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 September 30, 2014

 

or

 

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

 

For the transition period from                     to                

 

Commission file number: 333-178437

 

West Texas Resources, Inc.

(Exact name of registrant as specified in its charter)

 

Nevada				99-0365272
(State or Other Jurisdiction of Incorporation or Organization)				(I.R.S. Employer Identification Number)

 

5729 Lebanon Road, Suite 144

Frisco, Texas  75034

(Address of principal executive offices)

 

(214) 868-3939

(Registrant’s telephone number, including area code)

 

 

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

 

None

 

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

 

None

 

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

 

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act. Yes o No  x

 

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 past 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No o

 

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 was required to submit and post such files). Yes  x  No  o

 

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

 

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company (as defined in Rule 12b-2 of the Act):

 

Large accelerated filer o		Accelerated filer o
Non-accelerated filer o		Smaller reporting company x
(Do not check if a smaller reporting company)

 

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

Yes  o  No  x

 

State the aggregate market value of voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second fiscal quarter: $5,593,280.

 

The number of shares of the registrant’s common stock outstanding as of January 12, 2014 was 14,415,400.

 

 

TABLE OF CONTENTS

 

				Page
		PART I
Item 1.		Business		1
Item 1A.		Risk Factors		11
Item 1B.		Unresolved Staff Comments		17
Item 2.		Properties		18
Item 3.		Legal Proceedings		21
Item 4.		Mine Safety Disclosures		21
		PART II
Item 5.		Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Repurchases of Equity Securities		22
Item 6.		Selected Financial Data		23
Item 7.		Management’s Discussion and Analysis of Financial Condition and Results of Operations		24
Item 7A.		Quantitative and Qualitative Disclosures About Market Risk		25
Item 8.		Financial Statements and Supplementary Data		26
Item 9.		Changes in and Disagreements with Accountants on Accounting and Financial Disclosure		27
Item 9A.		Controls and Procedures		27
Item 9B.		Other Information		27
		PART III
Item 10.		Directors, Executive Officers and Corporate Governance		28
Item 11.		Executive Compensation		29
Item 12.		Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters		31
Item 13.		Certain Relationships and Related Transactions and Director Independence		32
Item 14.		Principal Accountant Fees and Services		32
		PART IV
Item 15.		Exhibits and Financial Statement Schedules		33
Signatures				35

 

 

CAUTIONARY NOTICE

 

This annual report on Form 10-K contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Those forward-looking statements include our expectations, beliefs, intentions and strategies regarding the future. Such forward-looking statements relate to, among other things, our market, strategy, competition, development plans, financing, revenues, operations and compliance with applicable laws. These and other factors that may affect our financial results are discussed more fully in “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in this report. Market data used throughout this report is based on published third party reports or the good faith estimates of management, which estimates are presumably based upon their review of internal surveys, independent industry publications and other publicly available information. Although we believe that such sources are reliable, we do not guarantee the accuracy or completeness of this information, and we have not independently verified such information. We caution readers not to place undue reliance on any forward-looking statements. We do not undertake, and specifically disclaim any obligation, to update or revise such statements to reflect new circumstances or unanticipated events as they occur, and we urge readers to review and consider disclosures we make in this and other reports that discuss factors germane to our business. See in particular our reports on Forms 10-K, 10-Q, and 8-K subsequently filed from time to time with the Securities and Exchange Commission.

 

PART I

 

Item 1.

Business

 

Overview

 

West Texas Resources, Inc. (the “company” or “we”) was incorporated under the laws of Nevada on December 9, 2010. We are engaged in the business of oil and gas exploration and development in North America. From inception to date, our activities have focused on the raising of capital and the investigation and acquisition of our initial oil and gas properties. We commenced revenue producing oil and gas operations effective as of April 1, 2013.

 

Our Strategy

 

Our objective is to become an independent energy company engaged in the acquisition, development and exploitation of oil and gas properties in North America in partnership with oil and gas producers. We will pursue strategic acquisitions of interests in oil and gas properties, including prospects with proven and unproven reserves, which we believe to have development potential. We intend to target both new and existing fields and producing wells to be revitalized.

 

At the present time, we have two employees, our chief executive officer and chief financial officer, Stephen Jones and John Kerr, respectively, each of whom has limited experience in the oil and gas exploration and development business. Subject to our receipt of significant additional capital, we intend to hire senior management and staff with experience in oil and gas exploration and development. Until such time, we intend to pursue an operating strategy that is based on our participation in exploration prospects as a non-operator. Based on that strategy, we intend to pursue the acquisition of oil and natural gas interests in partnership with other companies with exploration, development and production expertise. We will also pursue alliances with partners in the areas of geological and geophysical services and prospect generation, evaluation and prospect leasing. Pursuant to this strategy, we intend to engage and rely on third party geologists and geophysicists, among others, to review the available data concerning each potential acquisition on our behalf. In each case, we expect that the operator of the prospect will assemble the appropriate data and conduct the appropriate studies and that our consultants will conduct an independent review of the operator’s data and studies for purposes of advising us of the merits of each potential acquisition.

 

 

Oil and Gas Interests

 

Port Hudson Field

 

We own a 4.0506% working interest (3.1595% net revenue interest) in the oil and gas leases, wells and attendant production in the Port Hudson field, Baton Rouge Parish, Louisiana. Our acquisition of the Port Hudson working interest was effective as of April 1, 2013. Accordingly, we have received revenue from the Port Hudson working interest commencing on April 1, 2013. The Port Hudson field has three producing wells that have produced a total of 1.29 million bbls as of September 30, 2014 with estimated total remaining recoverable proved developed producing reserves of 449,000 bbls (14,186 bbls net to West Texas Resources), and 26,000 bbls of proven developed behind pipe reserves (821 bbls net to West Texas Resources) and are currently producing approximately 260 bbls per day. The operator of the Port Hudson field has no current plans for the further development of the property.

 

West Cam 225 Field

 

We own a 10.0167% working interest (7.2120% net revenue interest) in an offshore oil and gas field, known as West Cam 225, located in the shallow waters of the Gulf of Mexico near Cameron, Louisiana. As of September 30, 2014, the West Cam 225 field had proven reserves of 8,996 mmcf of gas or 1,499 mboes (108,131 equivalent bbls net to West Texas Resources) and has two producing wells, the #7 and the D-1, that were previously shut-in and waiting on a sales pipeline connection. The pipeline was completed and tested in August 2013 and now the two wells are currently producing intermittently at a combined gross rate of 1.6 mmcfd. As of September 30, 2014, the D-1 well has overproduced its expected recoverable reserves in its original completion in the 6,800’ sand and is currently producing at a high water cut. The operator presently intends to perform a recompletion on the D-1 well in the second quarter of 2015, at which time the D-1 well will be recompleted uphole into the 5,900’ sand and is expected to produce at a combined rate of 5.5 mmcfd, including the #7 well, and thereby provide access to 7.93 bcf of gross proved behind pipe reserves.

 

Wolfcamp Field

 

We hold non-operating leases covering approximately 1,070 gross mineral acre leases in the Wolfcamp field located in Hale County, Texas. The leases have a primary term of five years with our option to extend the term for another five years. The leased properties are a natural gas prospect, for which we hold 50% of the working interest and a 40% net revenue interest. The leased properties are subject to a 20% royalties held by the owners and a third party. We are currently evaluating our options for the exploitation of the leased properties, including our sale of the leases or our farm-out of the leases to a natural gas operator.

 

Sunshine Prospect

 

We hold a 15% (14.25% net revenue interest) in a non-operating oil and gas prospect located in Landry Parish, Louisiana. The working interest concerns 248 gross acres and net acres in the Sunshine Prospect. The operator intends to drill an initial well in the prospect in 2015.

 

Stansell Field

 

We hold a 1% working interest in an oil prospect located in Floyd County, Texas. The working interest comprises 15,000 leased acres in the southern section of the Palo Duro basin. The initial project will be the re-entry of the Stansell #1-A well, an existing well bore that was drilled in 2006. The original drilling encountered oil shows in three separate reservoirs and the operator intends to re-enter and recomplete the Stansell #1-A using current fracture stimulation technology. We have a carried 1% working interest in the Stansell #1-A well through the tanks. The operator plans to commence the re-entry of the Stansell #1-A well in December 2014.

 

Subject to our receipt of additional capital, we intend to pursue the acquisition of additional equity interests in other oil and gas properties in North America. However, as of the date of this report, we have no understandings or agreements in place concerning our acquisition of an interest in any other properties. 

 

 

Marketing and Pricing

 

We derive revenue principally from the sale of oil and natural gas. As a result, our revenues are determined, to a large degree, by prevailing prices for crude oil and natural gas. Our operating partners sell our oil and natural gas on the open market at prevailing market prices. The market price for oil and natural gas is dictated by supply and demand, and we cannot accurately predict or control the price we may receive for our oil and natural gas.

 

Price decreases would adversely affect our revenues, profits and the value of our proved reserves. Historically, the prices received for oil and natural gas have fluctuated widely. Among the factors that can cause these fluctuations are:

 

●

The domestic and foreign supply of natural gas and oil

 

●

Overall economic conditions

 

●

The level of consumer product demand

 

●

Weather conditions

 

●

The price and availability of competitive fuels such as heating oil and coal

 

●

Political conditions in the Middle East and other natural gas and oil producing regions

 

●

The level of oil and natural gas imports

 

●

Domestic and foreign governmental regulations

 

●

Potential price controls

 

We may enter into hedging arrangements to reduce our exposure to decreases in the prices of oil and natural gas. Hedging arrangements may expose us to risk of significant financial loss in some circumstances including circumstances where:

 

●

There is a change in the expected differential between the underlying price in the hedging agreement and actual prices received

 

●

Our production and/or sales of natural gas are less than expected

 

●

Payments owed under derivative hedging contracts typically come due prior to receipt of the hedged month’s production revenue

 

●

The other party to the hedging contract defaults on its contract obligations

 

In addition, hedging arrangements limit the benefit we would receive from increases in the prices for oil and natural gas. We cannot assure you that any hedging transactions we may enter into will adequately protect us from declines in the prices of oil and natural gas. On the other hand, we may choose not to engage in hedging transactions in the future. As a result, we may be more adversely affected by changes in oil and natural gas prices than our competitors who engage in hedging transactions.

 

Competition

 

The oil and gas industry is highly competitive and inherent difficulties exist for any new company seeking to enter an established field. Our proposed business will encounter numerous companies more experienced, better financed, and operationally organized to conduct acquisitions, development and exploration activities in the oil and gas industry in North America. Additionally, a small “start-up” such as us, with insignificant resources, is at a serious disadvantage against established competitors, including major oil companies.

 

 

Government Regulations

 

The following is a summary of the more significant existing environmental, health and safety laws and regulations applicable to the oil and natural gas industry and for which compliance may have a material adverse impact on the development or success of our proposed oil and gas operations.

 

Federal Income Tax. Federal income tax laws will significantly affect our operations. The principal provisions that will affect us are those that permit us, subject to certain limitations, to deduct as incurred, rather than to capitalize and amortize, our share of the domestic “intangible drilling and development costs” and to claim depletion on a portion of our domestic oil and natural gas properties based on 15% of our oil and natural gas gross income from such properties (up to an aggregate of 1,000 Bbls per day of domestic crude oil and/or equivalent units of domestic natural gas).

 

Environmental Regulation.  The exploration, development and production of oil and natural gas are subject to federal, state and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may, among other things, require permits to conduct drilling, water withdrawal and waste disposal operations; govern the amounts and types of substances that may be disposed or released into the environment; limit or prohibit construction or drilling activities in sensitive areas such as wetlands, wilderness areas or areas inhabited by endangered or threatened species; require investigatory and remedial actions to mitigate pollution conditions arising from oil and gas operations or attributable to former operations; and impose obligations to reclaim and abandon well sites and pits. Failure to comply with these laws and regulations may result in the assessment of sanctions, including monetary penalties, the imposition of remedial obligations and the issuance of orders enjoining operations in affected areas.

 

The clear trend in environmental regulation is to place more restrictions and limitations on activities that may affect the environment, and thus, any changes in environmental laws and regulations or re-interpretation of enforcement policies that result in more stringent and costly construction, drilling, water management, completion, waste handling, storage, transport, disposal, or remediation requirements or emission or discharge limits could have a material adverse effect on the development or success of our proposed oil and gas operations. Moreover, accidental releases or spills may occur in the course of our proposed oil and gas operations, and there can be no assurance that we will not incur significant costs and liabilities as a result of such releases or spills, including any third party claims for damage to property and natural resources or personal injury.

 

Hazardous Substances and Wastes.  The Comprehensive Environmental Response, Compensation and Liability Act, as amended ("CERCLA"), also known as the Superfund law and comparable state laws impose joint and several liability, without regard to fault or legality of conduct, on certain classes of persons who are considered to be responsible for the release of a "hazardous substance" into the environment. These persons include current and prior owners or operators of the site where the release occurred and entities that disposed or arranged for the disposal of the hazardous substances found at the site. Under CERCLA, these "responsible persons" may be subject to strict joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain environmental and health studies. In addition, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances into the environment. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. We may generate materials in the course of our proposed operations that may be regulated as hazardous substances.

 

We may also generate wastes that are subject to the requirements of the Resource Conservation and Recovery Act, as amended ("RCRA"), and comparable state statutes. RCRA imposes strict requirements on the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous wastes. Drilling fluids, produced waters and most of the other wastes associated with the exploration, production and development of crude oil and natural gas are currently exempt from regulation as hazardous wastes under RCRA.  However, it is possible that certain oil and natural gas exploration and production wastes now classified as non-hazardous could be classified as hazardous wastes in the future. In September 2010, the Natural Resources Defense Council filed a petition with the EPA requesting them to reconsider the RCRA exemption for exploration, production, and development wastes. To date, the EPA has not taken any action on the petition. Any change in the RCRA exemption for such wastes could result in an increase in costs to manage and dispose of wastes, which could have a material adverse effect on the development or success of our proposed oil and gas operations.

 

 

Air Emissions. The Clean Air Act, as amended, and comparable state laws and regulations restrict the emission of air pollutants from many sources and also impose various monitoring and reporting requirements. These laws and regulations may require our operating partners to obtain pre-approval for the construction or modification of certain projects or facilities expected to produce or significantly increase air emissions, obtain and strictly comply with air permit requirements or utilize specific equipment or technologies to control emissions. Obtaining permits has the potential to delay the development of oil and natural gas projects.

 

Water Discharges. The Federal Water Pollution Control Act, as amended ("Clean Water Act"), and analogous state laws impose restrictions and strict controls regarding the discharge of pollutants into navigable waters. Pursuant to the Clean Water Act and analogous state laws, permits must be obtained to discharge produced waters and sand, drilling fluids, drill cuttings and other substances related to the oil and gas industry into onshore, coastal and offshore waters of the United States or state waters. Any such discharge of pollutants into regulated waters must be performed in accordance with the terms of the permit issued by EPA or the analogous state agency. Spill prevention, control and countermeasure requirements under federal law require appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture or leak. In addition, the Clean Water Act and analogous state laws require individual permits or coverage under general permits for discharges of storm water runoff from certain types of facilities.

 

Climate Change. In December 2009, the EPA published its findings that emissions of carbon dioxide, methane and certain other GHGs present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth's atmosphere and other climatic changes. These findings allow the EPA to adopt and implement regulations that restrict emissions of GHGs under existing provisions of the federal Clean Air Act. Accordingly, the EPA has adopted regulations that require a reduction in emissions of GHGs from motor vehicles and also trigger permit review for GHG emissions from certain large stationary sources. The EPA's rules relating to emissions of GHGs from large stationary sources of emissions are currently subject to a number of legal challenges, but the federal courts have thus far declined to issue any injunctions to prevent the EPA from implementing, or requiring state environmental agencies to implement, the rules. In addition, Congress has actively considered legislation to reduce emissions of GHGs and almost one-half of the states have begun taking actions to control and/or reduce emissions of GHGs, primarily through the planned development of GHG emission inventories and/or regional GHG cap and trade programs. The adoption and implementation of any regulations imposing reporting obligations on, or limiting emissions of GHG gases from, our equipment and operations could require our operators to incur costs to reduce emissions of GHGs associated with our proposed operations or could adversely affect demand for the oil and natural gas we produce.

 

Endangered Species. The federal Endangered Species Act ("ESA") restricts activities that may affect endangered or threatened species or their habitats.  The designation of previously unidentified species as endangered or threatened on properties where we operate could subject us to additional costs or cause our oil and gas activities to be subject to operating restrictions or bans.

 

Employee Health and Safety. Our proposed operations are subject to a number of federal and state laws and regulations, including the federal Occupational Safety and Health Act, as amended ("OSHA"), and comparable state statutes, whose purpose is to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of the federal Superfund Amendment and Reauthorization Act and comparable state statutes require that information be maintained concerning hazardous materials used or produced in oil and gas operations and that this information be provided to employees, state and local government authorities and citizens.

 

State Regulation. Texas regulates the drilling for, and the production and gathering of, oil, natural gas and natural gas liquids, including requirements relating to drilling permits, the location, spacing and density of wells, unitization and pooling of interests, the method of drilling, casing and equipping of wells, the protection of fresh water sources, the orderly development of common sources of supply of oil, natural gas and natural gas liquids, the operation of wells, allowable rates of production, the use of fresh water in oil, natural gas and natural gas liquids operations, saltwater injection and disposal operations, the plugging and abandonment of wells and the restoration of surface properties, the prevention of waste of oil, natural gas and natural gas liquids resources, the protection of the correlative rights of oil, natural gas and natural gas liquids owners and, where necessary to avoid unfair, unjust or discriminatory service, the fees, terms and conditions for the gathering of natural gas. The effect of these regulations may be to limit the number of wells that our operating partners may drill, impact the locations at which our operating partners may drill wells, restrict the amounts of oil and natural gas that may be produced from wells drilled by our operating partners and increase the costs of operations.

 

 

Hydraulic Fracturing. We expect to participate in exploration and drilling projects that seek to recover oil and natural gas through the use of hydraulic fracturing.  Hydraulic fracturing, which involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production, is typically regulated by state oil and gas commissions. However, the EPA recently asserted federal regulatory authority over certain hydraulic fracturing practices. Also, legislation has been introduced in Congress to provide for federal regulation of hydraulic fracturing and to require disclosure of the chemicals used in the fracturing process. In addition, some states have adopted, and other states are considering adopting, regulations that could restrict hydraulic fracturing in certain circumstances. For instance, in June 2011, Texas adopted a law that requires disclosure to the Railroad Commission of Texas of the additives and other chemicals contained in hydraulic fracturing fluids used in the state, subject to certain trade secret protections. If new laws or regulations that significantly restrict hydraulic fracturing are adopted at the Texas state level, such legal requirements could make it more difficult or costly for our operating partners to perform fracturing to stimulate production in the play and thereby affect the determination of whether a well is commercially viable. In addition, if hydraulic fracturing is regulated at the federal level, fracturing activities could become subject to additional permit requirements or operational restrictions and also to associated permitting delays and potential increases in costs. Restrictions on hydraulic fracturing could also reduce the amount of oil or natural gas and natural gas liquids that our operating partners are ultimately able to produce in commercial quantities from our oil and gas properties.

 

Employees

 

As of the date of this report, we have two employees, our chief executive officer and chief financial officer. For the foreseeable future, we intend to use the services of independent consultants and contractors to perform various professional services related to our oil and gas operations. Subject to our receipt of significant additional capital, we intend to hire senior management and staff with experience in oil and gas exploration and development.  Until such time, we intend to rely on third party consultants to advise and assist us on our oil and gas operations.

 

Available Information

 

Our website is located at www.westtexasresources.com. The information on or accessible through our website is not part of this annual report on Form 10-K. A copy of this annual report on Form 10-K is located at the SEC’s Public Reference Room at 100 F Street, NE, Washington, D.C. 20549. Information on the operation of the Public Reference Room can be obtained by calling the SEC at 1-800-SEC-0330. The SEC also maintains an internet site that contains reports and other information regarding our filings at www.sec.gov.

 

Glossary of Oil and Natural Gas Terms

 

The following is a description of the meanings of some of the oil and natural gas industry terms used in this report.

 

bbl. Stock tank barrel, or 42 U.S. gallons liquid volume, used in this report in reference to crude oil or other liquid hydrocarbons.

 

bcf. Billion cubic feet of natural gas.

 

boe. Barrels of crude oil equivalent, determined using the ratio of six mcf of natural gas to one bbl of crude oil, condensate or natural gas liquids.

 

 

boe/d. boe per day.

 

btu. The British thermal unit, a traditional unit of energy equal to about 1055 joules. It is the amount of energy needed to cool or heat one pound of water by one degree Fahrenheit (Physical analogue; one four inch, wooden kitchen match consumed completely generates 1 btu).

 

Completion. The process of treating a drilled well followed by the installation of permanent equipment for the production of natural gas or oil, or in the case of a dry hole, the reporting of abandonment to the appropriate agency.

 

Condensate. Hydrocarbons which are in the gaseous state under reservoir conditions and which become liquid when temperature or pressure is reduced. A mixture of pentanes and higher hydrocarbons.

 

Development well. A well drilled within the proved area of a natural gas or oil reservoir to the depth of a stratigraphic horizon known to be productive.

 

Drilling locations. Total gross locations specifically quantified by management to be included in the Company’s multi-year drilling activities on existing acreage. The Company’s actual drilling activities may change depending on the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, drilling results and other factors.

 

Dry hole. A well found to be incapable of producing either oil or gas in sufficient quantities to justify completion as an oil or gas well.

 

Exploratory well. A well drilled to find and produce natural gas or oil reserves not classified as proved, to find a new reservoir in a field previously found to be productive of natural gas or oil in another reservoir or to extend a known reservoir.

 

Field. An area consisting of either a single reservoir or multiple reservoirs, all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.

 

Formation. An identifiable layer of rocks named after its geographical location and dominant rock type.

 

Fracture or fracturing. Hydraulic fracturing, a common practice that is used to stimulate production of oil and natural gas from dense subsurface rock formations. The hydraulic fracturing process involves the injection of water, sand and chemicals under pressure into a formation to fracture the surrounding rock and stimulate production.

 

Lease. A legal contract that specifies the terms of the business relationship between an energy company and a landowner or mineral rights holder on a particular tract of land and typically grants to the energy company a fee simple determinable estate in the minerals.

 

Leasehold. Mineral rights leased in a certain area to form a project area.

 

mbbls. Thousand barrels of crude oil or other liquid hydrocarbons.

 

mboe. Thousand barrels of crude oil equivalent, determined using the ratio of six mcf of natural gas to one bbl of crude oil, condensate or natural gas liquids

 

mcf. Thousand cubic feet of natural gas.

 

mcfe. Thousand cubic feet equivalent, determined using the ratio of six mcf of natural gas to one bbl of crude oil, condensate or natural gas liquids.

 

 

mmbbls. Million barrels of crude oil or other liquid hydrocarbons.

 

mmboe. Million barrels of crude oil equivalent, determined using the ratio of six mcf of natural gas to one bbl of crude oil, condensate or natural gas liquids.

 

mmbtu. Million British Thermal Units.

 

mmcf. Million cubic feet of natural gas.

 

Net acres, net wells, or net reserves. The sum of the fractional working interest owned in gross acres, gross wells, or gross reserves, as the case may be.

 

ngl. Natural gas liquids, or liquid hydrocarbons found in association with natural gas.

 

Overriding royalty interest. Is similar to a basic royalty interest except that it is created out of the working interest. For example, an operator possesses a standard lease providing for a basic royalty to the lessor or mineral rights owner of 1/8 of 8/8. This then entitles the operator to retain 7/8 of the total oil and natural gas produced. The 7/8 in this case is the 100% working interest the operator owns. This operator may assign his working interest to another operator subject to a retained 1/8 overriding royalty. This would then result in a basic royalty of 1/8, an overriding royalty of 1/8 and a working interest of 3/4. Overriding royalty interest owners have no obligation or responsibility for developing and operating the property. The only expenses borne by the overriding royalty owner are a share of the production or severance taxes and sometimes costs incurred to make the oil or gas salable.

 

Plugging and abandonment. Refers to the sealing off of fluids in the strata penetrated by a well so that the fluids from one stratum will not escape into another or to the surface. Regulations of all states require plugging of abandoned wells.

 

Present value of future net revenues (PV-10). The present value of estimated future revenues to be generated from the production of proved reserves, before income taxes, of proved reserves calculated in accordance with Financial Accounting Standards Board guidelines, net of estimated production and future development costs, using prices and costs as of the date of estimation without future escalation, without giving effect to hedging activities, non-property related expenses such a general and administrative expenses, debt service and depreciation, depletion and amortization, and discounted using an annual discount rate of 10%.

 

Production. Natural resources, such as oil or gas, taken out of the ground.

 

Proved oil and gas reserves. Proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be economically recoverable in future years from known reservoirs under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

 

(i)

Reservoirs are considered proved if economic producibility is supported by either actual production or conclusive formation test. The area of a reservoir considered proved includes (A) that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any; and (B) the immediately adjoining portions not yet drilled, but which can be reasonably judged as economically productive on the basis of available geological and engineering data. In the absence of information on fluid contacts, the lowest known structural occurrence of hydrocarbons controls the lower proved limit of the reservoir.

 

(ii)

Reserves which can be produced economically through application of improved recovery techniques (such as fluid injection) are included in the "proved" classification when successful testing by a pilot project, or the operation of an installed program in the reservoir, provides support for the engineering analysis on which the project or program was based.

 

 

(iii)

Estimates of proved reserves do not include the following: (A) oil that may become available from known reservoirs but is classified separately as "indicated additional reserves"; (B) crude oil, natural gas, and natural gas liquids, the recovery of which is subject to reasonable doubt because of uncertainty as to geology, reservoir characteristics, or economic factors; C) crude oil, natural gas, and natural gas liquids, that may occur in undrilled prospects; and (D) crude oil, natural gas, and natural gas liquids, that may be recovered from oil shales, coal, gilscnite, and other such sources.

 

Proved developed oil and gas reserves. Proved developed oil and gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. Additional oil and gas expected to be obtained through the application of fluid injection or other improved recovery techniques for supplementing the natural forces and mechanisms of primary recovery should be included as "proved developed reserves" only after testing by a pilot project or after the operation of an installed program has confirmed through production response that increased recovery will be achieved.

 

Proved undeveloped reserves. Proved undeveloped oil and gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Reserves on undrilled acreage shall be limited to those drilling units offsetting productive units that are reasonably certain of production when drilled. Proved reserves for other undrilled units can be claimed only where it can be demonstrated with certainty that there is continuity of production from the existing productive formation. Under no circumstances should estimates for proved undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual tests in the area and in the same reservoir.

 

Productive well. A well that is found to be capable of producing either oil or gas in sufficient quantities to justify completion as an oil or gas well.

 

Project. A targeted development area where it is probable that oil or natural gas can be produced from new wells.

 

Prospect. A specific geographic area which, based on supporting geological, geophysical or other data and also preliminary economic analysis using reasonably anticipated prices and costs, is deemed to have potential for the discovery of commercial hydrocarbons.

 

Recompletion. The process of re-entering an existing well bore that is either producing or not producing and completing new reservoirs in an attempt to establish or increase existing production.

 

Reserves. Oil, natural gas and gas liquids thought to be accumulated in known reservoirs.

 

Reservoir. A porous and permeable underground formation containing a natural accumulation of producible nature gas and/or oil that is confined by impermeable rock or water barriers and is separate from other reservoirs.

 

Secondary Recovery. A recovery process that uses mechanisms other than the natural pressure of the reservoir, such as gas injection or water flooding, to produce residual oil and natural gas remaining after the primary recovery phase.

 

Shut-in. A well that has been capped (having the valves locked shut) for an undetermined amount of time. This could be for additional testing, could be to wait for pipeline or processing facility, or a number of other reasons.

 

Standardized measure. The present value of estimated future cash inflows from proved oil and natural gas reserves, less future development, abandonment, production and income tax expenses, discounted at 10% per annum to reflect timing of future cash flows and using the same pricing assumptions as were used to calculate PV-10. Standardized measure differs from PV-10 because standardized measure includes the effect of future income taxes.

 

 

Successful. A well is determined to be successful if it is producing oil or natural gas, or awaiting hookup, but not abandoned or plugged.

 

Undeveloped acreage. Lease acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil and natural gas regardless of whether such acreage contains proved reserves.

 

Water flood. A method of secondary recovery in which water is injected into the reservoir formation to displace residual oil and enhance hydrocarbon recovery.

 

Working interest. The operating interest that gives the owner the right to drill, produce and conduct operating activities on the property and receive a share of production and requires the owner to pay a share of the costs of drilling and production operations.

 

 

Item 1A.

Risk Factors

 

There are numerous and varied risks, known and unknown, that may prevent us from achieving our goals. If any of these risks actually occur, our business, financial condition or results of operation may be materially adversely affected. In such case, the trading price of our common stock could decline and investors could lose all or part of their investment.

 

We are an early stage company and have limited assets. We were formed in 2010 and commenced revenue producing oil and gas operations effective as of April 1, 2013. As an early stage company, we are subject to all risks inherent in a new venture. The likelihood of our success must be considered in light of problems, expenses, complications and delays frequently encountered in connection with the development of a new business. We do not have a significant operating history and, as a result, there is a limited amount of information about us on which to make an investment decision.

 

We will require additional capital in order to achieve commercial success and, if necessary, to finance future losses from operations as we endeavor to build revenue, but we do not have any commitments to obtain such capital. The business of oil and gas acquisition, drilling and development is capital intensive and the level of operations attainable by an oil and gas company is directly linked to and limited by the amount of available capital. As of September 30, 2014, we had total current assets of $189,561 and a working capital deficit of $(272,849). We believe that our ability to achieve commercial success and our continued growth will be dependent on our ability to access capital either through the additional sale of our equity or debt securities, bank lines of credit, project financing or cash generated from oil and gas operations. Therefore, a principal part of our plan of operations is to acquire the additional capital required to finance the acquisition of such properties and our share of the development costs. We will seek additional working capital through the sale of our securities and, subject to the successful deployment of our cash on hand, we will endeavor to obtain additional capital through bank lines of credit and project financing. However, as of the date of this report, we have no commitments for the sale of our securities or our acquisition of additional capital through any other means nor can there be any assurance that any funds will be available on commercially reasonable terms, if at all.

 

The report of our independent registered public accounting firm for the fiscal year ended September 30, 2014 states that due to our losses from operations and lack of working capital there is substantial doubt about our ability to continue as a going concern.

 

Market conditions for oil and natural gas, and particularly the recent decline in prices for oil and natural gas, could adversely affect our revenue, cash flows, profitability and growth. Our project revenue, cash flows, profitability and future rate of growth depend substantially upon prevailing prices for oil and natural gas.  Prices also affect the amount of cash flow available for capital expenditures and our ability to borrow money or raise additional capital. Lower prices may also make it uneconomical for our operating partners to commence or continue production levels of natural gas and crude oil. Over the six months preceding the date of this report, the NYMEX settled prices for oil and natural gas have decreased by approximately 50%. For example, during 2013 and 2014, the price of oil per bbl was consistently in the range of $85 to $90 per bbl, and hit a two year high of $101 per bbl on June 21, 2014. However, since then the prices of oil and natural gas have significantly decreased due to an over-supply and decreasing demand, and experts believe that the prices of oil and natural gas will stay suppressed for some time from the price levels experienced during the last few years.

 

Lower oil and natural gas prices will reduce our revenues and may ultimately reduce the amount of oil and natural gas that is economic to produce from our oil and gas properties. As a result, our operating partners could determine during periods of low oil and natural gas prices to shut in or curtail production from any operating wells. In addition, our operating partners could determine during periods of low oil and natural gas prices to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. Specifically, our operating partners may abandon any well or property if it reasonably believes that the well or property can no longer produce oil or natural gas in commercially economic quantities. This could result in termination of our portion of the royalty interest relating to the abandoned well or property.

 

 

Our management has limited experience in operating an oil and gas business. At the present time, we have two employees, our chief executive officer and our chief financial officer, Stephen Jones and John Kerr, respectively, who also serve as the sole members of our board of directors. Mr. Jones and Mr. Kerr each has limited experience in the oil and gas business. We intend to expand our management team and board of directors with personnel who have experience in the oil and gas business, however we have no agreements or understandings in place as of the date of this report concerning the appointment of any additional officers or directors. We do not expect to be able to attract senior management or directors with significant oil and gas experience until such time as we raise significant additional capital.   Until such time, if ever, as we do, the success of our company will be dependent on the decisions and actions undertaken by Mr. Jones and Mr. Kerr.

 

We have limited management and staff and will be dependent for the foreseeable future upon consultants and partnering arrangements. At the present time, we have two employees, our chief executive officer and our chief financial officer, Stephen Jones and John Kerr, respectively. We have developed an operating strategy that is based on our participation in exploration prospects in North America as a non-operator for the foreseeable future. We intend to use the services of independent consultants and contractors to perform various professional services, including reservoir engineering, land, legal, environmental and tax services. We will also pursue alliances with partners in the areas of geological and geophysical services and prospect generation, evaluation and prospect leasing. As a non-operator working interest owner, we intend to rely on outside operators to drill, produce and market our natural gas and oil. Our dependence on third party consultants, service providers and operators creates a number of risks, including but not limited to:

 

●

the possibility that such third parties may not be available to us  as and when needed; and

 

●

the risk that we may not be able to properly control the timing and quality of work conducted with respect to our projects.

 

Our estimated reserves and future production rates are based on many assumptions that may prove to be inaccurate. Any material inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our estimated reserves. We have obtained a reserve report as of September 30, 2014 prepared by Collarini Associates, of Houston, Texas. Numerous uncertainties are inherent in estimating quantities of oil and natural gas reserves and future production. It is not possible to measure underground accumulations of oil or natural gas in an exact way. Oil and natural gas reserve engineering is complex, requiring subjective estimates of underground accumulations of oil and natural gas and assumptions concerning future oil and natural gas and prices, future production levels and operating and development costs. In estimating our level of oil and natural gas reserves, Collarini Associates makes certain assumptions that may prove to be incorrect, including assumptions relating to:

 

·

the level of oil and natural gas prices;

·

future production levels;

·

capital expenditures;

·

operating and development costs;

·

the effects of regulation;

·

the accuracy and reliability of the underlying engineering and geologic data; and

·

the availability of funds.

 

If these assumptions prove to be incorrect, Collarini Associates’ estimates of our reserves, the economically recoverable quantities of oil and natural gas attributable to any particular group of properties, the classifications of reserves based on risk of recovery and our estimates of the future net cash flows from our estimated reserves could change significantly. Moreover, the variability is likely to be higher for probable and possible reserve estimates. The reserve estimates for wells or fields that do not have a lengthy production history are less reliable than estimates for wells or fields with lengthy production histories. A lack of production history may contribute to inaccuracy in the estimates of proved reserves, future production rates and the timing of development expenditures.

 

 

Shortages or increases in costs of equipment, services and qualified personnel could delay the drilling of exploratory wells and adversely affect our future results of operations and the price of our common stock. The demand for qualified and experienced personnel to conduct field operations, geologists, geophysicists, engineers and other professionals in the oil and natural gas industry can fluctuate significantly, often in correlation with oil and natural gas prices, causing periodic shortages. Historically, there have been shortages of drilling rigs and other equipment as demand for rigs and equipment has increased along with the number of wells being drilled. These factors also cause significant increases in costs for equipment, services and personnel. Higher oil and natural gas prices generally stimulate demand and result in increased prices for drilling rigs, crews and associated supplies, equipment and services. Shortages of field personnel and equipment or price increases could significantly hinder the ability of our operating partners to conduct drilling operations, which could adversely affect our results of operations and stock price.

 

Our industry is highly competitive which may adversely affect our performance, including our ability to participate in ready to drill prospects. Oil and gas exploration and development companies operate in a highly competitive environment. In addition to capital, the principal resources necessary for the exploration and production of oil and natural gas are:

 

●

leasehold prospects under which oil and natural gas reserves may be discovered;

●

drilling rigs and related equipment to explore for such reserves; and

●

knowledgeable personnel to conduct all phases of oil and natural gas operations.

 

Numerous large, well-financed firms with large cash reserves are engaged in the acquisition of oil and gas properties in North America. We and our operating partners will face competition in acquisitions, development, exploration and production from major oil companies, numerous independents, individual proprietors and others. We expect competition to be intense for available target oil and gas properties.  Such competition could have a material adverse effect on our financial condition and operating results. We and our operating partners may not be able to compete successfully against current and future competitors and competitive pressures faced by us may materially adversely affect our business, financial condition, and results of operations.

 

Drilling for and producing oil and natural gas are high risk activities with many uncertainties that could delay the anticipated drilling schedule for exploratory wells and adversely affect our future results of operations and stock price. The drilling and completion of exploratory wells are subject to numerous risks beyond our control or the control of our operating partners, including risks that could delay the proposed drilling schedules and the risk that drilling will not result in commercially viable oil and natural gas production. Drilling for oil and natural gas can be unprofitable if dry wells are drilled and if productive wells do not produce sufficient revenues to return a profit. The decisions by us and our operating partners to develop or otherwise exploit certain prospects will depend in part on the evaluation of data obtained through geophysical and geological analyses, production data and engineering studies, the results of which are often inconclusive or subject to varying interpretations. The costs of drilling, completing and operating wells are often uncertain before drilling commences. Overruns in budgeted expenditures are common risks that can make a particular project uneconomical. Even if an exploratory well is successfully completed, it may not pay out the capital costs spent to drill it.   Drilling and production operations on an exploratory well may be curtailed, delayed or canceled as a result of various factors, including the following:

 

·

delays imposed by or resulting from compliance with regulatory requirements including permitting;

·

unusual or unexpected geological formations and miscalculations;

·

shortages of or delays in obtaining equipment and qualified personnel;

·

equipment malfunctions, failures or accidents;

·

lack of available gathering facilities or delays in construction of gathering facilities;

·

lack of available capacity on interconnecting transmission pipelines;

·

lack of adequate electrical infrastructure;

·

unexpected operational events and drilling conditions;

·

pipe or cement failures and casing collapses;

·

pressures, fires, blowouts, and explosions;

·

lost or damaged drilling and service tools;

·

loss of drilling fluid circulation;

·

uncontrollable flows of oil, natural gas and natural gas liquids water or drilling fluids;

·

natural disasters;

 

 

·

environmental hazards, such as oil, natural gas and natural gas liquids leaks, pipeline ruptures and discharges of toxic gases or fluids;

·

adverse weather conditions such as extreme cold, fires caused by extreme heat or lack of rain, and severe storms or tornadoes;

·

reductions in oil, natural gas and natural gas liquids prices;

·

oil and natural gas property title problems; and

·

market limitations for oil, natural gas and natural gas liquids.

 

If any of these or other similar industry operating risks occur, we could have substantial losses. Substantial losses also may result from injury or loss of life, severe damage to or destruction of property, clean-up responsibilities, regulatory investigation and penalties and suspension of operations.

 

Investigations of oil and gas properties do not eliminate the risks associated with the selection and the acquisition of such properties. Although we will engage third-party consultants to perform a review of the oil and properties proposed to be acquired, such reviews are subject to uncertainties. It generally is not feasible to review in detail every individual property involved in an acquisition. Even a detailed review of all properties and records may not reveal existing or potential problems; nor will it permit our consultants to become sufficiently familiar with the properties to assess fully their deficiencies and capabilities. Inspections are not always performed on every well, and potential problems, such as mechanical integrity of equipment and environmental conditions that may require significant remedial expenditures, are not necessarily observable even when an inspection is undertaken.

 

Oil and gas exploration and development is subject to complex federal, state, local and other laws and regulations that could adversely affect the cost, manner or feasibility of conducting our operations or expose us to significant liabilities. Our proposed oil and natural gas exploration and production operations are subject to complex and stringent laws and regulations. In order to conduct operations in compliance with these laws and regulations, oil and gas operators must obtain and maintain numerous permits, approvals and certificates from various federal, state and local governmental authorities. Substantial costs may be incurred by our operating partners in order to maintain compliance with these existing laws and regulations. Further, in light of the explosion and fire on the drilling rig Deepwater Horizon in the Gulf of Mexico, as well as recent incidents involving the release of oil and natural gas and fluids as a result of drilling activities in the United States, there has been a variety of regulatory initiatives at the federal and state level to restrict oil and natural gas drilling operations in certain locations. Any increased regulation or suspension of oil and natural gas exploration and production, or revision or reinterpretation of existing laws and regulations, that arises out of these incidents or otherwise could result in delays and higher operating costs, which will be passed along to us by way of our equity interest in the property. Such costs or significant delays could have a material adverse effect on our business, financial condition and results of operations.

 

Laws and regulations governing oil and natural gas exploration and production may also affect production levels. Oil and gas operators are required to comply with federal and state laws and regulations governing conservation matters, including provisions related to the unitization or pooling of the oil, natural gas and natural gas liquids properties; the establishment of maximum rates of production from wells; the spacing of wells; and the plugging and abandonment of wells. These and other laws and regulations can limit the amount of oil and natural gas operators can produce from their wells, limit the number of wells they can drill, or limit the locations at which they can conduct drilling operations, which in turn could negatively impact our business, financial condition and results of operations.

 

New laws or regulations, or changes to existing laws or regulations may unfavorably impact our proposed operations, could result in increased operating costs and have a material adverse effect on our financial condition and results of operations. For example, Congress is currently considering legislation that, if adopted in its proposed form, would subject companies involved in oil and natural exploration and production activities to, among other items, additional regulation of and restrictions on hydraulic fracturing of wells, the elimination of most U.S. federal tax incentives and deductions available to oil and natural gas exploration and production activities, and the prohibition or additional regulation of private energy commodity derivative and hedging activities.

 

These and other potential regulations could increase operating costs, reduce revenue, delay proposed operations, increase direct and third party post production costs associated with the oil and gas properties or otherwise alter the proposed operations of oil and gas properties in which we hold an equity interest, which could have a material adverse effect on our financial condition, results of operations and stock price.

 

 

Oil and gas operations are subject to environmental laws and regulations that could adversely affect the cost, manner or feasibility of conducting operations or result in significant costs and liabilities. Oil and natural gas exploration and production operations are subject to stringent and comprehensive federal, state and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may impose numerous obligations that are applicable to the operation of the properties in which we hold an interest including the acquisition of a permit before conducting drilling; water withdrawal or waste disposal activities; the restriction of types, quantities and concentration of materials that can be released into the environment; the limitation or prohibition of drilling activities on certain lands lying within wilderness, wetlands and other protected areas; and the imposition of substantial liabilities for pollution resulting from operations. Numerous governmental authorities, such as the U.S. Environmental Protection Agency ("EPA") and analogous state agencies, have the power to enforce compliance with these laws and regulations and the permits issued under them, often requiring difficult and costly actions. Failure to comply with these laws and regulations may result in the assessment of administrative, civil or criminal penalties; the imposition of investigatory or remedial obligations; and the issuance of injunctions limiting or preventing some or all of the proposed operations.

 

There is inherent risk of incurring significant environmental costs and liabilities in the performance of oil and gas operations due to the handling of petroleum hydrocarbons and wastes, because of air emissions and wastewater discharges related to such operations, and as a result of historical industry operations and waste disposal practices.   Under certain environmental laws and regulations, our operating partner could be subject to joint and several strict liability for the removal or remediation of previously released materials or property contamination regardless of whether our operating partner was responsible for the release or contamination or if the operations were in compliance with all applicable laws at the time those actions were taken. Private parties, including the owners of properties upon which our operating partners intend to drill wells and facilities where petroleum hydrocarbons or wastes are taken for reclamation or disposal may also have the right to pursue legal actions to enforce compliance, as well as to seek damages for contamination even in the absence of non-compliance, with environmental laws and regulations or for personal injury or property damage. In addition, the risk of accidental spills or releases could expose our operating partners to significant liabilities. All of the foregoing costs and liabilities of our operating partners may be passed along to us by way of our equity interest on the subject oil and gas property, which in turn could have a material adverse effect on our financial condition, results of operations and stock price. Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly construction, drilling, water management, completion, waste handling, storage, transport, disposal or cleanup requirements could require our operating partners to make significant expenditures to attain and maintain compliance. We would be responsible for our pro rata share of such costs, which may have a material adverse effect on our results of operations, financial condition or stock price.

 

Climate change laws and regulations restricting emissions of "greenhouse gases" could result in increased operating costs and reduced demand for oil and natural gas while the physical effects of climate change could disrupt production and cause our operating partners to incur significant costs in preparing for or responding to those effects. On December 15, 2009, the EPA published its findings that emissions of carbon dioxide, methane and other greenhouse gases ("GHGs") present a danger to public health and the environment. These findings allow the agency to adopt and implement regulations that restrict emissions of GHGs under existing provisions of the federal Clean Air Act. Accordingly, the EPA has adopted regulations that require a reduction in emissions of GHGs from motor vehicles and also trigger permit review for GHG emissions from certain large stationary sources. The EPA's rules relating to emissions of GHGs from large stationary sources of emissions are currently subject to a number of political and legal challenges, but the federal courts have thus far declined to issue any injunctions to prevent EPA from implementing, or requiring state environmental agencies to implement, the rules. In addition, on October 30, 2009, the EPA published a final rule requiring the reporting of GHG emissions from specified large GHG emission sources in the United States, beginning in 2011 for emissions occurring in 2010. On November 30, 2010, the EPA published a final rule that expands its October 2009 final rule on reporting of GHG emissions to require certain owners and operators of onshore oil and natural gas production to monitor greenhouse gas emissions beginning in 2011 and to report those emissions beginning in 2012. Both houses of Congress have from time to time considered legislation to reduce emissions of GHGs and almost one-half of the states, either individually or through multi-state regional initiatives, already have begun implementing legal measures to reduce emissions of GHGs. The adoption and implementation of any regulations imposing reporting obligations on, or limiting emissions of GHGs from the equipment and operations of our operating partners could require our operating partners to incur costs to reduce emissions of GHGs associated with our operations or could adversely affect demand for the oil and natural gas. All of the foregoing costs and liabilities of our operating partners may be passed along to us by way of our equity interest on the subject oil and gas property, which in turn could have a material adverse effect on our financial condition, results of operations and stock price.   Finally, it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the Earth's atmosphere may produce climate change that could have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events; if any such effects were to occur, they could have an adverse effect on our assets and operations.

 

 

Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays as well as adversely affect our results of operations, financial condition or stock price.   Our operating partners may from time to time engage in a production technique known as hydraulic fracturing, an important and common practice used to stimulate production of hydrocarbons from tight formations, such as shales.  The process involves the injection of water or other liquids, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. The process is typically regulated by state oil and gas commissions. However, the EPA recently asserted federal regulatory authority over certain hydraulic fracturing practices. Also, legislation has been introduced into Congress to provide for federal regulation of hydraulic fracturing and to require disclosure of the chemicals used in the fracturing process. In addition, some states have adopted, and other states are considering adopting, regulations that could restrict hydraulic fracturing in certain circumstances. For instance, in June 2011, Texas adopted a law that requires disclosure to the Railroad Commission of Texas of the additives and other chemicals contained in hydraulic fracturing fluids used in the state, subject to certain trade secret protections. If new laws or regulations that significantly restrict or regulate hydraulic fracturing are adopted, such legal requirements could make it more difficult or costly for our operating partners to perform fracturing to stimulate production from our oil and gas interests and thereby affect the determination of whether a well is commercially viable. Restrictions on hydraulic fracturing could also reduce the amount of oil and natural gas our operating partners are ultimately able to produce in commercial quantities from our oil and gas interests.

 

Hydraulic fracturing operations may result environmental contamination and other operational risks that could subject us to significant costs, liabilities and loss of investment.  Hydraulic fracturing is a process that involves the injection of water or other liquids, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. The process involves the risk that liquids and chemicals injected into the well may migrate into and contaminate water aquifers and wells or surrounding land. The process also involves the risk that water and liquids that are retrieved from the fractured well may be improperly disposed of, thus creating another potential for water or ground contamination. Our operating partners face the possibility of significant costs and liabilities in the event of any environmental contamination resulting from the hydraulic fracturing of wells in which we have an interest, in which event we may become liable for our pro rata share of such costs and liabilities. Also, even in the absence of any actual contamination, we can face significant costs if the operator is required to defend any lawsuits or investigations that allege contamination. Finally, any actual or alleged environmental contamination resulting from a drilling operation on an oil and gas property in which we have an interest can lead to the suspension or abandonment of that property and the loss of our entire investment in such property.

 

No Dividends. We do not expect to pay cash dividends on our common stock in the foreseeable future.

 

No Active Trading market. Our common shares are traded on the OTC Market under the symbol “WTXR.” However, we consider our common stock to be “thinly traded” and any last reported sale prices may not be a true market-based valuation of the common stock. Also, the present volume of trading in our common stock may not provide investors sufficient liquidity in the event you wish to sell your common shares. There can be no assurance that an active market for our common stock will develop. In addition, the stock market in general, and early stage public companies in particular, have experienced extreme price and volume fluctuations that have often been unrelated or disproportionate to the operating performance of such companies. If we are unable to develop a market for our common shares, you may not be able to sell your common shares at prices you consider to be fair or at times that are convenient for you, or at all.

 

 

Our common stock may be considered to be a “penny stock” and, as such, any the market for our common stock may be further limited by certain SEC rules applicable to penny stocks. To the extent the price of our common stock remains below $5.00 per share or we have a net tangible assets of $2,000,000 or less, our common shares will be subject to certain “penny stock” rules promulgated by the SEC. Those rules impose certain sales practice requirements on brokers who sell penny stock to persons other than established customers and accredited investors (generally institutions with assets in excess of $5,000,000 or individuals with net worth in excess of $1,000,000). For transactions covered by the penny stock rules, the broker must make a special suitability determination for the purchaser and receive the purchaser’s written consent to the transaction prior to the sale. Furthermore, the penny stock rules generally require, among other things, that brokers engaged in secondary trading of penny stocks provide customers with written disclosure documents, monthly statements of the market value of penny stocks, disclosure of the bid and asked prices and disclosure of the compensation to the brokerage firm and disclosure of the sales person working for the brokerage firm. These rules and regulations adversely the affect the ability of brokers to sell our common shares and limit the liquidity of our securities.

 

Item 1B.

Unresolved Staff Comments

 

Not applicable.

 

 

 

Item 2.

Properties

 

Company Executive Offices

 

Our executive offices are located in 5729 Lebanon Road., Suite 144, Frisco, Texas 75034. We believe that our current facilities are adequate for our foreseeable needs.

 

Oil and Gas Interests

 

In September 2011, we acquired our initial property consisting of a 31.25% working interest in an exploratory oil and gas drilling prospect covering 120 acres in Eastland County, Texas. The Eastland County prospect includes two exploratory wells, known as Rutherford #1 and C.M. Knott #1, that had been operating at a minimum level required to maintain the lease rights. In October 2011, the operator reentered the Rutherford #1 well and conducted drilling and casing activities, which were completed in November 2011. In January 2012, a third party conducted the fracture stimulation of the Rutherford #1. In February 2013, the operator placed a pump jack on the Rutherford #1 well, however no meaningful revenue has been derived from the well to date. During the three months ended June 30, 2013, we determined that our investment in the Eastland County prospect was impaired due to an unsuccessful fracture stimulation of the Rutherford #1. Accordingly, we recorded an impairment loss of $108,373 to write off the capitalized fracture stimulation costs. The operator has undertaken no further activity on the Eastland County prospect as of the date of this report.

 

Port Hudson Field

 

In August 2013, we acquired a 7.24625% working interest (5.65158% net revenue interest) in the oil and gas leases, wells and attendant production in the Port Hudson field, Baton Rouge Parish, Louisiana, from Wells Fargo Energy Capital, Inc. for total consideration of $702,900. Our acquisition of the Port Hudson working interest was effective as of April 1, 2013. Accordingly, we have received revenue from the Port Hudson working interest commencing on April 1, 2013.

 

On April 15, 2014, we entered into an agreement with EnTek Partners, LLC for the sale of 44.1% of our working interest in the Port Hudson field for the total consideration of $290,000, less any payments received by us for production from the Port Hudson field occurring after January 1, 2014. Pursuant to our agreement with EnTek Partners, we sold to EnTek an undivided 3.1956% of 8/8ths working interest (2.4926% net revenue interest) out of the working interests in the Port Hudson field owned by us. The transactions under the EnTek Partners agreement closed on April 16, 2014, with an effective date of January 1, 2014. After giving effect to the sale, we continue to hold a 4.0506% working interest (3.1595% net revenue interest) in the Port Hudson field.

 

The Port Hudson field has three producing wells that have produced a total of 1.29 million bbls as of September 30, 2014 with estimated total remaining recoverable proved developed producing reserves of 449,000 bbls (14,186 bbls net to West Texas Resources after giving effect to the transaction with EnTek Partners), and 26,000 bbls of proven developed behind pipe reserves (821 bbls net to West Texas Resources after giving effect to the transaction with EnTek Partners) and are currently producing approximately 260 bbls per day. The operator of the Port Hudson field has no current plans for the further development of the property.

 

West Cam 225 Field

 

In September 2013, we acquired a 10.0167% working interest (7.2120% net revenue interest) in an offshore oil and gas field, known as West Cam 225, located in the shallow waters of the Gulf of Mexico near Cameron, Louisiana, from Enovation Resources, LLC for total consideration of $50,000. Concurrent with our purchase of the working interest, we also paid the operator $230,459 as our allocable share of the expenses associated with the West Cam 225 property to build a new incremental flowline connecting the D-1 platform to the Stingray Pipeline System. Pursuant to our April 15, 2014 agreement with EnTek Partners, LLC, EnTek Partners has also agreed to provide to us $275,000 in non-recourse financing to pay for our share of a dual recompletion in the D-1 well at the West Cam 225 property in exchange for our agreement to provide EnTek Partners with 75% of the net profits derived by us from the West Cam 225 property until such time as EnTek Partners has recouped 100% of the recompletion costs advanced on our behalf and 50% of the net profits thereafter. The transactions under the EnTek Partners agreement closed on April 16, 2014, with an effective date of January 1, 2014.

 

 

As of September 30, 2014, the West Cam 225 field had proven reserves of 8,996 mmcf of gas or 1,499 thousand net equivalent bbls (108,131 boes net to West Texas Resources after giving effect to the transaction with EnTek Partners) and has two producing wells, the #7 and the D-1, that were previously shut-in and waiting on a sales pipeline connection. The pipeline was completed and tested in August 2013 and now the two wells are currently producing at a combined intermittent gross rate of 1.6 mmcfd. As of September 30, 2014, the D-1 well has overproduced its expected recoverable reserves in its original completion in the 6,800’ sand and is currently producing at a high water cut. The operator presently intends to perform a recompletion on the D-1 well in the second quarter of 2015, at which time the D-1 well will be recompleted uphole into the 5,900’ sand and the field is expected to produce at a combined gross rate of 5.5 mmcfd and thereby provide access to 7.93 bcf of gross proved behind pipe reserves.

 

Wolfcamp Field

 

In June and July 2014, we acquired non-operating leases covering approximately 1,070 gross mineral acre leases in the Wolfcamp field located in Hale County, Texas. The leases were acquired for cash payments of $45,484. The leases have a primary term of five years with our option to extend the term for another five years. The leased properties constitute the surface acreage comprising a natural gas prospect, for which we hold 50% of the working interest and 40% net revenue interest. The leased properties are subject to a 20% royalty interest held by the owners and a third party. We are currently evaluating our options for the exploitation of the leased properties, including our sale of the leases or our farm-out of the leases to a natural gas operator.

 

Sunshine Prospect

 

On August 1, 2014, we acquired from Restech Resources, LLC to purchase a 15% (14.25% net revenue interest) in a non-operating oil and gas prospect located in Landry Parish, Louisiana. The working interest concerns 248 gross acres and net acres in the Sunshine Prospect. Our purchase price for the working interest was $76,500. The operator presently intends to drill an initial well on the Sunshine prospect on 2015.

 

Stansell Field

 

We hold a 1% working interest in an oil prospect located in Floyd County, Texas. The working interest comprises 15,000 leased acres in the southern section of the Palo Duro basin. The initial project will be the re-entry of the Stansell #1-A well, an existing wellbore that was drilled in 2006. The original drilling encountered oil shows in three separate reservoirs and the operator intends to re-enter and recomplete the Stansell #1-A using current fracture stimulation technology. We have a carried 1% working interest in the Stansell #1-A well through the tanks. The operator plans to commence the re-entry of the Stansell #1-A well in December 2014.

 

Subject to our receipt of additional capital, we intend to pursue the acquisition of additional equity interests in other oil and gas properties in North America. However, as of the date of this report, we have no understandings or agreements in place concerning our acquisition of an interest in any other properties.

 

Estimated Proved Reserves

 

The following table sets forth our estimated proved reserves as of September 30, 2014:

 

Category		Oil				Gas				Dollar Amount
		(bbls)				(boe)				($)
Proved Developed			15,000				108,167			$	1,251,000
Proved Undeveloped			–				–				–
Total Proved			15,000				108,167			$	1,251,000

 

 

The estimated proven reserves set forth above are based on the SEC disclosure rules which require disclosure of oil and gas proved reserves by significant geographic area, using the arithmetic 12-month average first-day-of the-month prices for the year, as opposed to using year-end prices. The estimated dollar value of our proved reserves represents the present value, discounted at 10% per annum, or PV-10, of the estimated future cash flows before income taxes. The estimated dollar values are based on the unweighted arithmetic first-day-of the-month prices for the 12 months prior to September 30, 2014. We converted natural gas to oil equivalent at a ratio of six mcf to one boe.

 

All of our reserves are located within the continental U.S. and consist of our net interests in the estimated proven reserves at the Port Hudson and West Cam 225 fields. The reserve analysis set forth above was prepared by Collarini Associates, an independent third party oil and gas engineering firm.

 

The data in the table above represents estimates only. Oil and natural gas reserve engineering is inherently a subjective process of estimating underground accumulations of oil and natural gas that cannot be measured exactly. The accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and judgment. Accordingly, reserve estimates may vary from the quantities of oil and natural gas that are ultimately recovered. For a discussion of risks associated with reserve estimates generally, please read "Item 1A. Risk Factors—Our estimated reserves and future production rates are based on many assumptions that may prove to be inaccurate. Any material inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our estimated reserves.”

 

Acreage

 

The following tables summarize by geographic area our developed and undeveloped acreage as of September 30, 2014. The term of the undeveloped leasehold acreage ranges from three to five years.

 

		Developed1				Undeveloped2
State		Gross3		Net4		Gross3		Net4
Louisiana		5,120		505.7		16,070		685
Total		--		--

__________

¹ Developed acreage is acreage spaced for or assignable to productive wells.

² Undeveloped acreage is oil and gas acreage on which wells have not been drilled or completed to a point that would permit the production of economic quantities of oil or gas regardless of whether such acreage contains proved reserves.

³ A gross acre is an acre in which we own a working interest. The number of gross acres is the total number of acres in which we own a working interest.

⁴ A net acre is the amount of a gross acre represented by our working interest. The number of net acres is the sum of the fractional working interests owned in acres expressed as whole numbers and fractions thereof.

 

 

Productive Wells

 

The following table summarizes by geographic area our gross and net interests in producing oil and gas wells as of September 30, 2013. Productive wells are producing wells capable of production, including gas wells awaiting pipeline connections and oil wells awaiting connection to production facilities. Wells that are dually completed in more than one producing horizon are counted as one well. A gross well is a well in which we hold a working interest. A net well is the amount of a gross well represented by our working interest and the number of net wells is the sum of all of our fractional interests in gross wells in which we hold a working interest.

 

					Gross Wells						Net Wells
		State			Oil		Gas				Oil				Gas
		Louisiana			3			2				0.1215			0.2003
		Total			3			2				0.1215			0.2003

 

Drilling and Other Exploratory Activities

 

We were incorporated in December 2010 and did not participate in any drilling, or other exploratory or development, activity during the fiscal year ended September 30, 2011. In October 2011, we participated in our first drilling operation, which took place at our initial prospect, located in Eastland County, Texas. The Eastland County prospect includes two wells, known as Rutherford #1 and C.M. Knott #1, that had been operating at a minimum level required to maintain the lease rights. In October 2011, the operator of the prospect reentered the Rutherford #1 well and conducted drilling and casing activities, which were completed in November 2011.  In January 2012, a third party conducted the fracture stimulation of the Rutherford #1. In February 2013, the operator placed a pump jack on the Rutherford #1 well, however no meaningful revenue has been derived from the well to date. Our activity on the Rutherford #1 represents our only participation in drilling, exploratory or development activity to date. As of the date of this report, we have no wells in the process of drilling or completion other than the Rutherford #1.

 

Item 3.

Legal Proceedings

 

As of the date of this report, there are no pending legal proceedings to which we or our properties are subject, except for routine litigation incurred in the normal course of business.

 

Item 4.

Mine Safety Disclosures

 

Inapplicable.

 

 

PART II

 

Item 5.

Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Repurchases of Equity Securities

 

Market Information

 

Our common stock is quoted on the OTC Market under the symbol “WTXR” Our common stock trades only sporadically and has experienced in the past, and is expected to experience in the future, significant price and volume volatility. The following table shows the reported high and low closing prices per share for our common stock based on information provided by the OTC Market for the periods indicated.  

 

Fiscal Year Ended September 30, 2014		High		Low
Fourth Quarter		$1.00		$0.76
Third Quarter		$0.90		$0.64
Second Quarter		$0.89		$0.51
First Quarter		$1.15		$0.70

 

Fiscal Year Ended September 30, 2013		High		Low
Fourth Quarter		$1.00		$0.54
Third Quarter		$0.75		$0.60
Second Quarter		$0.75		$0.60
First Quarter		$0.80		$0.50

 

Holders of Record

 

As of January 12, 2014, there were approximately 171 holders of record of our common stock.

 

Dividend Policy

 

We have never declared or paid cash dividends on our common stock. We presently intend to retain earnings to finance the operation and expansion of our business.

 

Equity Compensation Plan Information

 

We have adopted the West Texas Resources, Inc. 2011 Stock Incentive Plan providing for the grant of non-qualified stock options and incentive stock options to purchase shares of our common stock and for the grant of restricted and unrestricted share grants. We have reserved 3,000,000 shares of our common stock under the plan. All officers, directors, employees and consultants to our company are eligible to participate under the plan. The purpose of the plan is to provide eligible participants with an opportunity to acquire an ownership interest in our company.

 

 

The following table sets forth certain information as of September 30, 2014 about our stock plans under which our equity securities are authorized for issuance.

 

Plan Category		(a) Number of Securities to be Issued Upon Exercise of Outstanding Options				(b) Weighted-Average Exercise Price of Outstanding Options				(c) Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (Excluding Securities Reflected In Column (a))
Equity compensation plans approved by security holders			800,000			$	0.53				2,200,000
Equity compensation plans not approved by security holders			–				–				–
Total			800,000			$	0.53				2,200,000

 

Unregistered Sales of Equity Securities and Use of Proceeds

 

During the fiscal year ended September 30, 2014, we conducted the private placement sale of 336,000 shares of our common stock at the offering price of $0.50 per share to 12 parties for the gross proceeds of $168,000. The issuances were exempt under Section 4(a)(2) of the Securities Act of 1933 and Rule 506 there under. All of the investors were accredited investors, as such term is defined in Rule 501 under the Securities Act. The offering was conducted by our management. No sales commissions or finders’ fees were paid by us or anyone else.

 

Item 6.

Selected Financial Data

 

Not applicable.

 

 

Item 7.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

General

 

We were formed on December 9, 2010 under the laws of Nevada for the purpose of oil and gas exploration and development in North America. We commenced revenue producing oil and gas operations effective as of April 1, 2013.

 

Results of Operations

 

From April 1, 2013 to December 2014, all of our revenue was derived from our working interest in the Port Hudson field. Commencing in January 2014, we have also derived revenue from our working interest in the West Cam 225 field. During the fiscal years ended September 30, 2014 and 2013, we had $304,289 and $254,601 of revenue, respectively. All of our revenue during the fiscal year ended September 30, 2013 was oil and gas sales derived from our working interest in the Port Hudson field, whereas our revenue for the fiscal year ended September 30, 2014 consisted of revenue in the amount of $260,179 from our working interest in the Port Hudson field and revenue in the amount of $44,110 from our working interest in the West Cam 225 field.

 

For the fiscal year ended September 30, 2014, we had general and administrative expenses of $742,870 compared to general and administrative expenses of $312,098 during the prior year. The increase in expenses is attributable to the higher level of activity during the 2014 and our incursion of $232,256 of stock-based compensation during the 2014 fiscal year compared to nil stock-based compensation during the prior year.

 

For the fiscal year ended September 30, 2014, we had other expenses of $294,530 compared to other expenses of $238,384 during the prior year. The increase in other expenses was due primarily to an increase in interest expense and amortized debt discount in the amount of $294,530 during 2014, compared to $111,766 of interest expense for the prior year related to our borrowings.

 

For the fiscal years ended September 30, 2014 and 2013, we incurred a net loss of $(733,111) and $(295,881), respectively. The increase in our net loss was the result of an increase in expenses during 2014 compared to the prior year.

 

Subject to our receipt of additional capital, our plan of operations over the next 12 months is to pursue the acquisition of additional equity interests in oil and gas properties to be thereafter exploited by us in conjunction with other oil and gas producers. As of the date of this memorandum, we have no understandings or agreements in place concerning our acquisition of an interest in any other properties.

 

At the present time, we have two employees, our chief executive officer and chief financial officer, Stephen Jones and John Kerr, respectively, each of whom has limited experience in the oil and gas exploration and development business. Subject to our receipt of significant additional capital, we intend to hire senior management and staff with experience in oil and gas exploration. Until such time, we intend to pursue an operating strategy that is based on our participation in exploration prospects as a non-operator. Based on that strategy, our plan of operations over the next 12 months is to pursue the acquisition of oil and natural gas interests in partnership with other companies with exploration, development and production expertise. We will also pursue alliances with partners in the areas of geological and geophysical services and prospect generation, evaluation and prospect leasing. Pursuant to this strategy, we intend to engage and rely on third party geologists and geophysicists, among others, to review the available data concerning each potential acquisition. In each case, we expect that the operator of the prospect will assemble the appropriate data and conduct the appropriate studies and that our consultants will conduct an independent review of the operator’s data and studies for purposes of advising us of the merits of each potential acquisition.

 

The business of oil and gas acquisition, drilling and development is capital intensive and the level of operations attainable by an oil and gas company is directly linked to and limited by the amount of available capital. Therefore, a principal part of our plan of operations is to acquire the additional capital required to finance the acquisition of such properties and our share of the development costs. As explained under “Financial Condition” below, we will seek additional working capital through the sale of our securities and, subject to the successful deployment of our cash on hand, we will endeavor to obtain additional capital through bank lines of credit and project financing.

 

 

Financial Condition

 

As of September 30, 2014, we had total assets of $1,075,371 and negative working capital of $(272,849). Our ability to achieve commercial success is dependent on our ability to obtain additional capital either through the additional sale of our equity or debt securities, bank lines of credit, project financing or cash generated from oil and gas operations. We believe that our ability to achieve commercial success and our continued growth will be dependent on our ability to access capital either through the additional sale of our equity or debt securities, bank lines of credit, project financing or cash generated from oil and gas operations. Therefore, a principal part of our plan of operations is to acquire the additional capital required to finance the acquisition of such properties and our share of the development costs. We will seek additional working capital through the sale of our securities and, subject to the successful deployment of our cash on hand, we will endeavor to obtain additional capital through bank lines of credit and project financing. We have undertaken the present offering for purposes of obtaining additional working capital. However, there are no commitments or agreement on the part of anyone to purchase our common shares. The Shares are being offered on a straight best efforts basis by our executive officers, which means that there is no minimum offering amount and no escrow of proceeds. There can be no assurance that we will be able to obtain additional capital on a timely basis in order to complete our acquisition of additional oil and gas interests.

 

The report of our independent registered public accounting firm for the fiscal year ended September 30, 2014 states that due to our losses from operations and lack of working capital there is substantial doubt about our ability to continue as a going concern.

 

Off-Balance Sheet Arrangements

 

We do not have any off-balance sheet financing arrangements.

 

Item 7A.

Quantitative and Qualitative Disclosures About Market Risk

 

Not applicable.

 

 

Item 8.

Financial Statements and Supplementary Data

 

Index To Financial Statements

 

	Page
Report of Independent Registered Public Accounting Firm	F-1
Balance Sheets at September 30, 2014 and 2013	F-2
Statements of Operations for the Years Ended September 30, 2014 and 2013	F-3
Statements of Changes In Shareholders’ Equity for the Years Ended September 30, 2014 and 2013	F-4
Statements of Cash Flows for the Years Ended September 30, 2014 and 2013	F-5
Notes to Financial Statements	F-6

 

  

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

 

 

To the Board of Directors and

Stockholders of West Texas Resources, Inc.

 

 

We have audited the accompanying balance sheets of West Texas Resources, Inc. as of September 30, 2014 and 2013, and the related statements of operations, stockholders’ equity, and cash flows for each of the two years in the period ended September 30, 2014. West Texas Resources, 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 financial statements referred to above present fairly, in all material respects, the financial position of West Texas Resources, Inc. as of September 30, 2014 and 2013, and the results of its operations and its cash flows the years ended September 30, 2014 in conformity with accounting principles generally accepted in the United States of America.

 

The accompanying financial statements have been prepared assuming the Company will continue as a going concern.  As discussed in Note 1 to the financial statements, the Company has not earned any significant revenues since inception and has an accumulated deficit of $1,277,409, which raises substantial doubt about its ability to continue as a going concern.  The financial statements do not include any adjustment that might result from the outcome of this uncertainty.

 

 

Farber Hass Hurley LLP

  

Chatsworth, California

January 13, 2015 

 

 

West Texas Resources, Inc.

 

BALANCE SHEETS

 

		September 30,				September 30,
		2014				2013
ASSETS
Current Assets
Cash		$	144,506			$	16,631
Accounts receivable			45,055				168,949
Total Current Assets			189,561				185,580
Oil and gas properties, using successful effort accounting			885,810				1,002,109
TOTAL ASSETS		$	1,075,371			$	1,187,689
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities
Accrued expenses		$	159,255			$	151,196
Payroll liabilities			3,499				3,911
Investment payable			13,600				–
Asset retirement obligation			10,000				10,000
Shareholder advances			35,000				15,000
Interest payable			19,303				5,378
Notes payable - related parties, net of discount			183,384				106,388
Other payable			38,369				–
Total Current Liabilities			462,410				291,873
Commitments and Contingencies			–				–
Shareholders' Equity
Preferred stock, $0.001 par value; 10,000,000 shares authorized; no shares issued and outstanding			–				–
Common stock, $0.001 par value; 200,000,000 shares authorized; 14,415,400 and 14,079,400 shares issued and outstanding at September 30, 2014 and September 30, 2013, respectively			14,415				14,079
Additional paid-in capital			1,875,955				1,426,035
Accumulated deficit			(1,277,409	)			(544,298	)
Total Shareholders' Equity			612,961				895,816
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY		$	1,075,371			$	1,187,689

 

See accompanying notes to these financial statements

 

 

West Texas Resources, Inc.

 

STATEMENTS OF OPERATIONS

 

		For the Years Ended September 30,
		2014				2013
Revenues
Oil and gas sales		$	304,289			$	254,601
General and administrative expenses			742,870				312,098
Operating Loss			(438,581	)			(57,497	)
Other income (expenses)
Interest expense			(40,923	)			(5,378	)
Amortization of debt discount			(253,607	)			(106,388	)
Depreciation expense			–				(2,980	)
Loss on disposal of fixed asset			–				(5,265	)
Asset retirement expense			–				(10,000	)
Impairment loss on investment			–				(108,373	)
Loss Before Income Taxes			(733,111	)			(295,881	)
Tax provision			–				–
Net Loss		$	(733,111	)		$	(295,881	)
Loss per share
Basic and diluted weighted average number of common shares outstanding			14,182,984				13,303,603
Basic and diluted net loss per share		$	(0.05	)		$	(0.02	)

 

See accompanying notes to these financial statements

 

 

West Texas Resources, Inc.

 

STATEMENTS OF SHAREHOLDERS' EQUITY

 

For the Years Ended September 30, 2014 and 2013

 

		Common Stock								Options				Additional								Total
		Number								Number				Paid-in				Accumulated				Shareholders'
		of Shares				Amount				of Options				Capital				Deficit				Equity
Balance, September 30, 2012			13,106,500			$	13,106				400,000			$	292,796			$	(248,417	)		$	57,485
Issuance of common stock for cash			890,900				891								444,559								445,450
Conversion of shareholder advances to common stock			82,000				82								40,918								41,000
Debt discount															647,762								647,762
Net loss																			(295,881	)			(295,881	)
Balance, September 30, 2013			14,079,400			$	14,079				400,000			$	1,426,035			$	(544,298	)		$	895,816
Issuance of common stock for cash			336,000				336								167,664								168,000
Debt discount															50,000								50,000
Stock based compensation											400,000				232,256								232,256
Net loss																			(733,111	)			(723,111	)
Balance, September 30, 2014			14,415,400			$	14,415				800,000			$	1,875,955			$	(1,277,409	)		$	612,961

 

See accompanying notes to these financial statements

 

 

West Texas Resources, Inc.

 

STATEMENTS OF CASH FLOWS

 

		For the Years Ended September 30,
		2014				2013
Cash flows from operating activities
Net loss		$	(733,111	)		$	(295,881	)
Adjustments to reconcile net loss to net cash from operating activities:
Stock-based compensation			232,256				–
Depreciation expense			–				2,980
Loss on disposal of fixed asset			–				5,265
Loss on sale of oil and gas interest			19,983				–
Asset retirement expense			–				10,000
Impairment loss on investment			–				108,373
Amortization of debt discount			253,607				106,388
Changes in operating assets and liabilities:
Accounts receivable			123,895				(168,949	)
Payroll liabilities			(412	)			54
Investment payable			13,600				–
Other payable - Bank of America			38,369				–
Interest payable			13,925				5,378
Accrued expenses			8,059				87,100
Net cash used in operating activities			(29,829	)			(139,292	)
Cash flows from investing activities
Cash to purchase oil and gas properties			(193,684	)			(983,359	)
Proceeds from sale of oil and gas interest			290,000				–
Net proceeds from sale of water truck			–				16,458
Net cash provided by (used in) investing activities			96,316				(966,901	)
Cash flows from financing activities
Proceeds from sale of common stock			168,000				445,450
Proceeds from notes payable			50,000				647,763
Repayment on note payable			(176,612	)			–
Shareholder Advances			20,000				21,000
Net cash provided by financing activities			61,388				1,114,213
Net increase (decrease) in cash			127,875				8,020
Cash, beginning of period			16,631				8,611
Cash, end of period		$	144,506			$	16,631
Supplemental cash flow disclosure:
Interest paid		$	26,998			$	–
Income taxes paid		$	–			$	–
Supplemental disclosure of non-cash transactions:
Conversion of shareholder advances to common stock		$	–			$	41,000

 

See accompanying notes to these financial statements

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

1.	Organization and Summary of Significant Accounting Policies

 

Organization and business

 

Texas Resources Energy, Inc. (“TREI”) was incorporated under the laws of Nevada on December 9, 2010, as a wholly-owned subsidiary of Russian Resources Energy, Inc., a Texas corporation (“RREI”), and then spun off to the shareholders of RRIE on the same date. On June 30, 2011, TREI changed its name to West Texas Resources, Inc. (the “Company”). The Company intends to engage in the acquisition, exploration and development of oil and gas properties in North America. From its inception, the Company has devoted its activities to developing a business plan, raising capital and acquiring operating assets.

 

Going concern

 

The accompanying financial statements have been prepared in conformity with accounting principles generally accepted in the United States (GAAP) that contemplate continuation of the Company as a going concern. The Company has not earned any significant revenues since inception. During the years ended September 30, 2014 and 2013, the Company incurred a net loss of $733,111 and $295,881, respectively, In addition, the Company had an accumulative deficit of $1,277,409 and $544,298, as of September 30, 2014 and 2013, respectively. These factors raise substantial doubt about the Company’s ability to continue as a going concern.

 

The Company will require up to $1 million of additional capital in order to fund its proposed operations over the next 12 months. Management plans to continue to seek sources of financing on favorable terms; however, there are no assurances that any such financing can be obtained on favorable terms, if at all.   Management expects to monitor and control the Company’s operating costs until cash is available through financing or operating activities.  There are no assurances that the Company will be successful in achieving these plans. The Company anticipates that losses will continue until such time, if ever, as the Company is able to generate sufficient revenues to support its operations.

 

Oil and gas properties

 

The Company uses the successful efforts method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties, to drill and equip exploratory wells that find proved reserves, to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed.

 

Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. Other unproved properties are amortized based on the Company's experience of successful drilling and average holding period. Capitalized costs of producing oil and gas properties, after considering estimated residual salvage values, are depreciated and depleted by the unit-of-production method.  

 

On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion, and amortization with a resulting gain or loss recognized in income.  On the sale of an entire interest in an unproved property for cash or cash equivalent, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

Impairment of long-lived assets

 

The Company accounts for the impairment and disposition of long-lived assets in accordance with ASC 360-10-35, Impairment or Disposal of Long-Lived Assets. In accordance with ASC 360-10-35, long-lived assets are reviewed for events of changes in circumstances, which indicate that their carrying value may not be recoverable. During the years ended September 30, 2014 and 2013, the Company determined that the investment in one of its oil and gas properties was impaired due to unsuccessful fracking process. Accordingly, the Company recorded impairment loss of $0 and $108,373 as of September 30, 2014 and 2013, respectively to write off the capitalized fracking costs.

 

Asset retirement obligations

 

ASC 410-20, Asset Retirement Obligations, clarifies that a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. The obligation to perform the asset retirement activity is unconditional even though uncertainty exists about the timing and/or method of settlement. ASC 410-20 requires a liability to be recognized for the fair value of a conditional asset retirement obligation if the fair value of the liability can be reasonably estimated.

 

Cash, cash equivalents, and other cash flow statement supplemental information

 

The Company considers all liquid investments with an original maturity of three months or less that are readily convertible into cash to be cash equivalents.  The Company places its cash equivalents with high credit quality financial institutions.  Accounts at these institutions are insured by the Federal Deposit Insurance Corporation (FDIC) up to $250,000. The Company performs ongoing evaluations of these institutions to limit its concentration of risk exposure.  Management believes this risk is not significant due to the financial strength of the financial institutions utilized by the Company.

 

Furniture, fixtures and equipment

 

Furniture, fixtures and equipment are carried at cost depreciated using the straight-line method over their estimated useful lives. Gain or loss on retirement or sale or other disposition of these assets is included in income in the period of disposition.

 

Use of estimates

 

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect certain reported amounts and disclosures.  Accordingly, actual results could differ from those estimates.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

  

Income taxes

 

The Company reports certain expenses differently for financial and tax reporting purposes and, accordingly, provides for the related deferred taxes. Income taxes are accounted for under the liability method in accordance with ASC 740, Income Taxes.

 

Management has considered its tax positions and believes that all of the positions taken by the Company in its Federal and State tax returns are more likely than not to be sustained upon examination. The Company is subject to examination by U.S. Federal and State tax authorities from 2011 to the present, generally for three years after they are filed.

 

The Company did not file its income tax returns for fiscal year 2012 and 2013. The Company believes that it should not have any material impact on the financials because the Company did not have any tax liabilities due to net loss incurred for these years.

 

Basic and diluted net income (loss) per share

 

Basic net income (loss) per share is based upon the weighted average number of common shares outstanding. Diluted net income (loss) per share is based on the assumption that all dilutive convertible shares and stock options were converted or exercised. Dilution is computed by applying the treasury stock method.  Under this method, options and warrants are assumed to be exercised at the beginning of the period (or at the time of issuance, if later), and as if funds obtained thereby were used to purchase common stock at the average market price during the period. For years ended September 30, 2014 and 2013, all common stock equivalents were anti-dilutive.

 

Stock-based payments

 

Compensation costs for all share-based awards are measured based on the grant date fair value and are recognized over the vesting period. The Company has no awards with market or performance conditions. Excess tax benefits will be recognized as an addition to additional paid-in-capital.

 

Fair value of financial instruments

 

The accounting standards regarding fair value of financial instruments and related fair value measurements defines financial instruments and requires disclosure of the fair value of financial instruments held by the Company. The Company considers the carrying amount of cash and other current assets and liabilities to approximate their fair values because of the short period of time between the origination of such instruments and their expected realization.

The Company has also adopted ASC 820-10 which defines fair value, establishes a three-level valuation hierarchy for disclosures of fair value measurement and enhances disclosure requirements for fair value measures. The three levels are defined as follows:

 

	·	Level 1 inputs to the valuation methodology are quoted prices (unadjusted) for identical assets or liabilities in active markets.
	·	Level 2 inputs to the valuation methodology include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the assets or liability, either directly or indirectly, for substantially the full term of the financial instruments.
	·	Level 3 inputs to the valuation methodology are unobservable and significant to the fair value.

 

As of September 30, 2014 and 2013, the Company did not identify any assets or liabilities that are required to be presented on the balance sheet at fair value in accordance with ASC 820-10.

 

Reclassifications

 

Certain reclassifications have been made to the prior year financial statements in order for them to be in conformity with the current year presentation.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

Recent accounting pronouncements

 

In July 2013, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2013-11: Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists. The new guidance requires that unrecognized tax benefits be presented on a net basis with the deferred tax assets for such carryforwards. This new guidance is effective for fiscal years and interim periods within those years beginning after December 15, 2013. The adoption of the new provision did not have an material impact on the Company’s financial condition or results of operations.

 

2.

Equipment

 

In August 2011, the Company purchased a water truck for $35,759 cash. In October 2011, the Company's water truck was placed in service pursuant to a lease arrangement with an unaffiliated third party. The lease required the lessee to pay the Company $2,500 per month plus 10% of the revenue collected by the lessee from its use or sublease of the truck. The lease was for a term of two years and the lessee had the option to purchase the truck at the end of the lease term for 75% of the Company's purchase price.  During the year ended September 30, 2012, the Company terminated the lease and wrote off the lease income receivable of $5,616 as bad debt expense due to the lessee’s cash flow problems.

 

The Company calculated the depreciation of the truck using straight-line method with a useful life of three years. For the three months ended December 31, 2012, the Company recorded depreciation expense of $2,980.

 

On December 31, 2012, the Company entered into an agreement with a third party to sell the water truck for a cash amount of $25,000 and recorded a receivable of $21,316, net of a replacement cost of tires of $3,684. The Company received cash of $21,316 as full payment of the sale on January 3, 2013. In addition, the Company paid $4,858 title fees and commission for selling the water truck in January 2013. For the years ended September 30, 2014 and 2013, the Company recorded loss on disposal of fix asset of $0 and $5,265.

 

3.	Oil and Gas Properties

 

West Texas Royalties

 

In September 2011, the Company acquired a 31.25% working interest in an exploratory oil and gas drilling prospect covering 120 acres in Eastland County, Texas, for $127,123 cash.

 

In October 2011, West Texas Royalties, Inc., the operator of the Company's Eastland County prospect began drilling and fracturing operations. As of September 30, 2013, no revenue has yet to be derived from the wells.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

During the year ended September 30, 2013, the Company determined that the investment in the Eastland County oil and gas properties was impaired due to unsuccessful fracking process. Accordingly, the Company recorded impairment loss of $108,373 to write off the capitalized fracking costs. In addition, the Company determined and recorded its share of the asset retirement obligation of $10,000 for the year ended September 30, 2013.

 

Port Hudson Field, Baton Rouge Parish, Louisiana

 

Effective April 1, 2013, the Company acquired a 7.24625% working interest in the oil and gas leases, wells and attendant production in the Port Hudson field, Baton Rouge Parish, Louisiana, for a total consideration of $702,900. The Company’s working interest is subject to certain overriding royalty interests, subject to which it has a 5.65158% net revenue interest in the Port Hudson Field.

 

On April 5, 2014, we entered into an agreement with EnTek Partners, LLC for the sale of 44.1% of our working interest in the Port Hudson field for the total consideration of $290,000, less any payments received by us for production from the Port Hudson field occurring after January 1, 2014. Pursuant to our agreement with EnTek Partners, we sold to EnTek an undivided 3.1956% of 8/8^th working interest (2.4926% net revenue interest) out of the working interests in the Port Hudson field owned by us. The transactions under the Entek Partners agreement closed on April 16, 2014, with an effective date of January 1, 2014. After giving effect to the sale, we continue to hold a 4.0506% working interest (3.1595% net revenue interest) in Port Hudson field. During the year ended September 30, 2014, the Company recorded a loss on sale of the working interest of $19,983.

 

Pursuant to the same agreement, EnTek Partners has also agreed to provide to the Company $275,000 in non-recourse financing to pay for its share of a dual recompletion in the D-1 well at West Cam 225 property in exchange for its agreement to provide EnTek Partners with 75% of the net profits derived by the Company from the West Cam 225 property until such time as EnTek Partners has recouped 100% of the recompletion costs advanced on the Company’s behalf and 50% of the net profits thereafter.

 

West Cam 225, Louisiana

 

On August 16, 2013, the Company entered into an agreement with Enovation Resources, LLC to purchase a 10.0167% working interest (7.2120% net revenue interest) in an offshore oil and gas field, known as West Cam 225, located in the shallow waters of the Gulf of Mexico near Cameron, Louisiana. The Company’s purchase price for the working interest is $50,000. In addition to the purchase price, the Company paid $230,459 as advance for costs for development.

 

Wolfcamp Field

 

In June and July 2014, we acquired non-operating leases covering approximately 1,070 gross mineral acre leases in the Wolfcamp field located in Hale County, Texas. The leases were acquired for cash payments of $45,484. The leases have a primary term of five years with our option to extend the term for another five years. The leased properties constitute the surface acreage comprising a natural gas prospect, for which we hold 50% of the working interest and 40% net revenue interest. The leased properties are subject to a 20% royalty interest held by the owners and a third party. We are currently evaluating our options for the exploitation of the leased properties, including our sale of the leases or our farm-out of the leases to a natural gas operator.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

Sunshine Prospect, Landry Parish, Louisiana

 

On August 1, 2014, the Company entered into an agreement with Restech Resources, LLC to purchase a 15% (14.25% net revenue interest) in an oil and gas prospect located in Landry Parish, Louisiana. The working interest concerns 248 gross acres and net acres in the Sunshine Prospect. Our purchase price for the working interest was $76,500.

 

Birnie Field, Motley County, Texas

 

On September 17, 2014, the Company entered into an agreement with Escopeta Oil and Gas Corporation to purchase a 10% working interest (7.5% net revenue interest) in a natural gas prospect located in the Birnie field in Motley County, Texas. The working interest concerns 5,760 leased acres in the Palo Duro Basin prospect. Our purchase price for the working interest was $70,000.

 

As of September 30, 2014 and 2013, total oil and gas properties amounted to $885,810 and $1,002,109, respectively.

 

4.	Notes Payable – Related Parties

 

On August 14, 2013, the Company entered into a loan agreement with a shareholder, Gary Bryant, pursuant to which Mr. Bryant loaned the Company $417,762, the proceeds of which were used to partially finance the acquisition of the Port Hudson interest described in Note 3 above. The loan bears interest on the unpaid principal amount at the rate of 8% per annum. All principal and interest are payable over a four year period, commencing November 1, 2013, at the amortized rate of $10,198 per month. Our obligations under the loan are secured by our working interest in the Port Hudson field.

 

On September 6, 2013, the Company entered into another loan agreement with Mr. Gary Bryant, pursuant to which Mr. Bryant loaned us $130,000, the proceeds of which were used to partially finance our payment of our allocable expenses associated with our working interest in the West Cam 225 field, described in Note 3 above. The loan bears interest on the unpaid principal amount at the rate of 6% per annum. All principal and interest are payable on December 6, 2013 and are convertible into shares of our common stock, at the option of the holder, at the rate of $0.50 per share. Our obligations under the loan are secured by our working interest in the Port Hudson field. We also entered into an amendment to our loan agreement with Mr. Bryant dated August 14, 2013, in the original principal amount of $417,762, to provide that all principal and interest under that loan agreement are convertible into shares of our common stock, at the option of the holder, at the rate of $0.50 per share.

 

On September 6, 2013, the Company entered into a second loan agreement with a company controlled by one of the shareholders pursuant to which the lender loaned us $100,000. The proceeds of which were used to partially finance our payment of our allocable expenses associated with our working interest in the West Cam 225 field, described in Note 3 above. The loan carried interest on the unpaid principal amount at the rate of 6% per annum. All principal and interest were paid off in April 2014. Our obligations under the loan were secured by our working interest in the West Cam 225 field. In connection with the loan, we granted the lender a warrant to purchase 200,000 shares of our common stock, at an exercise price of $0.50 per share, over a two year period expiring on September 5, 2015. This note was fully paid off as of September 30, 2014.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

The Company determined that the fair value of the above conversion options and the warrants using the Black – Scholes model with the variables listed below:

 

	·	Volatility: 160%
	·	Risk free rate of return: 0.01% to 0.875%
	·	Expected term: 0.25 to 4 years

 

On September 16, 2014, the Company entered into a Note purchase agreement with Lake Oswego Oil Company, LLC, an Oregon limited liability company controlled by one of the shareholders, pursuant to which the Company sells a secured promissory note in the principal amount of $50,000, for a purchase price of $50,000. Interest was accrued on the unpaid principal balance of the note at the rate of six percent per annum. All principal and unpaid interest were paid off in the first quarter of 2015. As an inducement to the note holder to enter into this agreement, the Company hereby grants the note holder a warrant to purchase 100,000 shares of the Company’s $0.001 par value common stock, and the warrant shall be exercisable at $0.50 per share over a two year period expiring on September 16, 2019.

 

The Company determined that the fair value of the warrants using Black – Scholes model with the variable listed below:

 

	·	Volatility: 340%
	·	Risk free rate of return: 1.688%
	·	Expected term: 2 years

 

In connection with the issuance of the above notes, the Company recorded a note discount of $50,000 and $647,762 for the years ended September 30, 2014 and 2013, respectively, which are to be amortized over the lives of the notes. For the years ended September 30, 2014 and 2013, the Company recorded amortization of note discount of $253,607 and $106,388 as amortization of debt discount.

 

5.	Shareholder Advances

 

During the year ended September 30, 2014 and 2013, a shareholder advanced a total amount of $20,000 and $21,000 respectively, as advances to the Company to support its daily operations. These advances are due on demand and do not bear any interest. In the fiscal year 2013, $41,000 of shareholder advances were converted into 82,000 shares of the Company’s common stock. As of September 30, 2014 and 2013, the total outstanding amount due to the shareholder was $35,000 and $15,000, respectively.

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

6.	Shareholders’ Equity

 

The Company is authorized to issue 200,000,000 shares of common stock, par value of $0.001, and 10,000,000 shares of preferred stock, par value of $0.001.

 

Commencing on January 24, 2011, the Company began the sale of up to 2,000,000 shares of its common stock at $.25 per share in a private placement. During fiscal 2011, the Company sold 962,000 shares for gross proceeds of $240,500. No commissions were incurred with respect to these sales of stock.

 

On November 26, 2012, the Board of Directors of the Company approved the Private Placement Memorandum for an offering of 3,000,000 shares of the Company’s common stock at $0.50 per share. The Shares are being offered by the Company’s executive officers on a straight best-efforts basis. However, in the event the Company engages finders or FINRA member firms, the Company expects to pay finders’ fees or sales commissions of up to 10% of the gross offering proceeds.

 

On November 29, 2012 and January 10, 2013, the Company entered into subscription agreements with an existing shareholder to sell 140,000 shares of the Company’s common stock at $0.50 per share. Pursuant to the agreement, $41,000 of shareholder advances were converted into 82,000 shares and the balance of the subscription price in the amount of $29,000 were received upon signing of the subscription agreements.

 

During the year ended September 30, 2013, the Company entered into various subscription agreements with accredited investors to sell 890,900 shares of the Company’s common stock at $0.50 per share. The total amount of $445,450 was received upon signing of the subscription agreements.

 

During the year ended September 30, 2014, the Company entered into various subscription agreements with accredited investors to sell 336,000 shares of the Company’s common stock at $0.50 per share. The total amount of $168,000 was received upon signing of the subscription agreements.

 

As of September 30, 2014 and 2013, the Company had 14,415,400 and 14,079,400 shares of common stock issued and outstanding and had not issued any of its preferred stock.

 

On September 15, 2011, the Company adopted the West Texas Resources, Inc. 2011 Stock Incentive Plan (the “Plan”) providing for the grant of non-qualified stock options and incentive stock options to purchase its common stock and for grant of restricted and unrestricted grants. The Company has reserved 3,000,000 shares of its common stock under the Plan. All officers, directors, employees and consultants to the Company are eligible to participate under the Plan. The purpose of the Plan is to provide eligible participants with an opportunity to acquire an ownership interest in the Company.

 

The Company granted options to certain consultants to purchase 400,000 shares of the Company’s common stock. The options vest immediately and expire on September 15, 2016. The fair value of each share-based award was estimated using the Black-Scholes option pricing model or a lattice model. The fair value of these options, determined to be $65,402, was included in general and administrative expenses for the year ended September 30, 2011.

 

The following assumptions were used in the fair value method calculation:

 

	·	Volatility: 83%
	·	Risk free rate of return: 1%
	·	Expected term: 5 years

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

On March 7, 2014, the Company granted options to certain consultants to purchase 1,500,000 shares of the Company’s common stock. The options expire on March 7, 2019 and vest as following:

 

	·	200,000 shares to vest upon the date of grant;
	·	250,000 shares to vest upon the completion of financing of at least $250,000 during the first three months following the date of grant;
	·	400,000 shares to vest upon the completion of financing of at least $1,000,000 (inclusive of any financing amounts attributed to the above-described vesting condition) during the first six months following the date of grant;
	·	500,000 shares to vest upon the completion of financing of an additional of at least $5,000,000 (exclusive of any financing amounts attributed to the above-described vesting condition) during the first 18 months following the date of grant; and
	·	150,000 shares to vest upon the closing stock price of the Company trading at a VWAP of $3 per share, for twenty of thirty consecutive trading days within 18 months following the date of grant.

 

The fair value of the vested options for 200,000 shares, determined to be $116,137, was recorded in general and administrative expenses for the year ended September 30, 2014. The unvested options will be evaluated upon completion of the market or performance condition. During the year ended September 30, 2014, the Company did not complete the financing of $250,000. Therefore, no share was vested for the year ended September 30, 2014.

 

On March 11, 2014, the Company granted options to its officers to purchase a total of 200,000 shares of the Company’s common stock. The options expire on March 11, 2019 and vest immediately. The fair value of these options, determined to be $116,119 and was included in general and administrative expenses for the year ended September 30, 2014.

 

The following assumptions were used in the fair value method calculation:

 

	·	Volatility: 190%
	·	Risk free rate of return: 1.5%
	·	Expected term: 5 years

 

The following information applies to all options outstanding at September 30, 2014:

 

	·	Weighted average exercise price: $0.53
	·	Options outstanding and exercisable: 800,000
	·	Average remaining life: 4.00 years

 

 

WEST TEXAS RESOURCES, INC.

 

NOTES TO FINANCIAL STATEMENTS

 

September 30, 2014 and 2013

 

7.	Supplementary Oil and Gas Information (Unaudited)

 

Proved oil and gas reserve quantities are based on estimates prepared by the Company’s third party reservoir engineering firms Collarini Associates for 2014, and our management for 2013 in accordance with guidelines established by the Securities and Exchange Commission. There are numerous uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production and timing of development expenditures. The following reserve data represents those estimates only and should not be construed as being exact. All of the reserves are located in the United States.

 

The information for the Company’s interests of reserves as of September 30, 2014 are as follows: 

 

Net Remaining Reserves (in thousands)

		Oil (bbls)				Gas (MMcf)				Cond (bbls)				BOE (bbls)
Proved Developed Reserves
WC225			0				27				0				5
Port Hudson			14				0				0				14
Subtotal			14				27				0				19
Proved Undeveloped Reserves
WC 225			0				622				0				104
Port Hudson			1				0				0				1
Subtotal			1				622				0				105
Total Proved Reserves			15				649				0				123

 

Total Proved Net Developed Reserves (in thousands)

		Proved NBOE
Reserves as of September 30, 2013			157
Less Adjustment for Entek Deal			(12	)
Production during the year			(6	)
Less Collarini adjustment			(16	)
Reserves as of September 30, 2014			123

 

8.	Subsequent Event

 

Events subsequent to September 30, 2014 have been evaluated through the date these financial statements were issued to determine whether they should be disclosed to keep the financial statements from being misleading. Management found no other subsequent events that should be disclosed.

 

 

Item 9.

Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

 

Not applicable.

 

Item 9A.

Controls and Procedures

 

(a)  Evaluation of Disclosure Controls and Procedures.

 

Our management, with the participation of our chief executive officer and chief financial officer evaluated the effectiveness of our disclosure controls and procedures pursuant to Rule 15a-15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Based upon that evaluation, our management, including our chief executive officer and chief financial officer, concluded that for the reasons described below our disclosure controls and procedures were not effective as of September 30, 2014 in ensuring all material information required to be filed has been made known in a timely manner.

 

(b)  Changes in internal control over financial reporting.

 

There were no changes to our internal control over financial reporting, as defined in Rules 15a-15(f) under the Exchange Act that occurred during the fiscal quarter ended September 30, 2014 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

(c)  Management’s report on internal controls over financial reporting.

 

Our management is responsible for establishing and maintaining adequate internal controls over financial reporting, as defined under Rule 15a-15(f) under the Exchange Act. Our management has assessed the effectiveness of our internal controls over financial reporting as of September 30, 2014 based on the framework established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Our internal control system was designed to provide reasonable assurance to our management and board of directors regarding the preparation and fair presentation of published financial statements. An internal control material weakness is a significant deficiency, or aggregation of deficiencies, that does not reduce to a relatively low level the risk that material misstatements in financial statements will be prevented or detected on a timely basis by employees in the normal course of their work. Our management assessed the effectiveness of our internal control over financial reporting as of September 30, 2014, and this assessment identified the following material weaknesses in our internal control over financial reporting:

 

	·	Due to our small size, we do not maintain effective internal controls to assure segregation of duties as we have only two employees who are responsible for initiating and approving of transactions, thereby creating the segregation of duties weakness;
	·	Our board of directors does not have an audit committee or a financial expert to maintain effective oversight of our financial reporting process; and
	·	Lack of formal policies or procedures to provide assurance that relevant information is identified, captured, processed, and reported in an appropriate and timely fashion.

 

Based on that evaluation, management concluded that our internal control over financial reporting was not effective as of September 30, 2014.

 

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 the rules of the Securities and Exchange Commission that permit us to provide only management’s report in this annual report.

 

Item 9B.

Other Information

 

Not applicable.

 

 

PART III

 

Item 10.

Directors, Executive Officers and Corporate Governance

 

Set forth below are our directors and officers.

 

Name	Age	Position
Stephen E. Jones	44	Chairman of the Board, President and Chief Executive Officer
John D. Kerr	47	Chief Financial Officer and Director

 

Mr. Jones has served as our chairman of the board and president and chief executive officer since our founding on December 9, 2010. From February 2010 to December 2010, Mr. Jones also served as president and chief executive officer of Russian Resources Energy, Inc. Mr. Jones has served as vice president of mergers and acquisitions for Newport Capital Consultants, Inc., a Bartonville, Texas based financial and management and consulting firm, since 2004. Mr. Jones holds a BSB degree in marketing from Oklahoma City University.

 

Mr. Kerr has served as our chief financial officer and a member of our board of directors since our founding on December 9, 2010. For over the past five years, Mr. Kerr has served as a vice president of Newport Capital Consultants, Inc.

 

Mr. Jones and Mr. Kerr are each the son-in-law of Gary Bryant, our principal stockholder. Mr. Bryant is the chief executive officer and owner of Newport Capital Consultants, Inc.  Newport Capital Consultants, Inc. is an affiliate of our company.

 

Mr. Jones and Mr. Kerr have each committed to provide their full time to our company, however from our inception to date, and until such time as we receive significant additional capital, their duties to our company will not require their full business time. Until such time as they are required to provide their full time to our company, they will continue to provide services on a limited basis to Newport Capital Consultants, provided that their provision of services to Newport Capital Consultants does not interfere with or otherwise impair their provision of services to our company.

 

Audit and Compensation Committees

 

As of the date of this report, we have not established an audit or compensation committee in light of the fact that all of our directors also serve as executive officers of our corporation.

 

Code of Ethics

 

We have adopted a code of ethics for all our employees, including our chief executive officer, principal financial officer and principal accounting officer or controller, and/or persons performing similar functions.

 

Limitation of Liability of Directors and Indemnification of Directors and Officers

 

Nevada corporate law provides that corporations may include a provision in their articles of incorporation relieving directors of monetary liability for breach of their fiduciary duty as directors, provided that such provision shall not eliminate or limit the liability of a director (i) for any breach of the director's duty of loyalty to the corporation or its stockholders, (ii) for acts or omissions not in good faith and which involve a breach of the director’s duty to the corporation or intentional misconduct or a knowing violation of law, (iii) for unlawful payment of a dividend or unlawful stock purchase or redemption, or (iv) for any transaction from which the director derived an improper personal benefit. Our articles of incorporation provides that directors are not liable to us or our stockholders for monetary damages for breach of their fiduciary duty as directors to the fullest extent permitted by Nevada law. In addition to the foregoing, our bylaws provide that we may indemnify directors, officers, employees or agents to the fullest extent permitted by law and we have agreed to provide such indemnification to each of our directors.

 

 

The above provisions in our articles of incorporation and bylaws and in the written indemnity agreements may have the effect of reducing the likelihood of derivative litigation against directors and may discourage or deter stockholders or management from bringing a lawsuit against directors for breach of their fiduciary duty, even though such an action, if successful, might otherwise have benefited us and our stockholders. However, we believe that the foregoing provisions are necessary to attract and retain qualified persons as directors.

 

Insofar as indemnification for liabilities arising under the Securities Act may be permitted to our directors, officers and controlling persons pursuant to the foregoing provisions, or otherwise, we have been advised that in the opinion of the Securities and Exchange Commission, such indemnification is against public policy as expressed in the Securities Act and is, therefore, unenforceable.

 

Item 11.

Executive Compensation

 

Summary Compensation Table

 

The following table sets forth the compensation paid by us to our chief executive officer and to all other executive officers for services rendered during the fiscal years ended September 30, 2014 and 2013.

 

Name and Position (a)	Year (b)	Salary (c)	Bonus (d)	Stock Awards (e)	Option Awards (f)	All Other Compensation (g)	Total (h)
Stephen E. Jones, President	2014	$36,000	--	--	$58,060	--	$94,060
and CEO	2013	$36,000	--	--	--	--	$36,000
John D. Kerr, CFO	2014	$36,000	--	--	$58,060	--	$94,060
	2013	$36,000	--	--	--	--	$36,000

 

The dollar amounts in column (f) reflect the values of options as of the grant date for the year ended September 30. 2014, in accordance with ASC 718, Compensation-Stock Compensation and, therefore, do not necessarily reflect actual benefits received by the individuals. Assumptions used in the calculation of these amounts are included in Note 6 to our audited financial statements for the year ended September 30, 2014.

 

Narrative Disclosure to Summary Compensation Table

 

We have no employment agreements with executive management. Each of our executive officers receives a salary of $3,000 per month.  Our executive officers are not entitled to receive any other compensatory benefits or consideration, such as medical or life insurance, car allowances or the like. At such time as our executive officers provide their full business time to our company on a continuous basis, we expect to adjust upward the compensation and benefits payable to our executive officers appropriately. In March 2014, we granted to Mr. Jones and Mr. Kerr options to purchase 100,000 shares of our common stock, each, at an exercise price of $0.60 per share.

 

 

 

Outstanding Equity Awards at September 30, 2014

 

Option Awards
Name (a)		Number of Securities Underlying Unexercised Options (#) Exercisable (b)		Number of Securities Underlying Unexercised Options (#) Unexercisable (c)		Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Unearned Options (#) (d)		Option Exercise Price (e)		Option Expiration Date (mm/dd/yyyy) (f)
John D. Kerr		200,000		--		--		$0.25		09/15/2016
John D. Kerr		100,000		--		--		$0.60		09/15/2016
Stephen E. Jones		100,000		--		--		$0.60		03/11/2019

 

Compensation of Directors

 

We have not paid any directors’ fees or other compensation to our directors for their services as directors.  All of our directors receive reimbursement for out-of-pocket expenses for attending board of directors meetings.  We intend to appoint additional members to the board of directors, including outside or non-officer members to the board.   There are no understandings or arrangements at this time concerning the appointment of additional directors to our board, and we do not expect to be able to attract directors with significant oil and gas experience until such time as we raise significant additional capital.   Any future outside directors may receive an attendance fee for each meeting of the board of directors.  From time to time we may also engage certain future outside members of the board of directors to perform services on our behalf and we will compensate such persons for the services which they perform.

 

Section 16(A) Beneficial Ownership Reporting Compliance

 

Because our common stock is not registered under the Exchange Act, our officers, directors and 10% stockholders are not required to file with the SEC beneficial ownership reports under Section 16 of the Exchange Act.

 

 

Item 12.

Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

 

The following table sets forth certain information regarding the beneficial ownership of our common stock as of the date of this memorandum by:

 

●

each person who is known by us to be the beneficial owner of more than five percent (5%) of our issued and outstanding shares of common stock;

 

●

each of our directors, executive officers and nominees to become directors; and

 

●

all directors and executive officers as a group.

 

 

 

Name and Address		Number of Shares		Percentage Owned (1)
Stephen E. Jones (2)(3)		400,000		2.8%
John D. Kerr (2)(3)		400,000		2.8%
Gary Bryant (4)(5)		7,112,524		45.9%
Danilo Cacciamatta (6)		1,100,000		7.6%
Suzanne Bryant (4)		1,100,400		7.6%
Directors and executive officers as a group		800,000		5.4%

 

(1)

The percentage amounts for each reported person are based on 14,407,400 common shares issued and outstanding as of the date of this report.

 

(2)

The address for the stockholder is 5729 Lebanon Road, Suite 144, Frisco, Texas  75034.

 

(3)

The shares for John D. Kerr include 300,000 shares underlying presently exercisable options and the shares for Stephen Jones include 100,000 shares underlying a presently exercisable option.

 

(4)

Gary and Suzanne Bryant are married, however they disclaim any interest in the shares held by the other. The address for the Gary and Suzanne Bryant is 980 Noble Champions Way, Bartonville, Texas 76226.

 

(5)

The shares for Gary Bryant include 1,095,524 shares issuable upon conversion of convertible secured promissory note issued by us to Mr. Bryant.

 

(6)

The address for the Danilo Cacciamatta is 1360 Temple Hills Dr., Laguna Beach, CA 92651.

 

 

 

Item 13.

Certain Relationships and Related Transactions, and Director Independence

 

Related Party Transactions, Promoters and Director Independence

 

In addition to our executive officers and directors, Mr. Gary Bryant may be deemed to be a promoter of our company. Mr. Bryant and his wife, Suzanne Bryant, each purchased 100,000 shares of our common stock, at a purchase price of $0.25 per share, in connection with our 2011 private placement of common shares. From time to time, Mr. Bryant provides us with advances of funds. The advances are unsecured and do not accrue interest on the principal amount. During the fiscal year ended September 30, 2013, Mr. Bryant agreed to convert $41,000 of advances into 82,000 shares of our common stock at the rate of $0.50 per share. At the same time, Mr. Bryant purchased 24,000 shares of our common at a price of $0.50 per share. As of September 30, 2014 and 2013, the total outstanding amount of advances from Mr. Bryant were $35,000 and $15,000, respectively.

 

In addition to the advances provided by Mr. Bryant, during the fourth fiscal quarter of 2013 Mr. Bryant loaned us a total of $547,762 for purposes of financing a portion of the Port Hudson and West Cam 225 acquisitions, including a loan for $417,762, which bears interest on the unpaid principal amount at the rate of 8% per annum and is payable over a four year period at the amortized rate of $10,198 per month, and another loan for $130,000, which bears interest on the unpaid principal amount at the rate of 6% per annum and is payable on February 6, 2016. Our obligations under both loans are secured by our working interest in the Port Hudson field and all principal and interest under each loan is convertible, at the option of the holder, into our common shares at the rate of $0.50 per share.

 

Except for above-mentioned advances, loans and stock purchases by Mr. and Mrs. Bryant, and compensation paid or payable by us to our executive officers and reported elsewhere in this report, we have not entered into any other transactions of any value with any of our directors, officers, principal stockholders, promoters or any of their family members or affiliates, including entities of which they are also officers or directors or in which they have a financial interest.  We have, however, adopted a policy that any transactions that we might enter into with related parties or promoters will only be on terms consistent with industry standards and approved by a majority of the disinterested directors of our board.

 

Item 14. Principal Accountant Fees and Services

 

The following table sets forth the aggregate fees billed to us for services rendered to us for the years ended September 30, 2014 and 2013 by our independent registered public accounting firm, Farber Hass Hurley LLP, for the audit of our consolidated financial statements for the years ended September 30, 2014 and 2013, and assistance with the reporting requirements thereof, the review of our condensed consolidated financial statements included in our quarterly reports on Form 10-Q, the filing of our Form 8-K, the filing of our Form S-1and accounting and auditing assistance relative to acquisition accounting and reporting.

 

(amounts in thousands)		2014				2013
Audit Fees		$	56,030			$	7,500
Audit-Related Fees			–				4,000
		$	56,030			$	11,500

 

 

PART IV

 

Item 15. Exhibits and Financial Statement Schedules

 

(a) Financial statements

 

Reference is made to the Index and Financial Statements under Item 8 in Part II hereof where these documents are listed.

 

(b) Financial statement schedules

 

Financial statement schedules are either not required or the required information is included in the consolidated financial statements or notes thereto filed under Item 8 in Part II hereof.

 

(c) Exhibits

 

The exhibits to this Annual Report on Form 10-K are set forth below. The exhibit index indicates each management contract or compensatory plan or arrangement required to be filed as an exhibit.

 

Number		Exhibit Description		Method of Filing
3.1		Articles of Incorporation of the Registrant		Incorporated by reference from the Registrant’s Registration Statement on Form S-1 filed on December 9, 2011.
3.2		Amendment to Articles of Incorporation of the Registrant		Incorporated by reference from the Registrant’s Registration Statement on S-1 filed on December 9, 2011.
3.3		Bylaws of the Registrant		Incorporated by reference from the Registrant’s Registration Statement on S-1 filed on December 9, 2011.
10.1		West Texas Resources, Inc. 2011 Stock Incentive Plan*		Incorporated by reference from the Registrant’s Registration Statement on S-1 filed on December 9, 2011.
10.2		Lease Agreement dated August 22, 2011 between Registrant and Bay Energy Services, Inc.		Incorporated by reference from the Registrant’s Registration Statement on S-1 filed on December 9, 2011.
10.3		Form of Registration Rights Agreement dated January 24, 2011 between Registrant and Selling Stockholders		Incorporated by reference from the Registrant’s Registration Statement on S-1 filed on December 9, 2011.
10.4		Assignment dated September 30, 2011 between Registrant and West Texas Royalties, Inc.		Incorporated by reference from the Amendment No. 1 to Registrant’s Registration Statement on S-1 filed on January 23, 2012.
10.5		Joint Operating Agreement between Registrant and West Texas Royalties, Inc.		Incorporated by reference from the Amendment No. 1 to Registrant’s Registration Statement on S-1 filed on January 23, 2012.

 

 

10.6		Letter Agreement dated July 3, 2013 between the Registrant and Wells Fargo Energy Capital, Inc.		Incorporated by reference from the Registrant’s Quarterly Report on Form 10-Q filed on August 19, 2013
10.7		Letter Agreement dated August 1, 2013 between Registrant and Gulfex Resources, LLC		Incorporated by reference from the Registrant’s Quarterly Report on Form 10-Q filed on August 19, 2013
10.8		Loan Agreement dated August 14, 2013 between Registrant and Gary Bryant		Incorporated by reference from the Registrant’s Quarterly Report on Form 10-Q filed on August 19, 2013
10.9		Promissory Note dated August 14, 2013 made by Registrant in favor of Gary Bryant		Incorporated by reference from the Registrant’s Quarterly Report on Form 10-Q filed on August 19, 2013
10.10		Letter Agreement dated August 16, 2013 between Registrant and Enovation Resources LLC.		Incorporated by reference from the Registrant’s Quarterly Report on Form 10-Q filed on August 19, 2013
10.11		Loan Agreement dated September 5, 2013 between Registrant and Gary Bryant, as amended on January 10, 2014		Incorporated by reference from the Registrant’s Annual Report on Form 10-K filed on January14, 2014
10.12		Loan Agreement dated September 5, 2013 between Registrant and Lake Oswego Oil Company, LLC, as amended on January 10, 2014		Incorporated by reference from the Registrant’s Annual Report on Form 10-K filed on January14, 2014
10.13		Letter Agreement dated April 15, 2014 between the Registrant and EnTek Partners, LLC		Incorporated by reference from the Registrant’s Current Report on Form 8-K filed on April 21, 2014
14.1		West Texas Resources, Inc. Code of Ethics		Incorporated by reference from the Registrant’s Annual Report on Form 10-K filed on January 14, 2013
21.1		List of subsidiaries of Registrant.		Incorporated by reference from the Registrant’s Registration Statement on S-1 filed on December 9, 2011.
31.1		Certification under Section 302 of the Sarbanes-Oxley Act of 2002.		Filed electronically herewith.
31.2		Certification under Section 302 of the Sarbanes-Oxley Act of 2002.		Filed electronically herewith.
32.1		Certifications Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350.		Filed electronically herewith.
101.INS**		XBRL Instance Document		Filed electronically herewith
101.SCH**		XBRL Taxonomy Extension Schema Document		Filed electronically herewith
101.CAL**		XBRL Taxonomy Extension Calculation Linkbase Document		Filed electronically herewith
101.LAB**		XBRL Taxonomy Extension Label Linkbase Document		Filed electronically herewith
101.PRE**		XBRL Taxonomy Extension Presentation Linkbase Document		Filed electronically herewith
101.DEF**		XBRL Taxonomy Extension Definition Linkbase Document		Filed electronically herewith

 

 

* Indicates management compensatory plan, contract or arrangement.

 

** Pursuant to applicable securities laws and regulations, we are deemed to have complied with the reporting obligation relating to the submission of interactive data files in such exhibits and are not subject to liability under any anti-fraud provisions of the federal securities laws as long as we have made a good faith attempt to comply with the submission requirements and promptly amend the interactive data files after becoming aware that the interactive data files fail to comply with the submission requirements. Users of this data are advised that, pursuant to Rule 406T, these interactive data files are deemed not filed and otherwise are not subject to liability.

 

 

SIGNATURES

 

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this annual report on Form 10-K to be signed on its behalf by the undersigned, thereunto duly authorized.

 

	WEST TEXAS RESOURCES, INC.
Date: January 13, 2015	By:	/s/ Stephen E. Jones
		Stephen E. Jones,
		Chief Executive Officer

 

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

 

Signature		Title		Date
/s/ Stephen E. Jones		Chief Executive Officer		January 13, 2015
Stephen E. Jones		(Principal Executive Officer)
/s/John D. Kerr		Chief Accounting Officer		January 13, 2015
John D. Kerr		(Principal Financial Officer)