allowance accordingly. However, if the financial condition of our customers were to deteriorate, additional allowances might be required.

Inventory   From time to time, crude oil production volumes may be stored as inventory and sold at a later time. Inventory is carried at the lower of production cost or market value. The first-in, first-out method is used for the crude oil inventory. As of December 31, 2013, inventory consisted of crude oil. There was no inventory as of December 31, 2014.

Oil and Gas Properties   The Company uses the full cost method of accounting for exploration and development activities as defined by the U.S. Securities and Exchange Commission (SEC). Under this method of accounting, the costs for unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. Capitalized costs include lease acquisition, geological and geophysical work, delay rentals, costs of drilling, completing and equipping the wells and any internal costs that are directly related to acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or other disposition of oil and gas properties are generally treated as a reduction in the capitalized costs of oil and gas properties, unless the impact of such a reduction would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.   The Company categorizes its full cost pools as costs subject to amortization and costs not being amortized. The sum of net capitalized costs subject to amortization, including estimated future development and abandonment costs, are amortized using the unit-of-production method.   Oil and gas properties include costs that are excluded from capitalized costs being amortized. These amounts represent costs of investments in unproved properties. The Company excludes these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. All costs excluded are reviewed annually to determine if impairment has occurred. The amount of any impairment is transferred to the costs subject to amortization.

Ceiling Test and Impairment   Under the full cost method of accounting, a ceiling test is performed each quarter for proved properties. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X. The ceiling test determines a limit, on a country-by-country basis, on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization and impairment(DD&A) and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) with consideration of price change only to the extent provided by contractual arrangement, discounted at 10%, net of related tax effects. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated DD&A. The Company has no proved properties subject to the full cost ceiling test as of December 31, 2014.

Asset Retirement Obligations   Asset retirement obligations (ARO) represent the future abandonment costs of tangible assets such as platforms, wells, service assets, pipelines, and other facilities. The fair value of a liability for an asset's retirement obligation is recorded in the period in which it is incurred if a reasonable estimate of fair value can be made, and that the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, an adjustment is made to the full cost pool, with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. The ARO assets, which are carried on the balance sheet as part of the full cost pool, will be included in our amortization base for the purposes of calculating depreciation, depletion and amortization expense. For the purposes of calculating the ceiling test, the future cash outflows associated with settling the ARO liability is included in the computation of the discounted present value of estimated future net revenues.

Revenue Recognition   The Company recognizes sales revenues for crude oil based on the amount sold to purchasers when delivery to the purchaser has occurred and title has transferred. This occurs when a tanker lifting has occurred.

Income Taxes   Deferred income taxes are provided on a liability method whereby deferred tax assets and liabilities are established for the difference between the financial reporting and income tax basis of assets and liabilities as well as operating loss and tax credit carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.   Realization of deferred tax assets is dependent upon sufficient future taxable income during the period that deductible temporary differences and carry-forwards are expected to be available to reduce taxable income. At December 31, 2014 and 2013, the Company has recorded a 100% valuation allowance as management believes it is likely that no deferred tax assets will be realized.   At December 31, 2014, the Company had net operating loss carry forwards of approximately $800,000 that will expire between 2031 through 2034.

Net Income (Loss) Per Share   Basic net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted-average number of common and common equivalent shares outstanding during the period. Common share equivalents included in the diluted computation represent shares issuable upon assumed exercise of stock options and warrants using the treasury stock and if converted method. For periods in which net losses are incurred, weighted average shares outstanding is the same for basic and diluted loss per share calculations, as the inclusion of common share equivalents would have an anti-dilutive effect. As of December 31, 2014 and 2013, there were no potentially dilutive shares.

Use of Estimates   The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at year-end and the reported amounts of revenues and expenses during the year and the reported amount of proved natural gas and oil reserves. Management bases its estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments that are not readily apparent from other sources. Actual results could differ from these estimates and changes in these estimates are recorded when known.

Subsequent Events   The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration.

Recently Issued Accounting Pronouncements   In August 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-15, Presentation of Financial Statements Going Concern. The Update provides U.S. GAAP guidance on managements responsibility in evaluating whether there is substantial doubt about a companys ability to continue as a going concern and about related footnote disclosures. For each reporting period, management will be required to evaluate whether there are conditions or events that raise substantial doubt about a companys ability to continue as a going concern within one year from the date the financial statements are issued. The amendments in this Update is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. The Company is currently evaluating the effects of ASU 2014-15 on the consolidated financial statements.   The Company does not believe that any other recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the accompanying financial statements.

<div align="center"> <table border="0" cellspacing="0" cellpadding="0" width="80%" style='width:80.0%'> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;padding:0in 0in 1.5pt 0in'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0in 0in 1.5pt 0in'>   </td> <td width="15%" colspan="2" valign="bottom" style='width:15.62%;border:none;border-bottom:solid black 1.5pt;padding:0'> December 31, 2014 </td> <td width="0%" valign="bottom" style='width:.9%;padding:0in 0in 1.5pt 0in'></td> <td width="0%" valign="bottom" style='width:.66%;padding:0in 0in 1.5pt 0in'></td> <td width="16%" colspan="2" valign="bottom" style='width:16.26%;border:none;border-bottom:solid black 1.5pt;padding:0'> December  31, 2013 </td> <td width="0%" valign="bottom" style='width:.66%;padding:0in 0in 1.5pt 0in'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="15%" colspan="2" valign="bottom" style='width:15.62%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.9%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="16%" colspan="2" valign="bottom" style='width:16.26%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="15%" colspan="2" valign="bottom" style='width:15.62%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.9%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> <td width="16%" colspan="2" valign="bottom" style='width:16.26%;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:#CCEEFF;padding:0'> Beginning asset retirement obligation </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.28%;background:#CCEEFF;padding:0'> 25,844 </td> <td width="0%" valign="bottom" style='width:.9%;background:#CCEEFF;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.9%;background:#CCEEFF;padding:0'> 54,709 </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:white;padding:0'> Change of estimate </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;background:white;padding:0'> (2,645 </td> <td width="0%" valign="bottom" style='width:.9%;background:white;padding:0'> ) </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;background:white;padding:0'> (2,509 </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'> )  </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:white;padding:0'> Addition </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;background:white;padding:0'> 18,260 </td> <td width="0%" valign="bottom" style='width:.9%;background:white;padding:0'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;background:white;padding:0'> - </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:#CCEEFF;padding:0'> Disposal of leases </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.34%;background:#CCEEFF;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;background:#CCEEFF;padding:0'> - </td> <td width="0%" valign="bottom" style='width:.9%;background:#CCEEFF;padding:0'></td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'>   </td> <td width="1%" valign="bottom" style='width:1.36%;background:#CCEEFF;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;background:#CCEEFF;padding:0'> (38,737 </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0'> ) </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:white;padding:0in 0in 1.5pt 0in'> Accretion expense </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0in 0in 1.5pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.34%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.28%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'> 2,823 </td> <td width="0%" valign="bottom" style='width:.9%;background:white;padding:0in 0in 1.5pt 0in'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0in 0in 1.5pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.36%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'>   </td> <td width="14%" valign="bottom" style='width:14.9%;border:none;border-bottom:solid black 1.5pt;background:white;padding:0'> 12,381 </td> <td width="0%" valign="bottom" style='width:.66%;background:white;padding:0in 0in 1.5pt 0in'>   </td> </tr> <tr align="left"> <td width="65%" valign="bottom" style='width:65.22%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'> Ending asset retirement obligation </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.34%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.28%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'>  44,282 </td> <td width="0%" valign="bottom" style='width:.9%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> <td width="1%" valign="bottom" style='width:1.36%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'> $ </td> <td width="14%" valign="bottom" style='width:14.9%;border-top:solid windowtext 1.0pt;border-left:none;border-bottom:double black 2.25pt;border-right:none;background:#CCEEFF;padding:0'> 25,844 </td> <td width="0%" valign="bottom" style='width:.66%;background:#CCEEFF;padding:0in 0in 3.0pt 0in'>   </td> </tr> </table> </div>

Nevada 2011-01-12

800000

1395848

1147903 6133 8720 11083

235263

440379

1238887

50000

15881

54709

-2645

-2509

18260

-38737

-2823

-12381

44282

25844

287800 575600 40000 20000 348265 695030

18351

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Equity Cash Flows From Financing Activities: Change in Accounts payable and accrued liabilities Change in Accounts payable and accrued liabilities Change in Inventory Change in Inventory Balance (Shares) Balance (Shares) Balance (Shares) Statement {1} Statement Legal and professional fees Total current assets Total current assets Entity Incorporation, State Country Name Entity Voluntary Filers Recently Issued Accounting Pronouncements Subsequent Events Payable for purchase of oil and gas properties Asset retirement cost Equity Components Net operating loss Accounts receivable Hicks Lease Liabilities {1} Lease Liabilities Total liabilities and shareholders' equity Total liabilities and shareholders' equity Common stock, $0.00001 par value, 100,000,000 shares authorized, 6,467,065 and 6,179,265 shares issued, respectively Note 6 - Asset Retirement Obligations Noncash investing activities: Net increase in cash Net increase in cash Net cash used in investing activities Net cash used in investing activities Changes in operating assets and liabilities: CONSOLIDATED STATEMENTS OF CASH FLOWS Issuance of common stock for cash Capital contributions Entity Registrant Name Operating Loss Carryforwards Ceiling Test and Impairment Accounts Receivable Cash Flows From Investing Activities: Weighted average number of common shares outstanding - basic and diluted Accumulated depletion, depreciation and amortization Inventory Cash Cash at beginning of year Cash at end of year CONSOLIDATED BALANCE SHEETS Current Fiscal Year End Date Note 9 - Subsequent Events Accumulated Deficit Additional Paid-in Capital General and administrative expenses CONSOLIDATED BALANCE SHEETS PARENTHETICAL Total assets Total assets Entity Current Reporting Status Basis of Presentation Statement Basic and Diluted Loss Per Common Share Common stock shares outstanding Shareholders' equity Total current liabilities Total current liabilities Costs not being amortized Costs subject to amortization KADs Oil, Inc. 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Note 5 - Accrued Lease Liabilities (Details) (USD $)

Dec. 31, 2014

Dec. 31, 2013

Accrued lease liabilities $ 65,881us-gaap_DebtAndCapitalLeaseObligations $ 65,881us-gaap_DebtAndCapitalLeaseObligations

KADs Oil, Inc.

Accrued lease liabilities 50,000 50,000

Other

Accrued lease liabilities $ 15,881 $ 15,881

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Sum of the carrying values as of the balance sheet date of all debt, including all short-term borrowings, long-term debt, and capital lease obligations.

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Note 2 - Summary of Significant Accounting Policies: Net Income (Loss) Per Share (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Net Income (Loss) Per Share
Net Income (Loss) Per Share

Basic net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted-average number of common and common equivalent shares outstanding during the period. Common share equivalents included in the diluted computation represent shares issuable upon assumed exercise of stock options and warrants using the treasury stock and “if converted” method. For periods in which net losses are incurred, weighted average shares outstanding is the same for basic and diluted loss per share calculations, as the inclusion of common share equivalents would have an anti-dilutive effect. As of December 31, 2014 and 2013, there were no potentially dilutive shares.

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Disclosure of accounting policy for computing basic and diluted earnings or loss per share for each class of common stock and participating security. Addresses all significant policy factors, including any antidilutive items that have been excluded from the computation and takes into account stock dividends, splits and reverse splits that occur after the balance sheet date of the latest reporting period but before the issuance of the financial statements.

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Note 3 - Going Concern
12 Months Ended

Dec. 31, 2014

Notes

Note 3 - Going Concern
Note 3 - Going Concern

As shown in the accompanying financial statements, the Company has incurred losses from operations, has not generated significant revenue and has not secured continuous funding for the operation of its oil and gas producing activities. These factors raise substantial doubt about the Company’s ability to continue as a going concern. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern. In addition to the offering of securities for sale to the public, the Company currently is diligently searching for other short-term and long-term sources of liquidity for its producing operations.

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Note 6 - Asset Retirement Obligations: Schedule of Asset Retirement Obligations (Tables)
12 Months Ended

Dec. 31, 2014

Tables/Schedules

Schedule of Asset Retirement Obligations

December 31,

2014

December 31,

2013

Beginning asset retirement obligation

$

25,844

$

54,709

Change of estimate

(2,645

)

(2,509

)

Addition

18,260

-

Disposal of leases

-

(38,737

)

Accretion expense

2,823

12,381

Ending asset retirement obligation

$

44,282

$

25,844

X

- Definition

Tabular disclosure of the carrying amount of a liability for asset retirement obligations.

+ References

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-Publisher FASB

-Name Accounting Standards Codification

-Topic 410

-SubTopic 20

-Section 50

-Paragraph 1

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Note 2 - Summary of Significant Accounting Policies: Recently Issued Accounting Pronouncements (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Recently Issued Accounting Pronouncements
Recently Issued Accounting Pronouncements

In August 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-15, Presentation of Financial Statements – Going Concern. The Update provides U.S. GAAP guidance on management’s responsibility in evaluating whether there is substantial doubt about a company’s ability to continue as a going concern and about related footnote disclosures. For each reporting period, management will be required to evaluate whether there are conditions or events that raise substantial doubt about a company’s ability to continue as a going concern within one year from the date the financial statements are issued. The amendments in this Update is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. The Company is currently evaluating the effects of ASU 2014-15 on the consolidated financial statements.

The Company does not believe that any other recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the accompanying financial statements.

X

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Note 1 - Business and Organization (Details)
12 Months Ended

Dec. 31, 2014

Details

Entity Incorporation, State Country Name Nevada

Entity Incorporation, Date of Incorporation Jan. 12, 2011

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Note 2 - Summary of Significant Accounting Policies: Income Taxes (Details) (USD $)

Dec. 31, 2014

Details

Operating Loss Carryforwards $ 800,000us-gaap_OperatingLossCarryforwards

X

- Definition

Amount of operating loss carryforward, before tax effects, available to reduce future taxable income under enacted tax laws.

+ References

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-Publisher FASB

-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section 50

-Paragraph 3

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Note 2 - Summary of Significant Accounting Policies
12 Months Ended

Dec. 31, 2014

Notes

Note 2 - Summary of Significant Accounting Policies
Note 2 - Summary of Significant Accounting Policies

Basis of Presentation

These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) and include the accounts of the Company and those of its wholly owned subsidiary. All significant intercompany accounts and transactions have been eliminated.

Cash and Cash Equivalents

Cash equivalents are highly liquid investments with an original maturity of three months or less.

Accounts Receivable

Accounts receivable are stated at the historical carrying amount net of write-offs and allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximates fair value because of the short-term nature of the instruments.

The Company's reported balance of accounts receivable, net of allowance for doubtful accounts, represents management's estimate of the amount that ultimately will be realized in cash. The Company reviews the adequacy of the allowance for doubtful accounts on an ongoing basis, using historical payment trends, the age of the receivables and knowledge of the individual customers or joint interest owners. When the analysis indicates, management increases or decreases the allowance accordingly. However, if the financial condition of our customers were to deteriorate, additional allowances might be required.

Inventory

From time to time, crude oil production volumes may be stored as inventory and sold at a later time. Inventory is carried at the lower of production cost or market value. The first-in, first-out method is used for the crude oil inventory. As of December 31, 2013, inventory consisted of crude oil. There was no inventory as of December 31, 2014.

Oil and Gas Properties

The Company uses the full cost method of accounting for exploration and development activities as defined by the U.S. Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs for unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. Capitalized costs include lease acquisition, geological and geophysical work, delay rentals, costs of drilling, completing and equipping the wells and any internal costs that are directly related to acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or other disposition of oil and gas properties are generally treated as a reduction in the capitalized costs of oil and gas properties, unless the impact of such a reduction would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.

The Company categorizes its full cost pools as costs subject to amortization and costs not being amortized. The sum of net capitalized costs subject to amortization, including estimated future development and abandonment costs, are amortized using the unit-of-production method.

Oil and gas properties include costs that are excluded from capitalized costs being amortized. These amounts represent costs of investments in unproved properties. The Company excludes these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. All costs excluded are reviewed annually to determine if impairment has occurred. The amount of any impairment is transferred to the costs subject to amortization.

Ceiling Test and Impairment

Under the full cost method of accounting, a ceiling test is performed each quarter for proved properties. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X. The ceiling test determines a limit, on a country-by-country basis, on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization and impairment(“DD&A”) and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) with consideration of price change only to the extent provided by contractual arrangement, discounted at 10%, net of related tax effects. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated DD&A. The Company has no proved properties subject to the full cost ceiling test as of December 31, 2014.

Asset Retirement Obligations

Asset retirement obligations (“ARO”) represent the future abandonment costs of tangible assets such as platforms, wells, service assets, pipelines, and other facilities. The fair value of a liability for an asset's retirement obligation is recorded in the period in which it is incurred if a reasonable estimate of fair value can be made, and that the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, an adjustment is made to the full cost pool, with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. The ARO assets, which are carried on the balance sheet as part of the full cost pool, will be included in our amortization base for the purposes of calculating depreciation, depletion and amortization expense. For the purposes of calculating the ceiling test, the future cash outflows associated with settling the ARO liability is included in the computation of the discounted present value of estimated future net revenues.

Revenue Recognition

The Company recognizes sales revenues for crude oil based on the amount sold to purchasers when delivery to the purchaser has occurred and title has transferred. This occurs when a tanker lifting has occurred.

Income Taxes

Deferred income taxes are provided on a liability method whereby deferred tax assets and liabilities are established for the difference between the financial reporting and income tax basis of assets and liabilities as well as operating loss and tax credit carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.

Realization of deferred tax assets is dependent upon sufficient future taxable income during the period that deductible temporary differences and carry-forwards are expected to be available to reduce taxable income. At December 31, 2014 and 2013, the Company has recorded a 100% valuation allowance as management believes it is likely that no deferred tax assets will be realized.

At December 31, 2014, the Company had net operating loss carry forwards of approximately $800,000 that will expire between 2031 through 2034.

Net Income (Loss) Per Share

Basic net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted net income (loss) per share is computed by dividing the net income (loss) attributable to common shareholders by the weighted-average number of common and common equivalent shares outstanding during the period. Common share equivalents included in the diluted computation represent shares issuable upon assumed exercise of stock options and warrants using the treasury stock and “if converted” method. For periods in which net losses are incurred, weighted average shares outstanding is the same for basic and diluted loss per share calculations, as the inclusion of common share equivalents would have an anti-dilutive effect. As of December 31, 2014 and 2013, there were no potentially dilutive shares.

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at year-end and the reported amounts of revenues and expenses during the year and the reported amount of proved natural gas and oil reserves. Management bases its estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments that are not readily apparent from other sources. Actual results could differ from these estimates and changes in these estimates are recorded when known.

Subsequent Events

The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration.

Recently Issued Accounting Pronouncements

In August 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-15, Presentation of Financial Statements – Going Concern. The Update provides U.S. GAAP guidance on management’s responsibility in evaluating whether there is substantial doubt about a company’s ability to continue as a going concern and about related footnote disclosures. For each reporting period, management will be required to evaluate whether there are conditions or events that raise substantial doubt about a company’s ability to continue as a going concern within one year from the date the financial statements are issued. The amendments in this Update is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. The Company is currently evaluating the effects of ASU 2014-15 on the consolidated financial statements.

The Company does not believe that any other recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the accompanying financial statements.

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Note 4 - Oil and Gas Properties, Full Cost Method (Details) (USD $)
12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Total $ 1,395,848 $ 1,147,590

Costs subject to amortization 1,147,903

Development Costs, Period Cost 235,263us-gaap_DevelopmentCosts 440,379us-gaap_DevelopmentCosts

Impairment of oil and gas properties 1,238,887us-gaap_ImpairmentOfOilAndGasProperties

Hicks

Payments to acquire leases 6,133

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Payments to acquire leases 8,720

Wadlington

Payments to acquire leases $ 11,083

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CONSOLIDATED BALANCE SHEETS (USD $)

Dec. 31, 2014

Dec. 31, 2013

Current Assets

Cash $ 92,426us-gaap_Cash $ 50,924us-gaap_Cash

Inventory 1,013us-gaap_InventoryNet

Accounts receivable 5,369us-gaap_AccountsReceivableNet

Total current assets 97,795us-gaap_AssetsCurrent 51,937us-gaap_AssetsCurrent

Oil and gas properties, full cost method

Costs subject to amortization 1,147,903

Costs not being amortized 1,398,782

Accumulated depletion, depreciation and amortization (2,934) (313)

Total oil and gas properties, full cost method 1,395,848 1,147,590

Total assets 1,493,643us-gaap_Assets 1,199,527us-gaap_Assets

Current liabilities

Accounts payable and accrued liabilities 110,521 123,050

Common stock payable 40,000fil_CommonStockPayable

Accrued lease liabilities 65,881us-gaap_DebtAndCapitalLeaseObligations 65,881us-gaap_DebtAndCapitalLeaseObligations

Total current liabilities 216,402us-gaap_LiabilitiesCurrent 188,931us-gaap_LiabilitiesCurrent

Asset retirement obligations 44,282us-gaap_AssetRetirementObligation 25,844us-gaap_AssetRetirementObligation

Total liabilities 260,684us-gaap_Liabilities 214,775us-gaap_Liabilities

Commitments and contingencies

Shareholders' equity

Common stock, $0.00001 par value, 100,000,000 shares authorized, 6,467,065 and 6,179,265 shares issued, respectively 65us-gaap_CommonStockValue 62us-gaap_CommonStockValue

Additional paid-in capital 2,986,107us-gaap_AdditionalPaidInCapital 2,410,510us-gaap_AdditionalPaidInCapital

Accumulated deficit (1,753,213) (1,425,820)

Total shareholders' equity 1,232,959us-gaap_StockholdersEquity 984,752us-gaap_StockholdersEquity

Total liabilities and shareholders' equity $ 1,493,643 $ 1,199,527

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CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)
12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Cash Flows From Operating Activities:

Net loss $ (327,393)us-gaap_NetIncomeLoss $ (1,567,380)us-gaap_NetIncomeLoss

Adjustments to reconcile net loss to net cash from operating activities:

Depletion, accretion and impairment expense 5,443 1,251,581

Changes in operating assets and liabilities:

Change in Accounts receivable (5,369)

Change in Inventory 1,013fil_IncreaseDecreaseInInventory (1,013)fil_IncreaseDecreaseInInventory

Change in Accounts payable and accrued liabilities 43,403 18,693

Net Cash Used in Operating Activities (282,903) (298,119)

Cash Flows From Investing Activities:

Payments for proved oil and gas properties (291,195) (364,338)

Net cash used in investing activities (291,195) (364,338)

Cash Flows From Financing Activities:

Capital contributions 0 18,351

Proceeds from sale of common stock 615,600 695,030

Net Cash Provided by Financing Activities 615,600 713,381

Net increase in cash 41,502 50,924

Cash at beginning of year 50,924us-gaap_Cash

Cash at end of year 92,426us-gaap_Cash 50,924us-gaap_Cash

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Cash paid for interest 686us-gaap_InterestPaid

Cash paid for income taxes

Noncash investing activities:

Asset retirement cost 15,616 2,509

Payable for purchase of oil and gas properties $ 55,932 $ 76,041

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Note 7 - Equity (Details) (USD $)
12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Issuance of common stock for cash $ 575,600fil_IssuanceOfCommonStockForCash $ 695,030fil_IssuanceOfCommonStockForCash

Common stock payable 40,000fil_CommonStockPayable

Common Stock Payable (shares) 20,000fil_CommonStockPayableShares

Common Stock

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Note 2 - Summary of Significant Accounting Policies: Asset Retirement Obligations (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Asset Retirement Obligations
Asset Retirement Obligations

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Note 8 - Related Party Transactions (Details) (USD $)
12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Details

Capital contributions $ 0 $ 18,351

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Note 2 - Summary of Significant Accounting Policies: Income Taxes (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Income Taxes
Income Taxes

Deferred income taxes are provided on a liability method whereby deferred tax assets and liabilities are established for the difference between the financial reporting and income tax basis of assets and liabilities as well as operating loss and tax credit carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.

Realization of deferred tax assets is dependent upon sufficient future taxable income during the period that deductible temporary differences and carry-forwards are expected to be available to reduce taxable income. At December 31, 2014 and 2013, the Company has recorded a 100% valuation allowance as management believes it is likely that no deferred tax assets will be realized.

At December 31, 2014, the Company had net operating loss carry forwards of approximately $800,000 that will expire between 2031 through 2034.

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Note 1 - Business and Organization
12 Months Ended

Dec. 31, 2014

Notes

Note 1 - Business and Organization
Note 1 - Business and Organization

North Texas Energy, Inc. (“the Company”) was incorporated in the State of Nevada on January 12, 2011. The Company intends to focus on re-entering non-producing oil fields and re-starting production with existing wells. On February 25, 2011, the Company entered into a Purchase and Sale Agreement with Remington Oil & Gas, Inc. (“Remington”) to acquire Remington’s interest in an oil and gas lease in Upshur and Milam County, Texas along with wellhead equipment and certain lease obligations.

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CONSOLIDATED BALANCE SHEETS PARENTHETICAL (USD $)

Dec. 31, 2014

Dec. 31, 2013

CONSOLIDATED BALANCE SHEETS PARENTHETICAL

Common stock par value $ 0.00001 $ 0.00001

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Note 2 - Summary of Significant Accounting Policies: Cash and Cash Equivalents (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Cash and Cash Equivalents
Cash and Cash Equivalents

Cash equivalents are highly liquid investments with an original maturity of three months or less.

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Document and Entity Information (USD $)
12 Months Ended

Dec. 31, 2014

Apr. 14, 2015

Jun. 30, 2014

Document and Entity Information:

Entity Registrant Name NORTH TEXAS ENERGY, INC.

Document Type 10-K

Document Period End Date Dec. 31, 2014

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Current Fiscal Year End Date --12-31

Entity Common Stock, Shares Outstanding 6,519,815dei_EntityCommonStockSharesOutstanding

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Entity Well-known Seasoned Issuer No

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Entity Incorporation, State Country Name Nevada

Entity Incorporation, Date of Incorporation Jan. 12, 2011

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Note 2 - Summary of Significant Accounting Policies: Accounts Receivable (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Accounts Receivable
Accounts Receivable

Accounts receivable are stated at the historical carrying amount net of write-offs and allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximates fair value because of the short-term nature of the instruments.

The Company's reported balance of accounts receivable, net of allowance for doubtful accounts, represents management's estimate of the amount that ultimately will be realized in cash. The Company reviews the adequacy of the allowance for doubtful accounts on an ongoing basis, using historical payment trends, the age of the receivables and knowledge of the individual customers or joint interest owners. When the analysis indicates, management increases or decreases the allowance accordingly. However, if the financial condition of our customers were to deteriorate, additional allowances might be required.

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)
12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

CONSOLIDATED STATEMENTS OF OPERATIONS

Revenues $ 70,615us-gaap_Revenues

Lease operating expense 96,856us-gaap_LeaseOperatingExpense

Depletion and accretion 5,443 12,381

Impairment of oil and gas properties 1,238,887us-gaap_ImpairmentOfOilAndGasProperties

Legal and professional fees 88,916us-gaap_ProfessionalFees 145,204us-gaap_ProfessionalFees

General and administrative expenses 206,793us-gaap_GeneralAndAdministrativeExpense 170,222us-gaap_GeneralAndAdministrativeExpense

Total operating expenses 398,008us-gaap_OperatingExpenses 1,566,694us-gaap_OperatingExpenses

Net operating loss (327,393)us-gaap_OperatingIncomeLoss (1,566,694)us-gaap_OperatingIncomeLoss

Interest expense (686)us-gaap_InterestExpense

Net loss $ (327,393)us-gaap_NetIncomeLoss $ (1,567,380)us-gaap_NetIncomeLoss

Basic and Diluted Loss Per Common Share $ (0.05)us-gaap_EarningsPerShareBasicAndDiluted $ (0.26)us-gaap_EarningsPerShareBasicAndDiluted

Weighted average number of common shares outstanding - basic and diluted 6,328,533 5,976,117

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Note 6 - Asset Retirement Obligations
12 Months Ended

Dec. 31, 2014

Notes

Note 6 - Asset Retirement Obligations
Note 6 – Asset Retirement Obligation

The following table provides a reconciliation of the changes in the estimated present value of asset retirement obligations.

December 31,

2014

December 31,

2013

Beginning asset retirement obligation

$

25,844

$

54,709

Change of estimate

(2,645

)

(2,509

)

Addition

18,260

-

Disposal of leases

-

(38,737

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Accretion expense

2,823

12,381

Ending asset retirement obligation

$

44,282

$

25,844

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Note 5 - Accrued Lease Liabilities
12 Months Ended

Dec. 31, 2014

Notes

Note 5 - Accrued Lease Liabilities
Note 5 – Accrued Lease Liabilities

The Company has an accrued lease liability to KADs Oil, Inc., the lessor of the Company’s leases in both Upshur and Milam County, Texas. As a result of the Purchase and Sale Agreement with Remington, the Company assumed the leasehold obligation of $50,000. Payments are to be made when oil and gas is recovered and delivered to market at the rate of 25% of the sale price after all operating expenses. No payment has been made as of December 31, 2014.

On May 10, 2011, the Company entered into an oil, gas and mineral lease agreement for its oil and gas properties located in Milam County, Texas. Pursuant to the lease agreement, the Company will pay the lessor $15,881 for the lease which is recorded as an accrued leasehold liability on the Company’s balance sheets at December 31, 2014 and 2013.

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The entire disclosure for debt and capital lease obligations can be reported. Information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants. Also includes descriptions and amounts of capital leasing arrangements that consist of direct financing, sales type and leveraged leases. Disclosure may include the effect on the balance sheet and the income statement resulting from a change in lease classification for leases that at inception would have been classified differently had guidance been in effect at the inception of the original lease.

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Note 2 - Summary of Significant Accounting Policies: Revenue Recognition (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Revenue Recognition
Revenue Recognition

The Company recognizes sales revenues for crude oil based on the amount sold to purchasers when delivery to the purchaser has occurred and title has transferred. This occurs when a tanker lifting has occurred.

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Note 2 - Summary of Significant Accounting Policies: Inventory (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Inventory
Inventory

From time to time, crude oil production volumes may be stored as inventory and sold at a later time. Inventory is carried at the lower of production cost or market value. The first-in, first-out method is used for the crude oil inventory. As of December 31, 2013, inventory consisted of crude oil. There was no inventory as of December 31, 2014.

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Note 9 - Subsequent Events
12 Months Ended

Dec. 31, 2014

Notes

Note 9 - Subsequent Events
Note 9 – Subsequent Events

Subsequent to December 31, 2014, the Company issued 52,750 common shares for $105,500 cash.

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Note 7 - Equity
12 Months Ended

Dec. 31, 2014

Notes

Note 7 - Equity
Note 7 – Equity

During the year ended December 31, 2014, the Company issued 287,800 common shares for $575,600 cash. The Company also received $40,000 cash for sale of 20,000 common shares which have not been issued. During the year ended December 31, 2013, the Company issued 348,265 common shares for $695,030 cash.

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Note 8 - Related Party Transactions
12 Months Ended

Dec. 31, 2014

Notes

Note 8 - Related Party Transactions
Note 8 – Related Party Transactions

During the years ended December 31, 2014 and 2013, the Company’s Chief Executive Officer, Mr. Kevin Jones, contributed $0 and $18,351, respectively, to the Company.

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Note 2 - Summary of Significant Accounting Policies: Basis of Presentation (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Basis of Presentation
Basis of Presentation

These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) and include the accounts of the Company and those of its wholly owned subsidiary. All significant intercompany accounts and transactions have been eliminated.

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Note 6 - Asset Retirement Obligations: Schedule of Asset Retirement Obligations (Details) (USD $)
12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Details

Asset retirement obligations $ 44,282us-gaap_AssetRetirementObligation $ 25,844us-gaap_AssetRetirementObligation $ 54,709us-gaap_AssetRetirementObligation

Asset Retirement Obligation, Revision of Estimate (2,645) (2,509)

Asset Retirement Obligation, Addition 18,260

Disposal of leases (38,737)fil_DisposalOfLeases

Asset retirement cost $ 2,823 $ 12,381

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Note 2 - Summary of Significant Accounting Policies: Ceiling Test and Impairment (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Ceiling Test and Impairment
Ceiling Test and Impairment

Under the full cost method of accounting, a ceiling test is performed each quarter for proved properties. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X. The ceiling test determines a limit, on a country-by-country basis, on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization and impairment(“DD&A”) and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) with consideration of price change only to the extent provided by contractual arrangement, discounted at 10%, net of related tax effects. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated DD&A. The Company has no proved properties subject to the full cost ceiling test as of December 31, 2014.

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Note 2 - Summary of Significant Accounting Policies: Use of Estimates (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Use of Estimates
Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at year-end and the reported amounts of revenues and expenses during the year and the reported amount of proved natural gas and oil reserves. Management bases its estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments that are not readily apparent from other sources. Actual results could differ from these estimates and changes in these estimates are recorded when known.

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Consolidated Statements of Stockholders' Equity (Deficit) (USD $)

Common Stock

Additional Paid-in Capital

Accumulated Deficit

Total

Balance at Dec. 31, 2012 $ 58 $ 1,697,133 $ 141,560 $ 1,838,751us-gaap_StockholdersEquity

Balance (Shares) at Dec. 31, 2012 5,831,000

Capital contributions 18,351 18,351

Issuance of common stock for cash 4 695,026 695,030fil_IssuanceOfCommonStockForCash

Issuance of common stock for cash (shares) 348,265

Net loss (1,567,380) (1,567,380)us-gaap_NetIncomeLoss

Balance at Dec. 31, 2013 62 2,410,510 (1,425,820) 984,752us-gaap_StockholdersEquity

Balance (Shares) at Dec. 31, 2013 6,179,265

Capital contributions 0

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Issuance of common stock for cash (shares) 287,800

Net loss (327,393) (327,393)us-gaap_NetIncomeLoss

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Balance (Shares) at Dec. 31, 2014 6,467,065

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Note 4 - Oil and Gas Properties, Full Cost Method
12 Months Ended

Dec. 31, 2014

Notes

Note 4 - Oil and Gas Properties, Full Cost Method
Note 4 – Oil and Gas Properties, Full Cost Method

The Company’s oil and gas properties at December 31, 2014 and 2013 are located in the State of Texas in the United States and are all in Milam County.

During 2014, the Company transferred $1,395,848 from costs subject to amortization to unproved properties as the wells were only producing insignificant volumes of crude oil. During 2013, the Company had transferred $1,147,903 of oil and gas properties to costs subject to amortization from unproved properties.

During the year ended December 31, 2014, the Company added two additional oil and gas leases known as the “Hicks” and “Cormwell” leases. The added leases contain a total of five wells of which two are on the Hicks lease and there are on the Cormwell lease. The wells on the Hicks and Cormwell leases were in operation during 2014. The Company paid $6,133 and $8,720, respectively, as cash consideration for the acquisition of the leases.

On October 10, 2014, the Company also entered into a lease agreement to lease an additional 221 acres in Milam County (“Wadlington” lease). The Company paid $11,083 for the Wadlington lease and is still in the process of obtaining the drilling permit.

For the year ended December 31, 2014, the Company invested $235,263 in the development of its oil and gas infrastructure and wells and the acquisition of new lease properties. For the year ended December 31, 2013, the Company invested $440,379 in the development of its oil and gas infrastructure and wells. In the month of December 2013, the Company produced approximately 120 barrels of oil from the refurbished wells on the Balch Lease which is included in inventory at December 31, 2013.

On December 18, 2013, the Company's oil and gas leases on its Upshur County Texas properties expired. The Company recorded an impairment expense of $1,238,887 related to the expired leases.

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Note 2 - Summary of Significant Accounting Policies: Subsequent Events (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Subsequent Events
Subsequent Events

The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration.

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Disclosure of accounting policy for reporting subsequent events.

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Note 2 - Summary of Significant Accounting Policies: Oil and Gas Properties (Policies)
12 Months Ended

Dec. 31, 2014

Policies

Oil and Gas Properties
Oil and Gas Properties

The Company uses the full cost method of accounting for exploration and development activities as defined by the U.S. Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs for unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. Capitalized costs include lease acquisition, geological and geophysical work, delay rentals, costs of drilling, completing and equipping the wells and any internal costs that are directly related to acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or other disposition of oil and gas properties are generally treated as a reduction in the capitalized costs of oil and gas properties, unless the impact of such a reduction would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.

The Company categorizes its full cost pools as costs subject to amortization and costs not being amortized. The sum of net capitalized costs subject to amortization, including estimated future development and abandonment costs, are amortized using the unit-of-production method.

Oil and gas properties include costs that are excluded from capitalized costs being amortized. These amounts represent costs of investments in unproved properties. The Company excludes these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. All costs excluded are reviewed annually to determine if impairment has occurred. The amount of any impairment is transferred to the costs subject to amortization.

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- Definition

Disclosure of accounting policy for oil and gas property which may include the basis of such assets, depreciation methods used and estimated useful lives, the entity's capitalization policy, including its accounting treatment for costs incurred for repairs and maintenance activities, whether such asset balances include capitalized interest and the method by which such is calculated, how disposals of such assets are accounted for and how impairment of such assets is assessed and recognized.

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Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

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-SubTopic 10

-Section 50

-Paragraph 3

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Note 5 - Accrued Lease Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Accrued lease liabilities	$ 65,881us-gaap_DebtAndCapitalLeaseObligations	$ 65,881us-gaap_DebtAndCapitalLeaseObligations
KADs Oil, Inc.
Accrued lease liabilities	50,000	50,000
Other
Accrued lease liabilities	$ 15,881	$ 15,881

Note 1 - Business and Organization (Details)	12 Months Ended
Note 1 - Business and Organization (Details)	Dec. 31, 2014
Details
Entity Incorporation, State Country Name	Nevada
Entity Incorporation, Date of Incorporation	Jan. 12, 2011

Note 2 - Summary of Significant Accounting Policies: Income Taxes (Details) (USD $)	Dec. 31, 2014
Details
Operating Loss Carryforwards	$ 800,000us-gaap_OperatingLossCarryforwards

Note 4 - Oil and Gas Properties, Full Cost Method (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Total	$ 1,395,848	$ 1,147,590
Costs subject to amortization		1,147,903
Development Costs, Period Cost	235,263us-gaap_DevelopmentCosts	440,379us-gaap_DevelopmentCosts
Impairment of oil and gas properties		1,238,887us-gaap_ImpairmentOfOilAndGasProperties
Hicks
Payments to acquire leases	6,133
Cormwell
Payments to acquire leases	8,720
Wadlington
Payments to acquire leases	$ 11,083

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current Assets
Cash	$ 92,426us-gaap_Cash	$ 50,924us-gaap_Cash
Inventory		1,013us-gaap_InventoryNet
Accounts receivable	5,369us-gaap_AccountsReceivableNet
Total current assets	97,795us-gaap_AssetsCurrent	51,937us-gaap_AssetsCurrent
Oil and gas properties, full cost method
Costs subject to amortization		1,147,903
Costs not being amortized	1,398,782
Accumulated depletion, depreciation and amortization	(2,934)	(313)
Total oil and gas properties, full cost method	1,395,848	1,147,590
Total assets	1,493,643us-gaap_Assets	1,199,527us-gaap_Assets
Current liabilities
Accounts payable and accrued liabilities	110,521	123,050
Common stock payable	40,000fil_CommonStockPayable
Accrued lease liabilities	65,881us-gaap_DebtAndCapitalLeaseObligations	65,881us-gaap_DebtAndCapitalLeaseObligations
Total current liabilities	216,402us-gaap_LiabilitiesCurrent	188,931us-gaap_LiabilitiesCurrent
Asset retirement obligations	44,282us-gaap_AssetRetirementObligation	25,844us-gaap_AssetRetirementObligation
Total liabilities	260,684us-gaap_Liabilities	214,775us-gaap_Liabilities
Commitments and contingencies
Shareholders' equity
Common stock, $0.00001 par value, 100,000,000 shares authorized, 6,467,065 and 6,179,265 shares issued, respectively	65us-gaap_CommonStockValue	62us-gaap_CommonStockValue
Additional paid-in capital	2,986,107us-gaap_AdditionalPaidInCapital	2,410,510us-gaap_AdditionalPaidInCapital
Accumulated deficit	(1,753,213)	(1,425,820)
Total shareholders' equity	1,232,959us-gaap_StockholdersEquity	984,752us-gaap_StockholdersEquity
Total liabilities and shareholders' equity	$ 1,493,643	$ 1,199,527

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	Dec. 31, 2014	Dec. 31, 2013
Cash Flows From Operating Activities:
Net loss	$ (327,393)us-gaap_NetIncomeLoss	$ (1,567,380)us-gaap_NetIncomeLoss
Adjustments to reconcile net loss to net cash from operating activities:
Depletion, accretion and impairment expense	5,443	1,251,581
Changes in operating assets and liabilities:
Change in Accounts receivable	(5,369)
Change in Inventory	1,013fil_IncreaseDecreaseInInventory	(1,013)fil_IncreaseDecreaseInInventory
Change in Accounts payable and accrued liabilities	43,403	18,693
Net Cash Used in Operating Activities	(282,903)	(298,119)
Cash Flows From Investing Activities:
Payments for proved oil and gas properties	(291,195)	(364,338)
Net cash used in investing activities	(291,195)	(364,338)
Cash Flows From Financing Activities:
Capital contributions	0	18,351
Proceeds from sale of common stock	615,600	695,030
Net Cash Provided by Financing Activities	615,600	713,381
Net increase in cash	41,502	50,924
Cash at beginning of year	50,924us-gaap_Cash
Cash at end of year	92,426us-gaap_Cash	50,924us-gaap_Cash
Supplemental Cash Flow Information
Cash paid for interest		686us-gaap_InterestPaid
Cash paid for income taxes
Noncash investing activities:
Asset retirement cost	15,616	2,509
Payable for purchase of oil and gas properties	$ 55,932	$ 76,041

Note 7 - Equity (Details) (USD $)	12 Months Ended
Note 7 - Equity (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Issuance of common stock for cash	$ 575,600fil_IssuanceOfCommonStockForCash	$ 695,030fil_IssuanceOfCommonStockForCash
Common stock payable	40,000fil_CommonStockPayable
Common Stock Payable (shares)	20,000fil_CommonStockPayableShares
Common Stock
Issuance of common stock for cash (shares)	287,800	348,265
Issuance of common stock for cash	$ 3	$ 4

Note 8 - Related Party Transactions (Details) (USD $)	12 Months Ended
Note 8 - Related Party Transactions (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Details
Capital contributions	$ 0	$ 18,351

CONSOLIDATED BALANCE SHEETS PARENTHETICAL (USD $)	Dec. 31, 2014	Dec. 31, 2013
CONSOLIDATED BALANCE SHEETS PARENTHETICAL
Common stock par value	$ 0.00001	$ 0.00001
Common stock shares authorized	100,000,000us-gaap_CommonStockSharesAuthorized	100,000,000us-gaap_CommonStockSharesAuthorized
Common stock shares issued	6,467,065us-gaap_CommonStockSharesIssued	6,179,265us-gaap_CommonStockSharesIssued
Common stock shares outstanding	6,467,065us-gaap_CommonStockSharesOutstanding	6,179,265us-gaap_CommonStockSharesOutstanding

Document and Entity Information (USD $)	12 Months Ended
Document and Entity Information (USD $)	Dec. 31, 2014	Apr. 14, 2015	Jun. 30, 2014
Document and Entity Information:
Entity Registrant Name	NORTH TEXAS ENERGY, INC.
Document Type	10-K
Document Period End Date	Dec. 31, 2014
Amendment Flag	false
Entity Central Index Key	0001514994
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		6,519,815dei_EntityCommonStockSharesOutstanding
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Entity Incorporation, State Country Name	Nevada
Entity Incorporation, Date of Incorporation	Jan. 12, 2011
Entity Public Float			$ 0dei_EntityPublicFloat

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	Dec. 31, 2014	Dec. 31, 2013
CONSOLIDATED STATEMENTS OF OPERATIONS
Revenues	$ 70,615us-gaap_Revenues
Lease operating expense	96,856us-gaap_LeaseOperatingExpense
Depletion and accretion	5,443	12,381
Impairment of oil and gas properties		1,238,887us-gaap_ImpairmentOfOilAndGasProperties
Legal and professional fees	88,916us-gaap_ProfessionalFees	145,204us-gaap_ProfessionalFees
General and administrative expenses	206,793us-gaap_GeneralAndAdministrativeExpense	170,222us-gaap_GeneralAndAdministrativeExpense
Total operating expenses	398,008us-gaap_OperatingExpenses	1,566,694us-gaap_OperatingExpenses
Net operating loss	(327,393)us-gaap_OperatingIncomeLoss	(1,566,694)us-gaap_OperatingIncomeLoss
Interest expense		(686)us-gaap_InterestExpense
Net loss	$ (327,393)us-gaap_NetIncomeLoss	$ (1,567,380)us-gaap_NetIncomeLoss
Basic and Diluted Loss Per Common Share	$ (0.05)us-gaap_EarningsPerShareBasicAndDiluted	$ (0.26)us-gaap_EarningsPerShareBasicAndDiluted
Weighted average number of common shares outstanding - basic and diluted	6,328,533	5,976,117

Note 6 - Asset Retirement Obligations: Schedule of Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Details
Asset retirement obligations	$ 44,282us-gaap_AssetRetirementObligation	$ 25,844us-gaap_AssetRetirementObligation	$ 54,709us-gaap_AssetRetirementObligation
Asset Retirement Obligation, Revision of Estimate	(2,645)	(2,509)
Asset Retirement Obligation, Addition	18,260
Disposal of leases		(38,737)fil_DisposalOfLeases
Asset retirement cost	$ 2,823	$ 12,381

Consolidated Statements of Stockholders' Equity (Deficit) (USD $)	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Total
Balance at Dec. 31, 2012	$ 58	$ 1,697,133	$ 141,560	$ 1,838,751us-gaap_StockholdersEquity
Balance (Shares) at Dec. 31, 2012	5,831,000
Capital contributions		18,351		18,351
Issuance of common stock for cash	4	695,026		695,030fil_IssuanceOfCommonStockForCash
Issuance of common stock for cash (shares)	348,265
Net loss			(1,567,380)	(1,567,380)us-gaap_NetIncomeLoss
Balance at Dec. 31, 2013	62	2,410,510	(1,425,820)	984,752us-gaap_StockholdersEquity
Balance (Shares) at Dec. 31, 2013	6,179,265
Capital contributions				0
Issuance of common stock for cash	3	575,597		575,600fil_IssuanceOfCommonStockForCash
Issuance of common stock for cash (shares)	287,800
Net loss			(327,393)	(327,393)us-gaap_NetIncomeLoss
Balance at Dec. 31, 2014	$ 65	$ 2,986,107	$ (1,753,213)	$ 1,232,959us-gaap_StockholdersEquity
Balance (Shares) at Dec. 31, 2014	6,467,065