10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

  FORM 10-K

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

 For the fiscal year ended December 31, 2012

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

For the transition period from to     

Commission File No:  000-51465

United American Petroleum Corp.

 (Exact name of registrant as specified in its charter)

Nevada	20-1904354
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
9600 Great Hills Trail, Suite 150W, Austin, TX 78759
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (512) 852-7888
Securities registered under Section 12(b) of the Act: None.
Securities registered pursuant to section 12(g) of the Act:
Common Stock, Par Value $.001 (Title of Class)

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

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. x Yes      o  No

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of 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 file, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.

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

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

The aggregate market value of the registrant's shares of common stock held by non-affiliates of the registrant on June 30, 2012, the last business day of the registrant’s most recently completed second fiscal quarter was $14,884,543.

As of April 14, 2013, there were 50,339,543 shares of the issuer's $.001 par value common stock issued and outstanding.

 Documents incorporated by reference. There are no annual reports to security holders, proxy information statements, or any prospectus filed pursuant to Rule 424 of the Securities Act of 1933 incorporated herein by reference. 

TABLE OF CONTENTS

	PART I
		Page
Item 1.	Business	3
Item 1A.	Risk Factors	5
Item 1B.	Unresolved Staff Comments	13
Item 2.	Properties	14
Item 3.	Legal Proceedings	16
Item 4.	Mine Safety Disclosures	16
	PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	16
Item 6.	Selected Financial Data	18
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	19
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	27
Item 8.	Financial Statements and Supplementary Data	F-1
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	28
Item 9A.	Controls and Procedures	28
Item 9B.	Other Information	29
	PART III
Item 10.	Directors, Executive Officers and Corporate Governance	30
Item 11.	Executive Compensation	33
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	36
Item 13.	Certain Relationships and Related Transactions, and Director Independence	37
Item 14.	Principal Accounting Fees and Services	38
	PART IV
Item 15.	Exhibits, Financial Statement Schedules	39

PART I

Item 1.   Business.

Our Background.   United American Petroleum Corp. (“We” or the “Company”), formerly Forgehouse, Inc., was incorporated in the State of Nevada on November 19, 2004.  Pursuant to an Agreement and Plan of Exchange, dated January 31, 2008 (the “Exchange Agreement”), we acquired ForgeHouse LLC, a limited liability company.  Between January 31, 2008 and December 16, 2009, we were solely engaged in the business of developing and selling physical security industry application and software (the “Prior Business”).  On December 16, 2009, we supplemented that business with the acquisition of, our wholly-owned subsidiary, Northern Future Energy Corp., a Nevada corporation (“NFEC”), which is engaged in the oil and gas business. On December 29, 2009, we discontinued the Prior Business and established our principal business of the acquisition of leasehold interests in petroleum and natural gas rights, either directly or indirectly, and the exploitation and development of properties subject to these leases.

On December 31, 2010, we entered into and closed an Agreement and Plan of Merger (“Merger Agreement”) with our newly formed wholly-owned subsidiary, United PC Acquisition Corp., a Nevada corporation (“Merger Sub”), and United American Petroleum Corp., a Nevada Corporation (“United”) (the “Merger Transaction”), pursuant to which Merger Sub merged with and into United with United surviving, making United our new wholly-owned subsidiary.  Immediately thereafter and pursuant to the Merger Agreement, United merged with and into the Company, with the Company surviving and we changed our name to “United American Petroleum Corp.” In connection with the Merger Transaction, we assumed all of United’s contractual obligations and acquired certain oil and gas properties of United in Texas.

We have not undergone bankruptcy, receivership, or any similar proceeding.

Our Business.   We are an exploration company engaged in the acquisition, exploration, development and production of oil and gas properties.  Our principal business is the acquisition of leasehold interests in petroleum and natural gas rights, either directly or indirectly, and the exploitation and development of properties subject to these leases.  Our primary focus is to develop our properties that have potential for near-term production, We also provide operational expertise for several third party well owners out of our operational base in Austin, Texas. We currently have proved reserves in the State of Texas.

Our Subsidiaries

Northern Future Energy Corp.   In addition to our properties located in Texas, we also own certain oil and gas interests located near Anchorage, Alaska, through our wholly-owned subsidiary, Northern Future Energy Corp.  Northern Future Energy Corp. acquired an oil and gas lease for State of Alaska Oil and Gas Lease ADL 391120 Tract: CI2006-464, which contains approximately 545 acres, pursuant to a Purchase Agreement dated November 2009.  Production on the properties has not commenced and there can be no assurance that any hydrocarbons will be economically recoverable, if at all. As of the date of this report, the Company is evaluating its ability to pursue production activities on this property.

United Operating, LLC.   On January 13, 2011, we formed our wholly-owned subsidiary, United Operating, LLC, a Texas limited liability company, for the purpose of operating the Patriot Interests, including, but not limited to: (i) the Merrick Davis #16 & #17 wells in Shackelford County, TX; (ii) the Crouch and Lane Heady wells in Erath County, TX; (iii) the Merrick Davis wells in Shackelford County, TX; (iv) the Walker Smith #22D well in Wilbarger County, TX; and (v) the Walker Smith wells in Wilbarger County, TX.  United Operating, LLC, has not undergone bankruptcy, receivership, or any similar proceeding.

UAP Management, LLC.   On January 13, 2011, we formed our wholly-owned subsidiary, UAP Management, LLC, a Texas limited liability company, for the purpose of managing the Gabriel Interests in Bastrop county, Texas. UAP Management, LLC, has not undergone bankruptcy, receivership, or any similar proceeding.

3

Business Strategy.   Our strategy is to increase shareholder value through strategic acquisitions, appraisal drilling and development. We are focused on the acquisition, appraisal development and exploitation of oil properties.  We are also searching for possible joint-ventures and new prospects that fit our strategic focus.

Competition.   The oil and gas industry is intensely competitive.  We compete with numerous individuals and companies, including many major oil and gas companies, which have substantially greater technical, financial, and operational resources and staffs.  Accordingly, there is a high degree of competition for desirable oil and gas leases, suitable properties for drilling operations, and necessary drilling equipment, as well as for access to funds.

We will also compete with other junior oil and gas exploration companies for financing from a limited number of investors that are prepared to make investments in junior oil and gas exploration companies. The presence of competing junior oil and gas exploration companies may have an adverse impact on our ability to raise additional capital in order to fund our exploration programs if investors are of the view that investments in competitors are more attractive based on the merit of the oil and gas properties under investigation and the price of the investment offered to investors.

We also compete with other junior and senior oil and gas companies for available resources, including, but not limited to, professional exploration and production, geological and engineering personnel services and supplies, for the drilling completion and production of hydrocarbon resources.

Intellectual Property. We do not presently own any copyrights, patents or trademarks. We own the Internet domain name www.unitedamericanpetroleum.com, which includes information we do not desire to incorporate by reference into this filing. Under current domain name registration practices, no one else can obtain an identical domain name, but someone might obtain a similar name, or the identical name with a different suffix, such as “.org”, or with a country designation. The regulation of domain names in the United States and in foreign countries is subject to change, and we could be unable to prevent third parties from acquiring domain names that infringe or otherwise decrease the value of our domain names.

Government Regulation .  Our oil and gas operations are subject to various federal, state, and local governmental regulations.  Matters subject to regulation include discharge permits for drilling operations, drilling and abandonment bonds, reports concerning operations, the spacing of wells, and pooling of properties, and taxation.  From time to time, regulatory agencies have imposed price controls and limitations on production by restricting the rate of flow of oil and gas wells below actual production capacity in order to conserve supplies of oil and gas.  The production, handling, storage, transportation, and disposal of oil and gas, by-products thereof, and other substances and materials produced or used in connection with oil and gas operations are also subject to regulation under federal, state, provincial, and local laws and regulations relating primarily to the protection of human health and the environment.  To date, our expenditures related to complying with these laws, and for remediation of existing environmental contamination, have not been significant.  The requirements imposed by such laws and regulations are frequently changed and subject to interpretation, and we are unable to predict the ultimate cost of compliance with these requirements or their effect on our operations.

Employees .  As of December 31, 2012, we have three employees.  We expect to utilize independent contractors, consultants, and other personnel from time to time in a cost effective manner to assist in our business efforts.  

Our Facilities. As of December 31, 2012, we maintain our corporate offices for approximately $250 per month on a month to month basis.  We also maintain our operational offices for $1,600 per month on a month to month basis.  We believe our current office space and facilities are sufficient to meet our current and future needs.  We do not anticipate the need to secure additional space.

Internet Website.   Our website is located at www.unitedamericanpetroleum.com . Our website describes each of our oil and gas projects, our management and provides additional information regarding our industry.

Legal Proceedings. We are not a party to any pending legal proceeding.

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Item 1A. Risk Factors.

In addition to the other information in this filing, the following risk factors should be considered carefully in evaluating our business before purchasing any of our shares of common stock. A purchase of our common stock is speculative in nature and involves a lot of risks. No purchase of our common stock should be made by any person who is not in a position to lose the entire amount of his investment.

Risks Related to our Business:

We have a limited history operating in the oil and gas industry.  As a result, it is difficult for potential investors to evaluate our business and prospects.

We entered the oil and gas business in December 2009. Our limited operating history makes it difficult for potential investors to evaluate our business or prospective operations. Since our formation, we have generated only limited revenues. As an early stage company, we are subject to all the risks inherent in the financing, expenditures, operations, complications and delays inherent in a new business. Accordingly, our business and success faces risks from uncertainties faced by developing companies in a competitive environment. There can be no assurance that our efforts will be successful or that we will ultimately be able to attain profitability.

Because we are an exploration stage company, we have limited revenues to sustain our operations.

We are an exploration stage company that is currently developing our business. To date, our revenues have not been sufficient to support our operating and other expenses. The success of our business operations will depend upon our ability to further develop our properties and increase our revenues. We are not able to predict whether we will be able to develop our properties and generate more substantial revenues. If we are not able to complete the successful development of our business, generate more substantial revenues and attain sustainable operations, then our business will fail.

We have a history of net losses which will continue and which may negatively impact our ability to achieve our business objectives.

For fiscal years 2012 and 2011, United American Petroleum Corp., had revenue of $551,296 and $210,814 and a net loss of $6,077,652 and $1,083,341, respectively.  We cannot guarantee that our future operations will result in net income. We may not be able to operate profitability on a quarterly or annual basis in the future and we will likely continue to have net losses for the foreseeable future. If our revenues grow more slowly than we anticipate or our operating expenses exceed our expectations, our operating results will suffer.

We will need additional financing to execute our business plan.

The revenues from our current operations are not sufficient to support our operating costs and anticipated drilling programs. We will need substantial additional funds to:

· effectuate our business plan;

· fund the acquisition, exploration, development and production of oil and natural gas in the future;

· fund future drilling programs; and

· hire and retain key employees

We may seek additional funds through public or private equity or debt financing, via strategic transactions, and/or from other sources. There are no assurances that future funding will be available on favorable terms or at all. If additional funding is not obtained, we may need to reduce, defer or cancel drilling programs, planned initiatives, or overhead expenditures to the extent necessary. The failure to fund our operating and capital requirements could have a material adverse effect on our business, financial condition and results of operations.

Our auditors have expressed substantial doubt regarding our ability to continue operations as a “going concern.” Investors may lose all of their investment if we are unable to continue operations and generate revenues, or if we do not raise sufficient funds.

We will seek to raise additional funds to meet our working capital needs principally through the additional sales of our securities.  However, we cannot guaranty that we will be able to obtain sufficient additional funds when needed, or that such funds, if available, will be obtainable on terms satisfactory to us.  If we do not raise sufficient funds, we may not be able to continue in business.  As a result, our auditors believe that substantial doubt exists about our ability to continue operations as a going concern.

5

As many of our properties are in the exploration stage, there can be no assurance that we will establish commercial discoveries on our properties.

Exploration for economic reserves of oil and gas is subject to a number of risk factors.  Few properties that are explored are ultimately developed into producing oil and/or gas wells.  Our properties are in the exploration stage only and are without proven reserves of oil and gas.  Any profitability in the future from our business will be dependent upon locating and developing economic reserves of oil and gas, which itself is subject to numerous risk factors as set forth herein.  We may not establish commercial discoveries on any of our properties.

Our exploration appraisal and development activities are subject to many risks which may affect our ability to profitably extract oil reserves or achieve targeted returns.  In addition, continued growth requires that we acquire and successfully develop additional oil reserves.

Oil exploration may involve unprofitable efforts, not only from dry wells, but from wells that are productive but do not produce sufficient net revenues to return a profit after drilling, operating and other costs. Completion of a well does not assure a profit on the investment or recovery of drilling, completion and operating costs. In addition, drilling hazards or environmental damage could greatly increase the cost of operations, and various field operating conditions may negatively affect the production from successful wells. These conditions include delays in obtaining governmental approvals or consents, shut-ins of connected wells resulting from extreme weather conditions, insufficient storage or transportation capacity or other geological and mechanical conditions. While diligent well supervision and effective maintenance operations can contribute to maximizing production rates over time, production delays and declines from normal field operating conditions cannot be eliminated and can be expected to negatively affect revenue and cash flow levels to varying degrees.

Our ability to successfully market and sell oil is subject to a number of factors that are beyond our control, and that may adversely impact our ability to produce and sell oil, or to achieve profitability.

The marketability and price of oil that may be acquired or discovered by us will be affected by numerous factors beyond our control.  Our ability to market our oil may depend upon our ability to acquire space on pipelines that deliver oil to commercial markets. We may be affected by deliverability uncertainties related to the proximity of our reserves to pipelines and processing facilities, by operational problems with such pipelines and facilities, and by government regulation relating to price, taxes, royalties, land tenure, allowable production, the export of oil and by many other aspects of the oil business.

Our revenues and future growth and the carrying value of our oil properties are substantially dependent on prevailing prices of oil. Our ability to borrow and to obtain additional capital on attractive terms is also substantially dependent upon oil and natural gas prices. Prices for oil and natural gas are subject to large fluctuations in response to relatively minor changes in the supply of and demand for oil, market uncertainty and a variety of additional factors beyond our control. These factors include economic conditions, in the United States and Canada, the actions of the Organization of Petroleum Exporting Countries, governmental regulation, political stability in the Middle East and elsewhere, the foreign supply of oil, the price of foreign imports and the availability of alternative fuel sources. Any substantial and extended decline in the price of oil would have an adverse effect on our borrowing capacity, revenues, profitability and cash flows from operations.

Volatile oil prices make it difficult to estimate the value of producing properties for acquisition and often cause disruption in the market for oil producing properties, as buyers and sellers have difficulty agreeing on such value. Price volatility also makes it difficult to budget for and project the return on acquisitions and development and exploitation projects.

Our reserve estimates are subject to numerous uncertainties and may be inaccurate.

We currently have proved reserves in Texas. We rely on independent third party petroleum engineering firms to calculate reserve estimates. There are numerous uncertainties inherent in estimating quantities of oil and natural gas reserves and cash flows to be derived therefrom, including many factors beyond our control. In general, estimates of economically recoverable oil and gas reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, marketability of our products, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which may vary from actual results. All such estimates are to some degree speculative, and classifications of reserves are only attempts to define the degree of speculation involved. For those reasons, estimates of the economically recoverable reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues expected therefrom prepared by different engineers, or by the same engineers at different times, may vary. Our actual production, revenues, taxes and development and operating expenditures with respect to our reserves will vary from estimates thereof and such variations could be material.

Estimates of proved or unproved reserves that may be developed and produced in the future are often based upon volumetric calculations and upon analogy to similar types of reserves rather than actual production history. Estimates based on these methods are generally less reliable than those based on actual production history. Subsequent evaluation of the same reserves based upon production history and production practices will result in variations in the estimated reserves and such variations could be material.

6

We cannot guaranty that title to our properties does not contain a defect that may materially affect our interest in those properties.

It is our practice in acquiring significant oil leases or interest in oil leases to retain lawyers to fully examine the title to the interest under the lease.  In the case of minor acquisitions, we rely upon the judgment of oil lease brokers or landmen who do the field work in examining records in the appropriate governmental office before attempting to place under lease a specific interest. We believe that this practice is widely followed in the oil industry. Nevertheless, there may be title defects which affect lands comprising a portion of our properties which may adversely affect us.

Our properties are held in the form of leases and working interests in operating agreements and leases. If the specific requirements of such licenses, leases and working interests are not met, the lease or working interest may terminate or expire.

All of our properties are held under interests in oil and gas leases and working interests in operating agreements and leases. If we fail to meet the specific requirements of each lease or working interest, especially future drilling and production requirements, the lease may be terminated or otherwise expire. We cannot be assured that we will be able to meet our obligations under each lease and working interest. The termination or expiration of our working interest relating to any lease would harm our business, financial condition and results of operations.

Competition in the oil and gas industry is highly competitive and there is no assurance that we will be successful in acquiring properties or leases.

The oil and gas industry is intensely competitive.  We compete with numerous individuals and companies, including many major oil and gas companies, which have substantially greater technical, financial, and operational resources and staff.  Accordingly, there is a high degree of competition for desirable oil and gas leases, suitable properties for drilling operations, and necessary drilling equipment, as well as for access to funds. We cannot predict if the necessary funds can be raised or that any projected work will be completed.  Desirable acreage may not become available or if it is available for leasing, that we may not be successful in acquiring the leases.

The marketability of natural resources will be affected by numerous factors beyond our control which may result in us not receiving an adequate return on invested capital to be profitable or viable.

The marketability of natural resources which may be acquired or discovered by us will be affected by numerous factors beyond our control.  These factors include market fluctuations in oil and gas pricing and demand, the proximity and capacity of natural resource markets and processing equipment, governmental regulations, land tenure, land use, regulation concerning the importing and exporting of oil and gas, and environmental protection regulations.  The exact effect of these factors cannot be accurately predicted, but the combination of these factors may result in us not receiving an adequate return on invested capital to be profitable or viable. 

Oil and gas operations are subject to comprehensive regulation, which may cause substantial delays or require capital outlays in excess of those anticipated, causing an adverse effect on us.

Our operations are subject to regulation at the federal, state and local levels, including regulation relating to matters such as the exploration for and the development, production, marketing, pricing, transmission and storage of oil, as well as environmental and safety matters.  Failure to comply with applicable regulations could result in fines or penalties being owed to third parties or governmental entities, the payment of which could negatively impact our financial condition or results of operations.  Our operations are subject to significant laws and regulations, which may negatively affect our ability to conduct business or increase our costs.  Extensive federal, state and local laws and regulations relating to health and environmental quality in the United States affect nearly all of our operations.  These laws and regulations set various standards regulating various aspects of health and environmental quality, provide for penalties and other liabilities for the violation of these standards, and in some circumstances, establish obligations to remediate current and former facilities and off-site locations.

Environmental legislation provides for, among other things, restrictions and prohibitions on spills, releases or emissions of various substances produced in association with oil operations. The legislation also requires that wells and facility sites be operated, maintained, abandoned and reclaimed to the satisfaction of the applicable regulatory authorities. Compliance with such legislation can require significant expenditures and a breach may result in the imposition of fines and penalties, some of which may be material. Environmental legislation is evolving in a manner expected to result in stricter standards and enforcement, larger fines and liability and potentially increased capital expenditures and operating costs. The discharge of oil or other pollutants into the air, soil or water may give rise to liabilities to governments and third parties and may require us to incur costs to remedy such discharge. No assurance can be given that environmental laws will not result in a curtailment of production or a material increase in the costs of production, development or exploration activities or otherwise adversely impact our financial condition, results of operations or prospects.  We could incur significant liability for damages, clean-up costs and/or penalties in the event of discharges into the environment, environmental damage caused by us or previous owners of our property or non-compliance with environmental laws or regulations. In addition to actions brought by governmental agencies, we could face actions brought by private parties or citizens groups.

Moreover, we cannot predict what legislation or regulations will be enacted in the future or how existing or future laws or regulations will be administered, enforced or made more stringent. Compliance with more stringent laws or regulations, or more vigorous enforcement policies of the regulatory agencies, could require us to make material expenditures for the installation and operation of systems and equipment for remedial measures, all of which could have a material adverse effect on our financial condition or results of operations.

7

Exploratory drilling involves many risks and we may become liable for pollution or other liabilities, which may have an adverse effect on our financial position.

Drilling operations generally involve a high degree of risk.  Hazards such as unusual or unexpected geological formations, power outages, labor disruptions, blow-outs, sour gas leakage, fire, inability to obtain suitable or adequate machinery, equipment or labor, and other risks are involved.  We may become subject to liability for pollution or hazards against which we cannot adequately insure or that we may elect not to insure.  Incurring any such liability may have a material adverse effect on our financial position and operations.

Our exploration and development activities will depend in part on the evaluation of data obtained through geophysical testing and geological analysis, as well as test drilling activity.

The results of geophysical testing and geological analysis are subjective, and we cannot guarantee that the exploration and development activities we conduct based on positive analysis will produce oil or gas in commercial quantities or costs. As we perform developmental and exploratory activities, further data required for evaluation of our oil and gas interests will become available. The exploration and development activities that will be undertaken by us are subject to greater risks than those associated with the acquisition and ownership of producing properties. The drilling of development wells, although generally consisting of drilling to reservoirs believed to be productive, may result in dry holes or a failure to produce oil or gas in commercial quantities. Moreover, any drilling of exploratory wells is subject to significant risk of dry holes.

Because we are small and have limited access to additional capital, we may have to limit our exploration activity, which may result in a loss of investment.

We have a small asset base and limited access to additional capital. Accordingly, we must limit our exploration activity. As such, we may not be able to complete an exploration program that is as thorough as our management would like. In that event, existing reserves may go undiscovered. Without finding reserves, we cannot generate revenues and investors may lose their investment.

Seasonal weather conditions and other factors could adversely affect our ability to conduct drilling activities.

Our operations could be adversely affected by seasonal weather conditions and wildlife restrictions on federal leases. In some areas, certain drilling and other oil and gas activities can only be conducted during limited times of the year, typically during the summer months. This would limit our ability to operate in these areas and could intensify competition during those times for drilling rigs, oil field equipment, services, supplies and qualified personnel, which may lead to periodic shortages. These constraints and the resulting shortages or high costs could delay our operations and materially increase our operating and capital costs, which could have a material adverse effect upon us and our results of operations.

We depend on the services of third parties for material aspects of our operations, including drilling operators, and accordingly if we cannot obtain certain third party services, we may not be able to operate.

We rely on third parties to operate some of the assets in which we possess an interest. The success of our oil operations, whether considered on the basis of drilling operations or production operations, will depend largely on whether the operator of the property properly fulfills our obligations.  As a result, our ability to exercise influence over the operation of these assets or their associated costs may be limited.  Our performance will therefore depend upon a number of factors that may be outside of our full control, including the timing and amount of capital expenditures, the operator’s expertise and financial resources, the approval of other participants, the selection of technology, and risk management practices.  The failure of third party operators and their contractors to perform their services in a proper manner could adversely affect our operations.

We will need additional financing to continue and grow our operations, which financing may not be available on acceptable terms or at all.

We will need to raise additional funds to fund our operations or grow our business.  Additional financing may not be available on terms or at times favorable to us, or at all.  If adequate funds are not available when required or on acceptable terms, we may be unable to continue and grow our operations.  In addition, such additional financing transactions, if successful, may result in additional dilution of our stockholders.  They may also result in the issuance of securities with rights, preferences, and other characteristics superior to those of the common stock and, in the case of debt or preferred stock financings, may subject us to covenants that restrict our ability to operate our business freely.

The loss or unavailability of our key personnel for an extended period of time could adversely affect our business operations and prospects.

Our success depends in large measure on certain key personnel, including Michael Carey, our President and Chief Executive Officer and Ryan Hudson, our Secretary and Chief Operating Officer. The loss of the services of Mr. Carey and/or Mr. Hudson could significantly hinder our operations.  Although we are looking into acquiring key person insurance, we do not currently have such insurance in effect for Mr. Carey or Mr. Hudson. In addition, the competition for qualified personnel in the oil industry is intense and there can be no assurance that we will be able to continue to attract and retain all personnel necessary for the development and operation of our business. 

8

The costs and effects of litigation, investigations, or similar matters could adversely affect our financial position and result of operations.

We may be involved from time to time in a variety of litigation, investigations, or similar matters arising out of our business.  Our insurance may not cover all claims that may be asserted against us, and any claims asserted against us, regardless of merit or eventual outcome, may harm our reputation.  If the ultimate judgments or settlements in any litigation or investigation significantly exceed insurance coverage, they could adversely affect our financial position and results of operations.  In addition, we may be unable to obtain appropriate types or levels of insurance in the future.

We are subject to the reporting requirements of federal securities laws, which will be expensive.

We are a public reporting company in the U.S. and, accordingly, subject to the information and reporting requirements of the Exchange Act and other federal securities laws, and the compliance obligations of the Sarbanes-Oxley Act. The costs of preparing and filing annual and quarterly reports, proxy statements and other information with the SEC and furnishing audited reports to stockholders will cause our expenses to be higher than they would be if we remained a privately-held company.

Our compliance with the Sarbanes-Oxley Act and SEC rules concerning internal controls is time consuming, difficult and costly.

We are a reporting company with the SEC and therefore must comply with Sarbanes-Oxley Act and SEC rules concerning internal controls.  It is time consuming, difficult and costly for us to develop and implement the internal controls and reporting procedures required by Sarbanes-Oxley.  In order to expand our operations, we  will need to hire additional financial reporting, internal control, and other finance staff in order to develop and implement appropriate internal controls and reporting procedures. If we are unable to comply with Sarbanes-Oxley’s internal controls requirements, we may not be able to obtain the independent accountant certifications that Sarbanes-Oxley Act requires us to obtain.

Failure to maintain the adequacy of our internal controls could impair our ability to provide accurate financial statements and comply with the requirements of the Sarbanes-Oxley Act, which could cause our stock price to decrease substantially.

We intend to amend certain of our prior periodic reports to include required disclosures that were previously omitted from those periodic reports. The filing of amendments to those periodic reports will necessitate a redetermination of the effectiveness of our internal controls over financial reporting and disclosure controls and procedures for those periods.   We have committed limited personnel and resources to the development of the external reporting and compliance obligations that are required of a public company. We have taken measures to address and improve our financial reporting and compliance capabilities and we are in the process of instituting changes to satisfy our obligations in connection with being a public company. We plan to obtain additional financial and accounting resources to support and enhance our ability to meet the requirements of being a public company. We will need to continue to improve our financial and managerial controls, reporting systems and procedures, and documentation thereof. If our financial and managerial controls, reporting systems, or procedures fail, we may not be able to provide accurate financial statements on a timely basis or comply with the Sarbanes-Oxley Act of 2002 as it applies to us. Any failure of our internal controls or our ability to provide accurate financial statements could cause the trading price of our common stock to decrease substantially.

9

Risks Related to our Common Stock

The exercise of outstanding warrants may cause immediate and substantial dilution to our existing stockholders.

If the price per share of our common stock at the time of conversion of our senior secured convertible promissory notes, and exercise of any warrants, options, or any other convertible securities is in excess of the various conversion or exercise prices of these convertible securities, conversion or exercise of these convertible securities would have a dilutive effect on our common stock. As of December 31, 2012, we had warrants to purchase up to 2,800,000 shares of our common stock at an exercise price of $1.00 per share. Further, any additional financing that we secure may require the granting of rights, preferences or privileges senior to those of our common stock and which result in additional dilution of the existing ownership interests of our common stockholders.

Our common shares are thinly-traded, and you may be unable to sell at or near ask prices or at all if you need to sell your shares or otherwise desire to liquidate such shares.

We cannot predict the extent to which an active public market for our common stock will develop or be sustained due to a number of factors, including the fact that we are a small company that is relatively unknown to stock analysts, stock brokers, institutional investors, and others in the investment community that generate or influence sales volume, and that even if we came to the attention of such persons, they tend to be risk-averse and would be reluctant to follow an unproven company such as ours or purchase or recommend the purchase of our shares until such time as we became more seasoned and viable. As a consequence, there may be periods of several days or more when trading activity in our shares is minimal or non-existent, as compared to a seasoned issuer which has a large and steady volume of trading activity that will generally support continuous sales without an adverse effect on share price. We cannot give you any assurance that a broader or more active public trading market for our common stock will develop or be sustained, or that current trading levels will be sustained.

The market price for our common stock may be particularly volatile given our status as a relatively small company with a thinly-traded “float” and lack of significant revenues that could lead to wide fluctuations in our share price. You may be unable to sell your common stock at or above your purchase price if at all, which may result in substantial losses to you.

The market for our common shares may be characterized by significant price volatility when compared to seasoned issuers, and we expect that our share price will be more volatile than a seasoned issuer for the indefinite future. The potential volatility in our share price is attributable to a number of factors. First, as noted above, our common shares may be sporadically and/or thinly traded. As a consequence of this lack of liquidity, the trading of relatively small quantities of shares by our stockholders may disproportionately influence the price of those shares in either direction. The price for our shares could, for example, decline precipitously in the event that a large number of our common shares are sold on the market without commensurate demand, as compared to a seasoned issuer that could better absorb those sales without adverse impact on its share price. Secondly, an investment in us is a speculative or “risky” investment due to our lack of revenues or profits to date and uncertainty of future market acceptance for current and potential products. As a consequence of this enhanced risk, more risk-adverse investors may, under the fear of losing all or most of their investment in the event of negative news or lack of progress, be more inclined to sell their shares on the market more quickly and at greater discounts than would be the case with the stock of a seasoned issuer.

Stockholders should be aware that, according to SEC Release No. 34-29093, the market for penny stocks has suffered in recent years from patterns of fraud and abuse. Such patterns include (1) control of the market for the security by one or a few broker-dealers that are often related to the promoter or issuer; (2) manipulation of prices through pre-arranged matching of purchases and sales and false and misleading press releases; (3) boiler room practices involving high-pressure sales tactics and unrealistic price projections by inexperienced sales persons; (4) excessive and undisclosed bid-ask differential and markups by selling broker-dealers; and (5) the wholesale dumping of the same securities by promoters and broker-dealers after prices have been manipulated to a desired level, along with the resulting inevitable collapse of those prices and with consequent investor losses. The occurrence of these patterns or practices could increase the volatility of our share price.

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If a trading market for our common shares does develop, trading prices may be volatile.

In the event that an orderly trading market develops and is maintained for our common shares, the market price of such shares may be based on factors that may not be indicative of future market performance.  Consequently, the market price of our shares may vary greatly.  If an orderly market for our shares develops and is maintained, there is a significant risk that our share price may fluctuate dramatically in the future in response to any of the following factors, some of which are beyond our control:

• variations in our operating results;

• changes in expectations of our future financial performance, including financial estimates by securities analysts and investors;

• changes in operating and stock price performance of other companies in our industry;

• additions or departures of key personnel; and

• future sales of our common stock.

Domestic and international stock markets often experience significant price and volume fluctuations. These fluctuations, as well as general economic and political conditions unrelated to our performance, may adversely affect the price of our common stock. In particular, following initial public offerings, the market prices for stocks of companies often reach levels that bear no established relationship to the operating performance of these companies. These market prices are generally not sustainable and could vary widely. In the past, following periods of volatility in the market price of a public company’s securities, securities class action litigation has often been initiated.

The issuance of common stock upon conversion of the Convertible Notes will cause immediate and substantial dilution.

The issuance of common stock upon conversion of the Convertible Notes (defined and described below under “Liquidity and Capital Resources”) will result in immediate and substantial dilution to the interests of other stockholders since the holders of the Convertible Notes may ultimately receive and sell the full amount of shares issuable in connection with the conversion of such Convertible Notes. Although the Convertible Notes may not be converted if such conversion would cause the holder thereof to own more than 4.99% of our outstanding common stock, this restriction does not prevent the holders of the Convertible Notes from converting some of their holdings, selling those shares, and then converting the rest of their holdings, while still staying below the 4.99% limit. In this way, the holders of the Convertible Notes could sell more than this limit while never actually holding more shares than this limit allows. If the holders of the Convertible Notes choose to do this, it will cause substantial dilution to the then holders of our common stock.

The continuously adjustable conversion price feature of our Convertible Notes could require us to issue a substantially greater number of shares, which may adversely affect the market price of our common stock and cause dilution to our existing stockholders.

Our existing stockholders will experience substantial dilution of their investment upon conversion of the Convertible Notes. The Convertible Notes are convertible into shares of common stock at a conversion price equal to (a) the lesser of $0.11 per share or 60% of the lowest trading price of the Company’s common stock in the 25 days prior to any conversion (subject to certain adjustments), and (b) the greater of (i) 60% of the average of the five lowest trading prices of the Company’s common stock during the ten trading days prior to such conversion date; and (ii) $0.00005 per share, respectively. As a result, the number of shares issuable could prove to be significantly greater in the event of a decrease in the trading price of our common stock, which decrease would cause substantial dilution to our existing stockholders. As sequential conversions and sales take place, the price of our common stock may decline, and if so, the holders of the Convertible Notes would be entitled to receive an increasing number of shares, which could then be sold, triggering further price declines and conversions for even larger numbers of shares, which would cause additional dilution to our existing stockholders and would likely cause the value of our common stock to decline.

The continuously adjustable conversion price feature of our Convertible Notes may encourage the holder of the Convertible Notes to sell short our common stock, which could have a depressive effect on the price of our common stock.

The Convertible Notes are convertible into shares of our common stock at a discount to the trading price of our common stock as discussed above. The significant downward pressure on the price of our common stock as the holders of the Convertible Notes convert and sell material amounts of our common stock could encourage investors to short sell our common stock. This could place further downward pressure on the price of our common stock. In addition, not only the sale of shares issued upon conversion of the Convertible Notes, but also the mere perception that these sales could occur, may adversely affect the market price of our common stock.

Volatility in our common stock price may subject us to securities litigation.

The market for our common stock is characterized by significant price volatility when compared to seasoned issuers, and we expect that our share price will continue to be more volatile than a seasoned issuer for the indefinite future. In the past, plaintiffs have often initiated securities class action litigation against a company following periods of volatility in the market price of its securities. We may, in the future, be the target of similar litigation. Securities litigation could result in substantial costs and liabilities and could divert management’s attention and resources.

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We do not anticipate paying any cash dividends.

We presently do not anticipate that we will pay any dividends on any of our capital stock in the foreseeable future. The payment of dividends, if any, would be contingent upon our revenues and earnings, if any, capital requirements, and general financial condition. The payment of any dividends will be within the discretion of our Board of Directors. We presently intend to retain all earnings, if any, to implement our business plan; accordingly, we do not anticipate the declaration of any dividends in the foreseeable future.

Because we may be subject to the “penny stock” rules, the level of trading activity in our stock may be reduced which may make it difficult for investors to sell their shares.

Broker-dealer practices in connection with transactions in “penny stocks” are regulated by certain penny stock rules adopted by the Securities and Exchange Commission. Penny stocks, like shares of our common stock, generally are equity securities with a price of less than $5.00, other than securities registered on certain national securities exchanges or quoted on NASDAQ. The penny stock rules require a broker-dealer, prior to a transaction in a penny stock not otherwise exempt from the rules, to deliver a standardized risk disclosure document that provides information about penny stocks and the nature and level of risks in the penny stock market. The broker-dealer also must provide the customer with current bid and offer quotations for the penny stock, the compensation of the broker-dealer and its salesperson in the transaction, and, if the broker-dealer is the sole market maker, the broker-dealer must disclose this fact and the broker-dealer’s presumed control over the market, and monthly account statements showing the market value of each penny stock held in the customer’s account. In addition, broker-dealers who sell these securities to persons other than established customers and “accredited investors” must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser’s written agreement to the transaction. Consequently, these requirements may have the effect of reducing the level of trading activity, if any, in the secondary market for a security subject to the penny stock rules, and investors in our common stock may find it difficult to sell their shares.

We will need additional capital, and the sale of additional shares or other equity securities could result in additional dilution to our stockholders.

We believe that our current cash and cash equivalents and anticipated cash flow from operations will not be sufficient to meet our anticipated cash needs for the near future. We will require additional cash resources due to changed business conditions or other future developments, including any investments or acquisitions we may decide to pursue. If our resources are insufficient to satisfy our cash requirements, we will seek to sell additional equity or debt securities or obtain a credit facility. The sale of additional equity securities could result in additional dilution to our stockholders. The incurrence of additional indebtedness would result in increased debt service obligations and could result in operating and financing covenants that would restrict our operations. We cannot assure you that financing will be available in amounts or on terms acceptable to us, if at all.

We lack a public market for shares of our common stock, which may make it difficult for investors to sell their shares.

There is no public market for shares of our common stock. We cannot guaranty that an active public market will develop or be sustained. Therefore, investors may not be able to find purchasers for their shares of our common stock. Should there develop a significant market for our shares, the market price for those shares may be significantly affected by such factors as our financial results and introduction of new products and services.  Factors such as announcements of new services by us or our competitors and quarter-to-quarter variations in our results of operations, as well as market conditions in our sector may have a significant impact on the market price of our shares. Further, the stock market has experienced extreme volatility that has particularly affected the market prices of stock of many companies and that often has been unrelated or disproportionate to the operating performance of those companies.

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The Company has established preferred stock which can be designated by the Company’s directors without shareholder approval and has established Series B Preferred Stock, which gives the holders majority voting power over the Company.

The Company has 10,000,000 shares of preferred stock authorized and 1,000 shares of Series B Preferred Stock designated.  As of the filing date of this report, the Company has 1,000 Series B Preferred Stock shares issued and outstanding, which shares are held by Michael Carey, the Company’s Chief Executive Officer, President and Director (500 shares), and Ryan Hudson, the Company’s Chief Operating Officer, Secretary and Director (500 shares). The Series B Preferred Stock have no dividend rights, no liquidation preference, no redemption rights and no conversion rights. The Series B Preferred Stock have the right, voting in aggregate, to vote on all shareholder matters (including, but not limited to, at every meeting of the stockholders of the Company and upon any action taken by stockholders of the Company with or without a meeting) equal to fifty-one percent (51%) of the total vote (the “Super Majority Voting Rights”). Additionally, we are not allowed to adopt any amendments to our Bylaws, Articles of Incorporation, as amended, make any changes to the Certificate of Designations establishing the Series B Preferred Stock, or effect any reclassification of the Series B Preferred Stock, without the affirmative vote of at least 66-2/3% of the outstanding shares of the Series B Preferred Stock.

Additional shares of preferred stock of the Company may be issued from time to time in one or more series, each of which shall have distinctive designation or title as shall be determined by the Board of Directors of the Company, prior to the issuance of any shares thereof. The preferred stock shall have such voting powers, full or limited, or no voting powers, and such preferences and relative, participating, optional or other special rights and such qualifications, limitations or restrictions thereof as adopted by the Board of Directors. Because the Board of Directors is able to designate the powers and preferences of the preferred stock without the vote of a majority of the Company’s shareholders, shareholders of the Company will have no control over what designations and preferences the Company’s preferred stock will have. As a result of this, the Company’s shareholders may have less control over the designations and preferences of the preferred stock and as a result the operations of the Company.

Our board of directors has the authority, without stockholder approval, to issue preferred stock with terms that may not be beneficial to common stockholders and may grant voting powers, rights and preference that differ from or may be superior to those of our shares of common stock.

Our articles of incorporation allow us to issue 10,000,000 shares of preferred stock without any vote or further action by our stockholders. Our board of directors has the authority to fix and determine the relative rights and preferences of preferred stock. Our board of directors also has the authority to issue preferred stock without further stockholder approval, including large blocks of preferred stock. As a result, our board of directors could authorize the issuance of a series of preferred stock that would grant to holders the preferred right to our assets upon liquidation, the right to receive dividend payments before dividends are distributed to the holders of common stock and the right to the redemption of the shares, together with a premium, prior to the redemption of our common stock.

Item 1B. Unresolved Staff Comments.

Not applicable to smaller reporting companies.

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Item 2.  Properties.

Our Facilities. As of December 31, 2012, we maintain our corporate offices for approximately $200 per month on a month to month basis.  We also maintain our operational offices of approximately 1,600 square feet for $1,600 per month on a month to month basis.  We believe our current office space and facilities are sufficient to meet our current and future needs .  

Our Properties.   On December 31, 2010, we completed the acquisition of United pursuant to the Merger Agreement.  As a result of the Merger Transaction and other acquisitions during the fiscal year 2011 and 2012, we own the following interests in the following oil and gas properties in Texas:

The Marcee 1 Interest. We own a 100% working interest in the Marcee 1 Tract, which is located on approximately 112 acres of land in Gonzalez County, Texas (“Marcee 1 Tract”).  We have recently completed a workover on the well to increase oil production.  We have discovered an abundance of gas being produced with the oil, which is currently being tested for saleable quality.  

The Lozano Interest.   We own a 100% working interest in the Hector Lozano Tract, which is located on approximately 110 acres, located in Frio County, Texas (“Lozano Tract”). The Lozano Tract is a producing asset with three wells with proven reserves. The production from the Lozano wells is mature and we believe the wells are likely to continue to produce with slow decline for the foreseeable future.  All three wells are currently producing a total of 4-5 barrels of oil per day.  Historically these wells have produced a total of 10-12 barrels of oil per day.  

Pursuant to the Merger Agreement, we also acquired all of United’s rights and interests in all operating agreements in all wells for which United was currently operating. We also acquired all of United’s assets used in the business conducted at the Marcee 1 Tract and the Lozano Tract or at any well that United acts as the operator, including certain furniture and equipment.

The Patriot Minerals Interests.   On January 28, 2011, we acquired multiple undivided working interests to certain existing wells and to certain leases located in Texas (“Patriot Interests”) from Patriot Minerals, LLC, a Texas limited liability company (“Patriot”). The Patriot Interests consist of certain undivided working interests including, but not limited to (i) the Welder lease in Duval County, TX; (ii) the Bailey Rogers and Fohn leases in Medina County, TX; (iii) the Walker Smith lease in Wilbarger County, TX; (iv) the Merrick Davis lease in Shackelford County, TX; and (v) the Crouch, Heady and Lane leases in Erath County, TX.  

At the time of our acquisition of the Patriot Interests, all wells were shut in due in part but not limited to Patriot’s insufficient payment of operating expenses to maintain the Patriot Interests.  During fiscal year 2011 and 2012, we performed minor work on various wells and are in the process of beginning workovers on wells on each of the leases.  We expect the workovers to begin in April 2013 and conclude in August 2013.  We expect we will have to expend significant capital to maintain the Patriot Interests.

The Gabriel and Rosser Interests.   On January 28, 2011, we acquired certain oil and gas interests located in Bastrop County, Texas, (“Gabriel Interests”) from Gabriel Rosser, LP (“Gabriel”).  The Gabriel Interests include  Gabriel's undivided 50.83% working interest and 39.131% revenue interest in as the Gabriel 2 SWD Gabriel 3, 4, 5, 9, 15, Rosser #2 and #4 and Koi #1 wells .At the time of our acquisition of the Gabriel Interests, all wells were not producing. The Gabriel Interests comprise over 400 acres, with approximately 10 wells that were shut in. As of the date of this report , the Company has performed workover procedures on certain wells in the Gabriel and production has commenced.

The Mckenzie State Well Interests. On November 30, 2011, we acquired one hundred percent (100%) of McKenzie’s working interest in the McKenzie State Well No. 1, located in Pecos County, Texas from McKenzie Oil Corp. (“McKenzie”)  in exchange for an aggregate cash sum of $550,000 and 50,000 shares of our common stock.   As of the date of this report, the Company has performed workover procedures on certain wells in the McKenzie and production has commenced.  In addition to the production from this current zone, several additional horizons (which are productive in the area) have been identified in the McKenzie well, which could be tested and potentially produced in the future.  

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Company Reserve Estimates. Our proved reserve information as of December 31, 2012 was estimated by Mire and Associates, Inc. (“Mire”), independent petroleum engineers. Our proved reserve information as of December 31, 2011 was estimated by Nova Resources, Inc (“Nova”), and  Mire, independent petroleum engineers. In accordance with SEC guidelines, Nova’s and Mire’s estimates of future net revenues from our properties, and the PV-10 and standardized measure thereof, were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the period January 1, 2012 through December 31, 2012, except where such guidelines permit alternate treatment, including the use of fixed and determinable contractual price escalations.

The technical persons at Nova and Mire are responsible for preparing the reserves estimates presented herein and meets the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers.

Mire is an independent petroleum engineering firm specializing in the technical and financial evaluation of oil and gas assets. Mire’s report was prepared under the direction of Kurt Mire, principle consultant and owner of Mire.  Mr. Mire earned a B.S. degree in Petroleum Engineering from the University of Louisiana at Lafayette and has more than 25 years of experience in production engineering, field operations and management, reservoir engineering, acquisitions and divestments.  Mire and its employees have no interest in our Company or in our properties, were not employed by our Company on a contingent fee basis and were objective in determining our reserves.

Nova is an independent petroleum engineering firm specializing in the technical and financial evaluation of oil and gas assets.  Nova’s report was prepared under the direction of Joseph V. Rochefort, principle consultant and owner of Nova.  Mr. Rochefort earned a B.S. degree in Physics and Geophysics from Texas Christian University and a Masters degree in Geology from Texas Tech University.  Mr. Rochefort has more than 28 years of practical experience in the estimation and evaluation of petroleum reserves.  Nova and its employees have no interest in our Company or in our properties, were not employed by our Company on a contingent fee basis and were objective in determining our reserves.

Michael Carey, our officer and director, acted as the liaison with the technical persons at Nova and Mire. 

Additional information regarding our oil and gas properties and reserve information can be found in Note 19 to the audited financial statements for the years ended December 31, 2012 and 2011, attached hereto.

Our Acreage and Wells.  We own mineral interests leases on the following productive wells, developed acreage and undeveloped acreage in Texas.  Other properties outside of Texas have been excluded from this table.

	December 31, 2012								December 31, 2011
	Oil				Gas				Oil				Gas
	Gross		Net		Gross		Net		Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1		88		11		2		1
Gross & Net Developed Acreage		1,553		480		325		149		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29		1,572		344		557		29

Production. For the year ended December 31, 2012, we had production from our Lozano, Marcee, McKinney and Patriot leases located in six Texas counties: Erath, Gonzalez, Medina, Navarro, Shackleford and Wilbarger.  The Company produced approximately 5,823 barrels of oil (bbls)and 234 thousand cubic feet of natural gas (Mcf) on a net basis.

For the year ended December 31, 2011, we only had production from our interest in the Lozano lease located in Frio County, Texas.  The Company produced approximately 1,310 barrels and 542 Mcf on a net basis.

Drilling Activity.  During the year ended December 31, 2012, the Company did not perform any new drilling activities.

During the year ended December 31, 2011, we conducted drilling activity in Texas on a new Gabriel #16 well to test an anticipated payzone in the Serpentine formation.  We anticipate that the new well will require a second completion attempt in order to achieve potential production on the well.

Delivery Commitments.  We are not obligated to provide a fixed and determinable quantity of oil or gas in the near future under existing contracts or agreements in Texas.

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Item 3.  Legal Proceedings.

We are not currently involved in legal proceedings that could reasonably be expected to have a material adverse effect on our business, prospects, financial condition or results of operations. We may become involved in material legal proceedings in the future 

Item 4.  Mine Safety Disclosures.

Not applicable.

PART II

Item 5.  Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Market Information .  Our common stock, par value $.001, is quoted on the OTC Bulletin Board and OTCQB under the symbol “UAPC”.   For the periods indicated, the following table sets forth the high and low bid prices per share of our common stock. These prices represent inter-dealer quotations without retail markup, markdown, or commission and may not necessarily represent actual transactions. 

	High ($)		Low ($)
Fiscal Year 2012
First Quarter	$	1.49	$	0.35
Second Quarter		1.49		0.80
Third Quarter		0.49		0.23
Fourth Quarter		0.23		0.09

	High ($)		Low ($)
Fiscal Year 2011
First Quarter	$	1.50	$	0.22
Second Quarter		1.05		0.80
Third Quarter		0.95		0.85
Fourth Quarter		0.85		0.40

Reports to Security Holders.   We are a reporting company with the SEC.  The public may read and copy any materials filed with the Securities and Exchange Commission at the Security and Exchange Commission’s Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549. The public may also obtain information on the operation of the Public Reference Room by calling the Securities and Exchange Commission at 1-800-SEC-0330.  The Securities and Exchange Commission maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the Securities and Exchange Commission. The address of that site is http://www.sec.gov.

Holders.   On April 14, 2013, we had approximately 50,339,443 shares of common stock issued and outstanding held by 26 stockholders of record.  The number of stockholders of record does not include beneficial owners of our common stock, whose shares are held in the names of various dealers, clearing agencies, banks, brokers and other fiduciaries.

Dividends. We currently anticipate that we will not declare or pay cash dividends on our common stock in the foreseeable future. We will pay dividends on our common stock only if and when declared by our Board of Directors.  Our Board of Directors’ ability to declare a dividend is subject to restrictions imposed by Nevada law.  In determining whether to declare dividends, the Board of Directors will consider these restrictions as well as our financial condition, results of operations, working capital requirements, future prospects and other factors it considers relevant. 

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Securities Authorized For Issuance Under Equity Compensation Plans.  Effective on or around January 22, 2008, shareholders holding a majority of the Company’s voting securities approved the Company’ 2008 Incentive Plan (the “Plan”), which was previously approved by the then sole director of the Company on January 2, 2008. The Plan provided for the issuance of a total of up to 3,000,000 shares of common stock, options, restricted share units, share appreciation rights and other share based awards to acquire common stock to employees, directors and consultants.  A total of 1,877,000 options were granted during the year ended December 31, 2008, which options were subsequently forfeited during the years ended December 31, 2009 and 2008.  The Company does not anticipate issuing any additional shares of common stock under the Plan moving forward.

The following table provides information as of December 31, 2012 regarding compensation plans (including individual compensation arrangements) under which equity securities are authorized for issuance:

Plan Category	Number of securities to be issued upon exercise of outstanding options, warrants and rights	Weighted-average exercise price of outstanding options, warrants and rights	Number of securities available for future issuance under equity compensation plans (excluding those in first column)
Equity compensation plans approved by the security holders	3,000,000	-	3,000,000
Equity compensation plans not approved by the security holders	-	-	-
Total	3,000,000	-	3,000,000

Recent Sales of Unregistered Securities.  

During the fourth quarter ended December 31, 2012, the Company issued the following restricted securities to employees and consultants in consideration for services rendered.

On December 21, 2012, the Company issued an employee 80,000 shares of common stock as share based compensation.

On December 21, 2012, the Company issued an independent oil and gas advisor 125,000 shares of common stock as share based compensation.

On December 21, 2012, the Company issued an independent investor relations advisor 100,000 shares of common stock as share based compensation.

The Company claims an exemption from registration provided by Section 4(2) and Rule 506 of Regulation D of the Securities Act of 1933, as amended (the “Securities Act”) since the foregoing issuances did not involve a public offering, the recipients took the securities for investment and not resale, the Company took appropriate measures to restrict transfer, and the recipients were either (a) “accredited investors” and/or (b) had access to similar documentation and information as would be required in a Registration Statement under the Securities Act.

On (a) January 31, 2013, the Company sold a Note to JMJ Financial in the initial amount of $50,000; and (b) February 19, 2013, the Company sold a $103,500 Convertible Note to Asher Enterprises, Inc. (“Asher”), each in transactions exempt from registration as provided by Section 4(2) and Rule 506 of Regulation D of the Securities Act. JMJ Financial and Asher are “accredited investors,” as such term is defined in Rule 501(a) of Regulation D of the Securities Act. The sale of the Note and Convertible Note did not involve a public offering and were made without general solicitation or general advertising. JMJ and Asher acquired the securities for investment purposes only and not with a view to or for sale in connection with any distribution thereof. Neither the Note nor the Convertible Note or the underlying shares of common stock issuable upon the conversion thereof have been registered under the Securities Act and none may be offered or sold in the United States absent registration or an applicable exemption from registration requirements.

The sale of the Note and Convertible Note did not involve a public offering and were made without general solicitation or general advertising. JMJ and Asher acquired the securities for investment purposes only and not with a view to or for sale in connection with any distribution thereof. Neither the Note nor the Convertible Note or the underlying shares of common stock issuable upon the conversion thereof have been registered under the Securities Act and none may be offered or sold in the United States absent registration or an applicable exemption from registration requirements.

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Penny Stock Regulation.   Trading of our securities will be in the over-the-counter markets which are commonly referred to as the “pink sheets” or on the OTC Bulletin Board. As a result, an investor may find it more difficult to dispose of, or to obtain accurate quotations as to the price of the securities offered.

Shares of our common stock will probably be subject to rules adopted the Securities and Exchange Commission that regulate broker-dealer practices in connection with transactions in “penny stocks”.  Penny stocks are generally equity securities with a price of less than $5.00 (other than securities registered on certain national securities exchanges or quoted on the NASDAQ system, provided that current price and volume information with respect to transactions in those securities is provided by the exchange or system).  The penny stock rules require a broker-dealer, prior to a transaction in a penny stock not otherwise exempt from those rules, deliver a standardized risk disclosure document prepared by the Securities and Exchange Commission, which contains the following:

· a description of the nature and level of risk in the market for penny stocks in both public offerings and secondary trading;

· a description of the broker’s or dealer’s duties to the customer and of the rights and remedies available to the customer with respect to violation to such duties or other requirements of securities’ laws;

· a brief, clear, narrative description of a dealer market, including "bid" and "ask” prices for penny stocks and the significance of the spread between the "bid" and "ask" price;

· a toll-free telephone number for inquiries on disciplinary actions;

· definitions of significant terms in the disclosure document or in the conduct of  trading in penny stocks;  and

· such other information and is in such form (including language, type, size and format), as the Securities and Exchange Commission shall require by rule or regulation.

Prior to effecting any transaction in penny stock, the broker-dealer also must provide the customer the following:

· the bid and offer quotations for the penny stock;

· the compensation of the broker-dealer and its salesperson in the transaction;

· the number of shares to which such bid and ask prices apply, or other comparable information relating to the depth and liquidity of the market for such stock; and

· monthly account statements showing the market value of each penny stock held in the customer’s account.

In addition, the penny stock rules require that prior to a transaction in a penny stock not otherwise exempt from those rules, the broker-dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser’s written acknowledgment of the receipt of a risk disclosure statement, a written agreement to transactions involving penny stocks, and a signed and dated copy of a written suitability statement.  These disclosure requirements may have the effect of reducing the trading activity in the secondary market for a stock that becomes subject to the penny stock rules.  Holders of shares of our common stock may have difficulty selling those shares because our common stock will probably be subject to the penny stock rules.

Purchases of Equity Securities.   None during the period covered by this Annual Report.

Item 6. Selected Financial Data.

Not applicable.

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

Forward Looking Statements

This Annual Report of United American Petroleum Corp. on Form 10-K contains forward-looking statements, particularly those identified with the words, “anticipates,” “believes,” “expects,” “plans,” “intends”, “objectives” and similar expressions. These statements reflect management's best judgment based on factors known at the time of such statements. The reader may find discussions containing such forward-looking statements in the material set forth under “Management's Discussion and Analysis and Plan of Operations,” generally, and specifically therein under the captions “Liquidity and Capital Resources” as well as elsewhere in this Annual Report on Form 10-K. Actual events or results may differ materially from those discussed herein. The forward-looking statements specified in the following information have been compiled by our management on the basis of assumptions made by management and considered by management to be reasonable. Our future operating results, however, are impossible to predict and no representation, guaranty, or warranty is to be inferred from those forward-looking statements. The assumptions used for purposes of the forward-looking statements specified in the following information represent estimates of future events and are subject to uncertainty as to possible changes in economic, legislative, industry, and other circumstances. As a result, the identification and interpretation of data and other information and their use in developing and selecting assumptions from and among reasonable alternatives require the exercise of judgment. To the extent that the assumed events do not occur, the outcome may vary substantially from anticipated or projected results, and, accordingly, no opinion is expressed on the achievability of those forward-looking statements. No assurance can be given that any of the assumptions relating to the forward-looking statements specified in the following information are accurate, and we assume no obligation to update any such forward-looking statements.

Critical Accounting Policy and Estimates.  Our Management's Discussion and Analysis of Financial Condition and Results of Operations section discusses our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of these financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. On an on-going basis, management evaluates its estimates and judgments, including those related to revenue recognition, accrued expenses, financing operations, and contingencies and litigation. Management bases its estimates and judgments on historical experience and on various other factors that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. The most significant accounting estimates inherent in the preparation of our financial statements include estimates as to the appropriate carrying value of certain assets and liabilities which are not readily apparent from other sources.

Oil and Gas Properties

The Company follows the full cost method of accounting for its investments in oil and gas properties. Under the full cost method, all costs associated with the exploration of properties are capitalized into appropriate cost centers within the full cost pool.  Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities.  Cost centers are established on a country-by-country basis.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred.  The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

For each cost center, capitalized costs are subject to an annual ceiling test, in which the costs shall not exceed the cost center ceiling.  The cost center ceiling is equal to i) the present value of estimated future net revenues computed by applying current prices of oil and gas reserves (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions;  plus ii) the cost of properties not being amortized; plus iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; less iv) income tax effects related to differences between the book and tax basis of the properties.  If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs.

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Share-Based Compensation

The Company accounts for share-based compensation in accordance with Accounting Standards Codification subtopic 718-10, Stock Compensation (“ASC 718-10”).  This requires the measurement and recognition of compensation expense for all share-based payment awards made to employees and directors, including employee stock options and employee stock purchases related to an Employee Stock Purchase Plan based on the estimated fair values.

As of December 31, 2012, there were no outstanding employee stock options.

Recent Accounting Pronouncements

There were various updates recently issued, most of which represented technical corrections to the accounting literature or application to specific industries and are not expected to a have a material impact on the Company's financial position, results of operations or cash flows.

Overview.   United American Petroleum Corp. (“we” or the “Company”), formerly Forgehouse, Inc., was incorporated in the State of Nevada on November 19, 2004. On December 31, 2010, we entered into and closed an Agreement and Plan of Merger (“Merger Agreement”) with our then newly formed wholly-owned subsidiary, United PC Acquisition Corp., a Nevada corporation (“Merger Sub”), and United American Petroleum Corp., a Nevada Corporation (“United”) (the “Merger Transaction”), pursuant to which Merger Sub merged with and into United with United surviving, making United our wholly-owned subsidiary. Immediately thereafter and pursuant to the Merger Agreement, United merged with and into the Company, with the Company surviving and we changed our name to “United American Petroleum Corp.” In connection with the Merger Transaction, we assumed all of United’s contractual obligations and acquired certain oil and gas properties of United located in Texas.   The Merger Transaction was deemed to be a reverse acquisition, where the Company (the legal acquirer) is considered the accounting acquiree and United (the legal acquiree) is considered the accounting acquirer. The Company is deemed a continuation of the business of United, and the historical financial statements of United became the historical financial statements of the Company.

Recent Events. On October 11, 2012, the Company filed with the Nevada Secretary of State, a Certificate of Designations, Establishing the Designations, Preferences, Limitations and Relative Rights of Its Series B Preferred Stock (the “Designation”).  The Designation, which was approved by the Board of Directors on October 9, 2012 and authorized under the Company’s Articles of Incorporation, which provides the Board of Directors the right to designate series of preferred stock, provided for the designation of a series of 1,000 shares of Series B Preferred Stock, par value $0.001 (the “Series B Preferred Stock”).  The Series B Preferred Stock have no dividend rights, no liquidation preference, no redemption rights and no conversion rights. The Series B Preferred Stock have the right, voting in aggregate, to vote on all shareholder matters (including, but not limited to at every meeting of the stockholders of the Company and upon any action taken by stockholders of the Company with or without a meeting) equal to fifty-one percent (51%) of the total vote (the “Super Majority Voting Rights”). Additionally, we are not allowed to adopt any amendments to our Bylaws, Articles of Incorporation, as amended, make any changes to the Certificate of Designations establishing the Series A Preferred Stock, or effect any reclassification of the Series A Preferred Stock, without the affirmative vote of at least 66-2/3% of the outstanding shares of the Series B Preferred Stock.

A total of 1,000 shares of the Company’s Series B Preferred Stock, 500 shares each, have not been issued as of the date of this report to the Company’s Chief Executive Officer, Chief Financial Officer, President, Treasurer and Director, Michael Carey, and the Company’s Chief Operating Officer, Secretary and Director, Ryan Hudson.

The Company also filed a Certificate of Withdrawal with the Secretary of State of Nevada on October 11, 2012, which terminated its previous designation of Series A Convertible Preferred Stock, of which no shares were outstanding as of such termination.

During the three month period ended March 31, 2013, the Company secured certain funding from external sources including two convertible notes payable in the amount of approximately $140,000 as described in detail below.  The Company additionally solicited $114,000 of funds from working interest partners to cover non-consenting working interest partners’ portions of workover costs on the Merrick Davis, Crouch and Lane Heady properties.  As of the date of this report, the Company has completed workovers on these properties and is awaiting production results.

Our Business.   We are an exploration company engaged in the acquisition, exploration, development and production of oil and gas properties.  Our principal business is the acquisition of leasehold interests in petroleum and natural gas rights, either directly or indirectly, and the exploitation and development of properties subject to these leases.  Our primary focus is to develop our properties that have potential for near-term production. We also provide operational expertise for several third-party well owners out of our operation base in Austin, Texas. We currently have proved reserves in the State of Texas.

The following discussion of our financial condition and results of operations should be read in conjunction with our financial statements for the period ended December 31, 2012, together with notes thereto, which are included in this Annual Report.

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Results of Operations for the twelve months ended December 31, 2012, as compared to the twelve months ended December 31, 2011.

Revenues .  We had total revenues of $551,295 for the twelve months ended December 31, 2012, which were generated from oil and gas sales of $512,088 and administrative revenue of $39,207.  This was a $340,481 increase from total revenues of $210,814 for the twelve months ended December 31, 2011, which were generated from oil and gas sales of $141,362 and administrative revenue of $69,452.  

Administrative revenues decreased during fiscal year 2012 from administrative revenues in fiscal year 2011 due to a reduction in the online wells managed by the Company.

During 2012, the Company was required to reclassify certain administrative and operator fees from revenue to reduce our lease operating and general and administrative expenses.  Our administrative revenues, as presented within this report for the years ended December 2012 and 2011, are administrative fees charged through United Operating, LLC, our wholly-owned subsidiary, to third party well owners for properties which the company owns no portion of, for managing and accounting for the development and production of their oil and gas property interests.

The following table sets forth the revenue and production data for the twelve months ended December 31, 2012 and 2011.

	TWELVE MONTHS  ENDED DECEMBER 31,		TWELVE MONTHS ENDED DECEMBER 31,		INCREASE			% INCREASE
	2012		2011		(DECREASE)			(DECREASE)
REVENUES
Oil and Gas Revenues	$	512,088	$	141,362	$	370,726			262	%
Administrative revenues		39,207		69,452		(30,245	)		(44	%)
Total Revenues	$	551,295	$	210,814	$	340,481			162	%
PRODUCTION:
Total production – barrels of oil equivalent (BOE)		6,057		1,400		4,657			333	%
Barrels of Oil Per Day (BOPD)		16.60		3.84		12.76			333	%
AVERAGE SALES PRICES:
Price per BOE	$	84.54	$	100.95	$	(16.41	)		(16	%)

For the twelve months ended December 31, 2012, we increased total barrels of oil equivalent (BOE) produced by 333% over the same period in the prior year.  For the twelve months ended December 31, 2012 and 2011, total BOE produced was 6,057 and 1,400 respectively.  The increase in oil and gas production and revenues is primarily related to production increases on the Lozano, McKenzie, and Welder properties.  The Company conducted workover procedures on these properties during 2012 which has yielded significant increases in production for the current year’s period over the prior year’s period.

During the twelve months ended December 31, 2012, we increased our barrels of oil per day (BOPD) produced to an average of 16.60 BOPD from 3.84 BOPD for the twelve months ended December 31, 2011.

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Operating Expenses.  The following table sets forth information relating to our operating expenses for the twelve months ended December 31, 2012 and 2011.

	TWELVE MONTHS ENDED DECEMBER 31,		TWELVE MONTHS ENDED DECEMBER 31,		INCREASE			% INCREASE
	2012		2011		(DECREASE)			(DECREASE)
LEASE OPERATING EXPENSES
Lease and well operating expenses	$	237,208	$	5,751	$	231,457			4,024	%
Workover expenses		141,861		49,618		92,243			186	%
Legal, title and administrative well expenses		21,105		8,019		13,086			163	%
Total Lease Operating Expenses	$	400,174	$	63,389	$	336,785			(531	%)
DEPRECIATION AND ACCRETION EXPENSE
Depreciation and Accretion expense		117,499		21,817		95,682			439	%
GENERAL AND ADMINISTRATIVE EXPENSE
Public reporting and compliance related expense		432,056		391,064		40,992			10	%
Employee and officer expenses		233,622		228,717		4,905			2	%
Other general and administrative expenses		162,463		203,598		(41,135	)		(20	%)
Total General and Administrative Expenses	$	828,141	$	823,379		4,762			1	%
TOTAL OPERATING EXPENSES	$	1,345,814	$	908,584	$	437,230			48	%

For the twelve months ended December 31, 2012, our total operating expenses were $1,345,814, which consisted of lease operating expenses of $400,174, accretion expense of $3,514, depletion expense of $113,985, and general and administrative expenses of $828,141.  By comparison, for the twelve months ended December 31, 2011, our total operating expenses were $908,584, which consisted of lease operating expenses of $63,389, accretion expense of $2,592, depletion expense of $19,225, and general and administrative expenses of $823,379.

For the twelve months ended December 31, 2012 compared to the twelve months ended December 31, 2011, we incurred increases in lease and well operating expenses of $231,457 or 4,024% related to the properties acquired in 2012 and increases in production activities on our properties.  During the twelve months ended December 31, 2012, we worked over the Lozano property resulting in an increase to workover expenses of $92,243 or 186%, from the prior period.

During the twelve months ended December 31, 2012 compared to the twelve months ended December 31, 2011, our depreciation and accretion expenses increased by $95,682 or 439% due to an increase in our production and producing properties.

The increase in general and administrative expenses of $2,665 or 2% during the twelve months ended December 31, 2012, compared to the prior period, was largely due to the decrease in other general and administrative expenses of $43,232, offset by increases in public reporting and compliance related expenses of $40,992.

Net Operating Loss.  For the twelve months ended December 31, 2012, our total net operating loss was $794,519 as compared to a net operating loss of $697,770 from the prior period, an increase of $80,749 or 12% from the prior period. Our net operating loss increased over the prior period due to workover procedures and costs related to operating as a public company, which were offset by increases in oil and gas sales.

Other Income (Expense).   For the twelve months ended December 31, 2012 we had interest expense of $2,252,915 associated with the conversion of certain of our previously outstanding convertible promissory notes during the period, compared to interest expense of $298,291 for the twelve months ended December 31, 2011, relating to our outstanding convertible promissory notes.

Net Income (Loss).    For the twelve months ended December 31, 2012, our net loss was $6,077,652, as compared to a net loss of $1,083,341 for the twelve months ended December 31, 2011, a decrease in net loss of $4,978,131 or 460% from the prior period.

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Liquidity and Capital Resources.

During the twelve months ended December 31, 2012, we used $361,158 in operations, $274,527 in investing activities, related solely to property acquisitions and received $615,000 of cash from financing activities, related directly to proceeds on convertible notes.  Our convertible notes are described below.

First Note and Warrants.    On April 13, 2012, we issued 1,240,000 shares of our common stock to the investor who elected to convert the outstanding principal amount of $620,000 due on a convertible promissory note dated December 31, 2010 into shares of our common stock at a conversion price of $0.50 per share.

On June 1, 2012, we issued an additional 1,180,000 shares of our common stock to an investor who elected to convert the remaining outstanding principal amount of $590,000 due to such investor under certain convertible promissory notes dated January 20, 2011, March 9, 2011, June 20, 2011 and June 30, 2011 into shares of our common stock at a conversion price of $0.50 per share.

On June 11, 2012, we issued 300,481 shares of our common stock to an investor who elected to convert all of the accrued interest due on its convertible promissory notes dated December 31, 2010, January 20, 2011, March 9, 2011, June 20, 2011 and June 30, 2011 into shares of our common stock at a conversion price of $0.50 per share. Following such conversions, the convertible promissory notes converted are no longer outstanding and we extinguished $1,210,000 in principal and $150,240.11 in accrued and unpaid interest due under such notes in connection with such conversions.

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Second Note and Warrants.   On June 7, 2012, we issued 3,314,062 shares of our common stock to an investor who elected to convert the outstanding principal amount of $1,590,000 and all of the accrued interest due on its convertible promissory notes dated October 14, 2011, November 29, 2011, December 19, 2011, February 10, 2012, March 30, 2012, and June 4, 2012 into shares of common stock at a conversion price of $0.50 per share.   Following such consummation, the converted promissory notes are no longer outstanding and we extinguished $1,590,000 in principal and $67,030.56 in accrued and unpaid interest due under the Second Notes.

As of December 31, 2012, we had total current assets of $719,239, consisting of cash of $572,784, accounts receivable of $133,258, and related party receivable of $13,196. As of December 31, 2012, we had long-term assets consisting of $1,054,323 of oil and gas properties, net, and $261,975 of unevaluated oil and gas properties.

As of December 31, 2012, we had current liabilities in the amount of $859,223, of which $407,284 were represented by accounts payable and accrued liabilities and $451,939 represented liabilities associated with cash held in restriction for certain workovers.  As of December 31, 2012, we had long-term liabilities consisting of an asset retirement obligation of $69,316.

We had no other liabilities and no other long term commitments or contingencies as of December 31, 2012.

As of December 31, 2012, we had a working capital deficit of $139,985 and an accumulated deficit of $7,256,643.

On December 31, 2010, we entered into a credit facility with VP Bank (Switzerland) Ltd. (“VP Bank”), whereby VP Bank agreed to lend up to $2,250,000 to us in multiple installments in exchange for senior secured convertible promissory notes with a conversion price of $0.50 per share and five-year warrants to acquire shares of common stock at an exercise price of $1.00 per share in the amount of each installment. The notes are due on December 31, 2013, or upon default, whichever is earlier, and bear interest at the annual rate of 10%.Pursuant to thecredit facility, we issued the following notes and warrants toVP Bankon the following dates: 

Date of Note	Amount of Note	Number of Warrants
December 31, 2010	$620,000	620,000
January 1, 2011	$150,000	150,000
March 9, 2011	$250,000	250,000
June 20, 2011	$75,000	75,000
June 30, 2011	$115,000	115,000
TOTAL	$1,210,000	1,210,000

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The agreement provides that VP Bank will lend additional installments to us in amounts as requested by us; provided however, that we provide the proposed use of proceeds for each requested amount.

On April 13, 2012, we issued 1,240,000 shares of our common stock to VP Bank pursuant to VP Bank’s election to convert the outstanding principal amount of $620,000 due on its note dated December 31, 2010 at a conversion price of $0.50 per share as previously disclosed in our Current Report on Form 8-K filed with the Commission on April 19, 2012.  On June 1, 2012, we issued 1,180,000 shares of our common stock to VP Bank pursuant to VP Bank’s election to convert the outstanding principal amount of $590,000 due on its notesdated January 1, 2011, March 9, 2011, June 20, 2011 and June 30, 2011 at a conversion price of $0.50 per share as previously disclosed in our Current Report on Form 8-K filed with the Commission on June 6, 2012.  On June 11, 2012, we issued 300,481 shares of our common stock to VP Bank pursuant to VP Bank’s election to convert all of the accrued interest due on its notes dated December 31, 2010, January 20, 2011, March 9, 2011, June 20, 2011 and June 30, 2011 at a conversion price of $0.50 per share as previously disclosed in our Current Report on Form 8-K filed with the Commission on June 13, 2012.  As of the date of this filing there are no outstanding notes held by VP Bank and VP Bank is the holder of 1,210,000 warrants at an exercise price of $1.00 per share.

On October 14, 2011, we entered into a credit facility with Yaksha Industries Inc. (“Yaksha”) pursuant to which Yaksha agreed to lend up to $1,500,000 to us in multiple installments in exchange for a convertible promissory note with a conversion price of $0.50 per share and five-year warrants to acquire shares of common stock at an exercise price of $1.00 per share in the amount of each installment.On June 4, 2012, Yaksha agreed to increase the total amount of the facility to $1,590,000.  Pursuant to the credit facility, we issued the following notes and warrants to Yaksha on the following dates:

Date of Note	Amount of Note	Number of Warrants
October 14, 2011	$400,000	400,000
November 29, 2011	$550,000	550,000
December 19, 2011	$25,000	25,000
February 10, 2012	$150,000	150,000
March 30, 2012	$250,000	250,000
June 4, 2012	$215,000	215,000
TOTAL	$1,590,000	1,590,000

The agreement provides that Yaksha will lend additional installments to us in amounts as requested by us; provided however, that we provide the proposed use of proceeds for each requested amount.

On June 7, 2012, we issued 3,314,062 shares of our common stock pursuant to Yaksha’s election to convert the outstanding principal amount of $1,590,000 and all accrued interest due on its notes datedOctober 14, 2011, November 29, 2011, December 19, 2011, February 10, 2012, March 30, 2012, and June 4, 2012 at a conversion price of $0.50 per shareas previously disclosed in our Current Report on Form 8-K filed with the Commission on June 13, 2012.  As of the date of this filing, there are no outstanding notes held by Yaksha and Yaksha is the holder of warrants to purchase an aggregate of 1,590,000 shares at an exercise price of $1.00 per share.

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Effective on January 31, 2013 (the “Effective Date”), the Company entered into a promissory note (the “Note”) with JMJ Financial, pursuant to which JMJ Financial agreed to lend the Company up to an aggregate principal amount of $360,000 (the “Principal Sum”). On February 13, 2013, JMJ Financial provided $50,000 to the Company in connection with the parties’ entry into the Note and may choose to lend the Company additional funds under the Note from time to time in its sole discretion. The Principal Sum due to JMJ Financial is prorated based on the consideration actually paid by JMJ Financial, plus a 10% original issue discount ("OID") and as such, a total of up to $400,000 (not including accrued and unpaid interest and other fees and amounts due under the Note) may be evidenced by the Note.

The Note has a maturity date of twelve (12) months from the Effective Date. If the Note is repaid within ninety (90) days of the Effective Date, the interest rate is zero percent (0%). Should the Note still be outstanding after 90 days, a one-time 12% interest rate is applied to the Note. In addition, JMJ Financial has the right, at any time 90 days after the Effective Date, at its election, to convert all or part of the outstanding and unpaid Principal Sum and accrued interest (and any other fees) due under the Note into shares of the Company’s common stock at a conversion price equal to the lesser of $0.11 per share or 60% of the lowest trading price of the Company’s common stock in the 25 days prior to any conversion (provided that if the shares converted are not deliverable via DWAC, an additional 10% discount will apply, and if the shares are ineligible for deposit with DTC another 5% discount will apply).

JMJ Financial has contractually agreed to restrict its ability to convert the Note such that the number of shares of the Company’s common stock held by JMJ Financial and its affiliates after such conversion will not exceed 4.99% of the Company’s then issued and outstanding shares of common stock.

The Company also provided JMJ Financial (a) piggy-back registration rights in connection with the shares issuable upon conversion of the Note (provided that if the Company does not register such shares in the next registration statement filing the Company makes with the Commission it is required to pay JMJ Financial a penalty of the greater of (i) 25% of the amount outstanding under the Note, and (ii) $25,000); and (b) adjustment rights in connection with the Note in the event the Company provides any other investor, or issues any other security with, more favorable terms than the Note. Upon the occurrence of an event of default under the Note, the Company is required to pay JMJ Financial the higher of (i) the amount owed under the Note divided by the applicable conversion price and multiplied by the volume weighted average price of the Company’s common stock on the date such amount is demanded in full; or (ii) 150% of the amount owed under the Note. Additionally, upon an event of default, all interest under the Note accrues at 18% per annum. The Note provides for customary events of default such as failing to timely make payments under the Note when due.

Effective on February 19, 2013, the Company entered into a Securities Purchase Agreement with Asher Enterprises, Inc. (“Asher”), pursuant to which the Company sold Asher a convertible note in the amount of $103,500, bearing interest at the rate of 8% per annum (the “Convertible Note” and the “Note”, the “Convertible Notes”). The Convertible Note provides Asher the right to convert the outstanding balance (including accrued and unpaid interest) of such Convertible Note into shares of the Company’s common stock at a conversion price equal to the greater of (a) 60% of the average of the five lowest trading prices of the Company’s common stock during the ten trading days prior to such conversion date; and (b) $0.00005 per share, at any time after the expiration of 180 days from the date such Convertible Note was issued. The Convertible Note is payable, along with interest thereon on February 20, 2014. In the event any principal or interest is not timely paid, such amount accrues interest at 22% per annum until paid in full. Asher is prohibited from converting the Convertible Note into shares of the Company’s common stock to the extent that such conversion would result in Asher beneficially owning more than 4.99% of the Company’s common stock, subject to 61 days prior written notice to the Company from Asher of Asher’s intention to waive or modify such provision.

The Company can repay the Convertible Note prior to maturity (or conversion), provided that it pays 112% of such note (and accrued and unpaid interest thereon) if the note is repaid within the first 30 days after the issuance date; 117% of such note (and accrued and unpaid interest thereon) if the note is repaid during the period which is 31 and 60 days after the issuance date; 123% of such note (and accrued and unpaid interest thereon) if the note is repaid during the period which is 61 and 90 days after the issuance date; 129% of such note (and accrued and unpaid interest thereon) if the note is repaid during the period which is 91 and 120 days after the issuance date; 133% of such note (and accrued and unpaid interest thereon) if the note is repaid during the period which is 121 and 150 days after the issuance date; and 139% of such note (and accrued and unpaid interest thereon) if the note is repaid during the period which is 151 days and prior to 180 days after the issuance date. After 180 days have elapsed from the issuance date the Company has no right to prepay the Convertible Note.

Upon the occurrence of an event of default, as described in the Convertible Note, Asher can declare the entire amount of principal and interest then due on the Convertible Note immediately due and payable and require the Company to pay an amount equal to the greater of (i) 150% times the sum of principal and interest due under the Convertible Note (the “Default Sum”); and (ii) the highest number of shares of common stock issuable upon conversion of the Default Sum multiplied by the highest closing price of the Company’s common stock during the period that such Convertible Note has been in default.

The Convertible Note provides for customary events of default such as failing to timely make payments under the Convertible Note when due.

The transactions discussed above with Asher closed on February 25, 2013.

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In the opinion of management, available funds will not satisfy our working capital requirements to operate at our current level of activity for the next twelve months. If we do not raise additional capital, then we may not be able to conduct oil and gas exploration and development activities and expand our operations. Our forecast for the period for which our financial resources will be adequate to support our operations involves risks and uncertainties and actual results could differ as a result of a number of factors. In addition to generating revenues from our current operations, we will need to raise additional capital to expand our operations to the point at which we are able to operate profitably.

We have been, and intend to continue, working toward identifying and obtaining new sources of financing. No assurances can be given that we will be successful in obtaining additional financing in the future. Any future financing that we may obtain may cause significant dilution to existing stockholders. Moreover, in the event that we can raise additional funds, we cannot guarantee that additional funding will be available on favorable terms. Any debt financing or other financing of securities senior to common stock that we are able to obtain will likely include financial and other covenants that will restrict our flexibility. Any failure to comply with these covenants would have a negative impact on our business, prospects, financial condition, results of operations and cash flows.

If adequate funds are not available, we may be required to delay, scale back or eliminate portions of our operations or to obtain funds through arrangements with strategic partners or others that may require us to relinquish rights to certain of our assets. Accordingly, the inability to obtain such financing could result in a significant loss of ownership and/or control of our assets and could also adversely affect our ability to fund our continued operations and our expansion efforts with respect to our properties.

During fiscal year 2013, we expect that the following will continue to impact our liquidity: (i) legal and accounting costs of being a public company; (ii) expected expenses related to the exploration and development of our properties; (iii) expected expenses related to repair and maintenance costs on wells that are currently producing and (iv) anticipated increases in overhead and the use of independent contractors for services to be provided to us. We will need to obtain funds to pay those expenses. Other than those items specified above, we are not aware of any other known trends, events or uncertainties, which may affect our future liquidity.

We are in the exploration stage, have limited revenue and have incurred net losses to date.  These factors raise substantial doubt about our ability to continue as a going concern.   No assurances can be given that we will obtain sufficient working capital to sustain ongoing operations. The financial statements do not include any adjustments that might be necessary if we are unable to continue as a going concern.

We are not currently conducting any research and development activities. We do not anticipate conducting such activities in the near future. In the event that we expand our operations, then we may need to hire additional employees or independent contractors as well as purchase or lease additional equipment. Our management believes that we do not require the services of independent contractors to operate at our current level of activity. However, if our level of operations increases beyond the level that our current staff can provide, then we may need to supplement our staff in this manner.  

Off-Balance Sheet Arrangements.   We have no off-balance sheet arrangements as of December 31, 2012.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

Not applicable.

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Item 8. Financial Statements and Supplementary Data.

The financial statements required by Item 8 are presented in the following order:

TABLE OF CONTENTS

	Page
Report of Independent Registered Public Accounting Firm	F-2
Consolidated Balance Sheets as of December 31, 2012 and 2011	F-3
Consolidated Statement of Operations for the years ended December 31, 2012 and 2011	F-4
Consolidated Statement of Stockholders' Deficit for the years ended December 31, 2012 and 2011	F-5
Consolidated Statement of Cash Flow for the years ended December 31, 2012 and 2011	F-6
Notes to Financial Statements	F-8

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors

United American Petroleum Corp.

Austin, Texas

We have audited the accompanying consolidated balance sheets of United American Petroleum Corp. and its subsidiaries (the “Company”) as of December 31, 2012 and 2011 and the related consolidated statements of operations, stockholders' deficit and cash flows for each of the years then ended.   These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our 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 an audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2012 and 2011 and the consolidated results of their operations and their cash flows for each of the years then in conformity with accounting principles generally accepted in the United States of America.  

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 3 to the consolidated financial statements, the Company has suffered losses from operations and has a working capital deficit. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. Management’s plans in regards to these matters are also described in Note 3. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/s/ MaloneBailey, LLP

www.malonebailey.com

Houston, Texas

April 16, 2013

F-2

UNITED AMERICAN PETROLEUM CORP.

CONSOLIDATED BALANCE SHEETS

DECEMBER 31, 2012 AND 2011

	2012		2011
ASSETS
CURRENT ASSET
Cash	$	572,784	$	593,469
Accounts receivable		133,258		35,405
Related party receivables		13,196		25,718
Other receivable		-		160,302
Total current assets		719,238		814,894
Oil and gas properties (full cost method):
Evaluated, net of accumulated depletion of $137,120 and $23,135
as of December 31, 2012 and 2011, respectively		1,054,322		528,336
Unevaluated		261,975		617,630
TOTAL ASSETS	$	2,035,535	$	1,960,860
LIABILITIES AND STOCKHOLDERS' DEFICIT
CURRENT LIABILITIES
Accounts payable and accrued liabilities		407,284		217,702
Related party payable		-		-
Note payable - related party		-		-
Note payable		-		-
Other payable		451,939		431,151
Total current liabilities		859,223		648,853
Accrued interest		-		141,255
Convertible note payable, net of discount of $- and $1,561,997   as of December 31, 2012 and 2011, respectively		-		623,003
Embedded derivative liability		-		1,138,989
Asset retirement obligation		69,316		56,012
TOTAL LIABILITIES		928,539		2,608,112
STOCKHOLDERS' DEFICIT
Preferred Stock, Series B, $0.001 par value, 1,000 shares authorized, 1,000 shares issued     and 1,000 share outstanding and no shares issued and outstanding, respectively		1		-
Common stock, $.0001 par value, 100,000,000 shares authorized, 50,339,543 shares issued and        50,339,542 and 44,000,000 shares outstanding, respectively		50,339		44,000
Additional paid-in capital		8,313,299		487,739
Accumulated deficit		(7,256,643)		(1,178,991	)
Total stockholders' deficit		1,106,996		(647,252	)
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT	$	2,035,535	$	1,960,860

The accompanying notes are an integral part of these consolidated financial statements.

F-3

UNITED AMERICAN PETROLEUM CORP.

CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE YEARS ENDED DECEMBER 31, 2012, AND 2011

	TWELVE MONTHS ENDED			TWELVE MONTHS ENDED
	DECEMBER 31, 2012			DECEMBER 31, 2011
REVENUE
Oil sales	$	512,088		$	141,362
Well operator income		39,207			69,452
TOTAL REVENUE		551,295			210,814
OPERATING EXPENSES (INCOME)
Lease operating expenses		400,174			63,389
Accretion expense		3,514			2,592
Depletion expense		113,985			19,225
General and administrative		828,141			823,379
TOTAL OPERATING EXPENSES		1,345,814			908,584
NET LOSS BEFORE OTHER EXPENSE		(794,519	)		(697,770	)
OTHER INCOME (EXPENSE)
Interest Expense		(2,252,915	)		289,291
Loss on embedded derivatives		(3,030,218	)		(96,280	)
Total other expense		(5,283,133	)		(385,571	)
NET INCOME (LOSS)	$	(6,077,652	)	$	(1,083,341	)
INCOME (LOSS) PER SHARE - BASIC		(0.13	)		(0.02	)
WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING - BASIC		47,633,640			43,954,258
INCOME (LOSS) PER SHARE - DILUTED		(0.13	)		(0.02	)
WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING - DILUTED		47,633,640			43,954,258

The accompanying notes are an integral part of these consolidated financial statements.

F-4

UNITED AMERICAN PETROLEUM CORP.

CONSOLIDATED STATEMENT OF STOCKHOLDERS' DEFICIT

FOR THE YEARS ENDED DECEMBER 31, 2012, AND 2011

	Series B Preferred Stock				Common Stock				Additional Paid-in			Accumulated			Stockholders’
	Shares		Par Value		Shares		Par Value		Capital			Deficit			Deficit
Balance, December 31, 2010		-		-		43,950,000	$	43,950	$	(237,338	)		(95,650	)	$	(289,038	)
Discount on convertible notes		-		-		-		-		684,627			-			684,627
Shares issued for oil   and gas property		-		-		50,000		50		40,450			-			40,500
Net loss for the period		-		-		-		-		-			(1,083,341	)		(1,083,341	)
Balance - December 31, 2011		-		-		44,000,000	$	44,000	$	487,739			(1,178,991	)	$	(647,252	)
Relative Fair value of warrants   issued with Debt		-		-		-		-		290,459			-			290,459
Common stock issued for conversion of debt and accrued interest		-		-		6,034,542		6,035		3,011,236			-			3,017,271
Reclassification of derivative liability to additional paid-in capital due to conversion of related notes payable		-		-		-		-		4,493,670			-			4,493,670
Shares issued for services		1,000		1		305,000		305		30,195			-			30,501
Net loss for the period		-		-		-		-		-			(6,077,652	)		(6,077,652	)
Balance - December 31, 2012		1,000		1		50,339,542	$	50,339	$	8,313,299			(7,256,643	)	$	1,106,996

The accompanying notes are an integral part of these consolidated financial statements.

F-5

UNITED AMERICAN PETROLEUM CORP.

CONSOLIDATED STATEMENTS OF CASH FLOW

FOR THE YEARS ENDED DECEMBER 31, 2012, AND 2011

	TWELVE MONTHS ENDING			TWELVE MONTHS ENDING
	DECEMBER 31, 2012			DECEMBER 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Income (loss)	$	(6,077,652	)	$	(1,083,341	)
Adjustments to reconcile net loss
to net cash used in operating activities:
Depreciation expense		-			-
Depletion expense		113,985			19,225
Accretion expense		3,514			2,592
Share based compensation		30,501			-
Amortization of debt discount		2,176,996			168,935
Loss on embedded derivatives		3,030,218			96,280
Change in assets and liabilities
Accounts receivable		(97,853	)		(31,835	)
Related party receivable		12,522			(44,362	)
Other receivable		160,302			(141,658	)
Accounts payable and accrued expenses		189,582			(26,192	)
Accrued interest		75,939			120,330
Other payable		20,788			431,151
Net cash (used in) operating activities		(361,158	)		(488,875	)
CASH FLOWS USED IN INVESTING ACTIVITIES:
Acquisition of oil and gas properties		(274,527	)		(715,000	)
Net cash used in investing activities		(274,527	)		(715,000	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from convertible notes		615,000			1,565,000
Payment of note payable		-			(250,000	)
Payment of related party payable		-			(25,000	)
Payment of related party notes payable		-			(50,000	)
Net cash provided by financing activities		615,000			1,240,000
NET INCREASE IN CASH AND CASH EQUIVALENTS		(20,685	)		36,125
CASH AND CASH EQUIVALENTS - BEGINNING OF PERIOD		593,469			557,344
CASH AND CASH EQUIVALENTS - END OF PERIOD	$	572,784		$	593,469

The accompanying notes are an integral part of these consolidated financial statements.

F-6

	TWELVE MONTHS ENDING DECEMBER 31, 2012		TWELVE MONTHS ENDING DECEMBER 31, 2011
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid during the period for:
Interest	$	-	$	-
Taxes		-		-
NON CASH TRANSACTIONS:
Asset retirement liability incurred	$	9,790	$	37,955
Stock repurchase and cancellation		-		-
Common stock issued for oil and gas property		-		40,500
Acquisition of oil and gas properties with payables		-		84,975
Discount from derivative liabilities		324,541		880,373
Discount to additional paid-in capital from relative fair value of warrants		290,459		684,627
Conversion of convertible notes payable		2,800,000		-
Conversion of accrued interest		217,271		-
Settlement of derivative liabilities to additional paid-in capital		4,493,670		-

The accompanying notes are an integral part of these consolidated financial statements.

F-7

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

1. Nature of Operations and Basis of Presentation

Nature of Operations

4 Phoenix Oil & Gas, LLC, a limited liability company, was formed under the laws of the state of Texas on October 19, 2009 (“Predecessor”).   On August 10, 2010, we formed United American Petroleum Corp. a company incorporated under the laws of the state of Nevada.  United American Petroleum Corp.’s principal business is the acquisition and management of leasehold interests in petroleum and natural gas rights, either directly or indirectly, and the exploitation and development of properties subject to these leases.  In these notes, the terms “United,” “Company,” “we,” “us,” “successor," or “our” mean United American Petroleum Corp.

On December 31, 2010, the Company entered into a Plan of Merger (the “Merger”) with Forgehouse, Inc. and their newly formed wholly-owned subsidiary United PC Acquisition Corp. Following the closing and pursuant to the Plan of Merger, effective as of December 31, 2010, the Company merged with and into United PC Acquisition Corp. with the Company surviving (the “Reverse Merger”). The Company, as a wholly-owned subsidiary of Forgehouse, Inc. was then merged with and into Forgehouse, Inc. and Forgehouse, Inc. changed its name to United American Petroleum Corp. For accounting purposes, the Merger was treated as a reverse merger and a recapitalization of United American Petroleum Corp.

On January 13, 2011, the Company formed a wholly owned subsidiary, UAP Management, LLC, a Texas limited liability company, for the purpose of managing the Gabriel Rosser, LP (see Note 9).

On January 13, 2011, the Company formed a wholly owned subsidiary, United Operating, LLC, a Texas limited liability company, for the purpose of operating and managing the various interests acquired from Patriot Minerals, LLC (see Note 9).

 Basis of Presentation

The accompanying consolidated financial statements include United American Petroleum Corp. and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated. The accompanying financial statements have been prepared in accordance with the Generally Accepted Accounting Principles in the United States of America ("GAAP"). We made certain reclassifications to prior-period amounts to conform to the current presentation.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reported periods.  Actual results could materially differ from those estimates.

Cash and Cash Equivalents

All highly liquid investments purchased with an original maturity of three months or less at the time of acquisition are considered to be cash equivalents.

Fair Value of Financial Instruments

The Company is required to estimate the fair value of all financial instruments included on its balance sheet.  The carrying value of cash, accounts receivable, accounts payable and accrued liabilities approximate their fair value due to the short period to maturity of these instruments.

F-8

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

2.           Summary of Significant Accounting Policies

Concentration of Credit Risk

The Company collects its receivables on its working interests in oil and gas properties from well operators. As such, the Company generally has relatively few customers. These receivables are unsecured and the Company performs ongoing credit evaluations of the well operators’ financial condition whenever necessary. Bad debt is recognized on an account-by-account review after all means of collection have been exhausted and recovery is not probable. There has been no bad debt expense for the period ended December 31, 2012 and 2011, respectively.

Revenue Recognition- Oil and Gas

The Company recognizes oil and gas revenue from interests in producing wells using the “sales method.” Under this method of accounting, revenues are recognized based on volumes sold, which may differ from the volume to which we are entitled based on our working interest. An imbalance is recognized as a liability only when the estimated remaining reserves will not be sufficient to enable the under–produced owner(s) to recoup its entitled share through future production. Under the sales method, no receivables are recorded where we have taken less than our share of production. Our net imbalance position at December 31, 2012 and December 31, 2011, was immaterial.

Revenue Recognition – Well Operator Income

The Company will record revenue for well operator income only on properties for which the Company has no ownership in accordance with ASC 605.

For properties in which the Company has ownership, well operator income amounts may be recorded as reductions of the costs incurred, to the extent of identifiable and specific costs of the specific services for which the Company has been reimbursed. No income in excess of those specific costs was recorded and the Company recorded no offset to the full cost pool.

Oil and Gas Properties

The Company follows the full cost method of accounting for its investments in oil and gas properties. Under the full cost method, all costs associated with the exploration of properties are capitalized into appropriate cost centers within the full cost pool. Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities. Cost centers are established on a country-by-country basis.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

F-9

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

2.           Summary of Significant Accounting Policies (Continued)

For each cost center, capitalized costs are subject to an annual ceiling test, in which the costs shall not exceed the cost center ceiling. The cost center ceiling is equal to i) the present value of estimated future net revenues computed by applying current prices of oil and gas reserves (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; plus ii) the cost of properties not being amortized; plus iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; less iv) income tax effects related to differences between the book and tax basis of the properties. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs.

Asset Retirement Obligations

ASC 410, Asset Retirement and Environmental Obligations addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. Specifically, ASC 410 requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. In addition, the asset retirement cost is capitalized as part of the asset’s carrying value and subsequently allocated to expense over the asset’s useful life.

Fair Value of Financial Instruments

Unless otherwise indicated, the fair value of all reported assets and liabilities which represent financial instruments approximate the carrying values of such instruments due to their short-term maturity.

Recoverability of Long-Lived Assets

The Company has adopted Accounting Standards Codification subtopic 360-10, Property, Plant and Equipment (“ASC 360-10”). ASC 360-10 requires that long-lived assets and certain identifiable intangibles held and used by the Company be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

Events relating to recoverability may include significant unfavorable changes in business conditions or a forecasted inability to achieve break-even operating results over an extended period. The Company evaluates the recoverability of long-lived assets based upon forecasted undiscounted cash flows. Should impairment in value be indicated, the carrying value of intangible assets would be adjusted, based on estimates of future discounted cash flows resulting from the use and ultimate disposition of the asset. ASC 360-10 also requires assets to be disposed of be reported at the lower of the carrying amount or the fair value less costs to sell.

Share-Based Compensation

The Company accounts for share-based compensation in accordance with Accounting Standards Codification subtopic 718-10, Stock Compensation (“ASC 718-10”). This requires the measurement and recognition of compensation expense for all share-based payment awards made to employees and directors, including employee stock options and employee stock purchases related to an Employee Stock Purchase Plan based on the estimated fair values.

As of December 31, 2012, there were no outstanding employee stock options.

F-10

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

2.           Summary of Significant Accounting Policies (Continued)

Income Taxes

The Company has adopted Accounting Standards Codification subtopic 740-10, Income Taxes (“ASC 740-10”). ASC 740-10 requires the recognition of deferred tax liabilities and assets for the expected future tax consequences of events that have been included in the financial statement or tax returns. Under this method, deferred tax liabilities and assets are determined based on the difference between financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. Valuation allowances are established, when necessary, to reduce deferred tax assets to amounts that are expected to be realized.

Basic and Diluted Earnings (Loss) Per Share

Basic earnings (loss) per common share is computed by dividing net income (loss) available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per common share is computed in the same way as basic earnings (loss) per common share except that the denominator is increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued and if the additional common shares were dilutive.

Property and Equipment

Property and equipment is recorded at cost and depreciated over the estimated useful lives of the assets using principally the straight-line method. When items are retired or otherwise disposed of, income is charged or credited for the difference between net book value and proceeds realized. Ordinary maintenance and repairs are charged to expense as incurred, and replacements and betterments are capitalized.

The range of estimated useful lives used to calculated depreciation for principal items of property and equipment are as follow:

Asset Category	Depreciation Period
Furniture and Fixtures	5 Years
Automobiles	5 Years
Equipment	10 Years

Recent Accounting Pronouncements

In September 2011, the FASB issued Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350) - Testing Goodwill for Impairment (ASU 2011-08), to allow entities to use a qualitative approach to test goodwill for impairment. ASU 2011-08 permits an entity to first perform a qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying value. If it is concluded that this is the case, it is necessary to perform the currently prescribed two-step goodwill impairment test. Otherwise, the two-step goodwill impairment test is not required. ASU 2011-08 is effective for us in fiscal 2012 and earlier adoption is permitted. The Company is currently evaluating the impact of our pending adoption of ASU 2011-08 on our consolidated financial statements.

Management does not expect the adoption of recently issued accounting pronouncements to have a significant impact on our results of operations, consolidated financial position or cash flow.

3.           Going Concern

The Company has incurred a net loss and negative operating cash flows since inception through December 31, 2012. These factors raise substantial doubt about the Company's ability to continue as a going concern. The Company's management is implementing plans to sustain the Company’s cash flow from operating activities and/or acquire additional capital funding. The consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

F-11

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

4.           Reclassification

In accordance with the SEC’s Staff Accounting Bulletin No. 108, “Considering the Effects of Prior Year Misstatements when Quantifying Misstatements in Current Year Financial Statements” (“SAB 108”), the Company recorded a reclassification adjustment  for year ended December 31, 2011 of $145,726 which served to reduce Administrative income, Lease operating expenses and General & Administrative expenses.  This non-cash adjustment resulted from incorrectly recognizing revenue for administrative income collected from third party working interest owners of properties that were partially owned by the Company.   As a result of the Company’s evaluation of this error under SAB 108, the Company determined that this error was not material in relation to the current year, but not material to the year ended December 31, 2011.  Consequently, the December 31, 2011 income statement was adjusted to reflect the correction of this error.  In evaluating materiality and determining the appropriateness of applying SAB 108 to this error, the Company considered materiality both qualitatively and quantitatively as prescribed by the SEC’s Staff Accounting Bulletin No. 99.  The following table reflects the impact of the above error to the consolidated statements of operations as of and for the year ended December 31, 2011:

Certain amounts disclosed in prior periods have been reclassified to conform to current presentation. Such reclassifications are for presentation purposes only and have no effect on the Company’s net loss or financial position in any of the periods presented.

A summary of these changes by category is as follows:

	December 31, 2011			Reclassification of Previously Reported Activity			Adjusted December 31, 2011
Oil and Gas sales		141,362						141,362
Well Operator Income		215,178			(145,726	)		69,452
TOTAL REVENUE		356,540			(145,726	)		210,814
OPERATING EXPENSES (INCOME)
Lease operating expenses		109,865			(46,476	)		63,389
Accretion expense		2,592						2,592
Depletion expense		19,225						19,225
General and administrative		922,628			(99,249	)		823,379
TOTAL OPERATING EXPENSES		1,054,310			(145,726	)		908,584
NET LOSS BEFORE OTHER EXPENSE		(697,770	)		-			(697,770	)
OTHER INCOME (EXPENSE)
Interest Expense		(289,291	)					(289,291	)
Gain (Loss) on embedded derivatives		(96,280	)					(96,280	)
NET INCOME		(1,083,341	)		-			(1,083,341	)

5.            Related Party Receivable

As of December 31, 2012, the Company had a related party receivable in the amount of $13,196 due related to working interest amounts payable. This is a 51.31% (reduction) from an amount of $25,718 as of December 31, 2011.  Our directors are also officers in this Company.

F-12

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

6.            Embedded Derivative Liabilities

Conversion Option Liability

As described in Note 14, the Company issued a convertible note with certain reset provisions. The Company accounted for these reset provisions in accordance with ASC 815-40, which requires that the Company bifurcate the embedded conversion option as a liability at the grant date and to record changes in fair value relating to the conversion option liability in the statement of operations as of each subsequent balance sheet date.   The debt discount related to the convertible note is amortized over the life of the note using the effective interest method.  See Note 8 for a reconciliation of the changes in fair value of the Company’s embedded derivative.  

December 31, 2010 Convertible Note Installments (First Financing)

On April 13, 2012, the Company converted a $620,000 convertible note into 1,240,000 shares of common stock.  On the conversion date, the Company determined a fair value of $1,280,115 for the conversion option liability for this convertible note using the Black Scholes Option Pricing Model based upon the following:  dividend yield of -0-%, volatility of 108.17%, risk free rate of 0.27% and an expected term of approximately 1.72 years.  The Company recognized a non-cash loss included in other income (expense) of $982,960 preceding conversion during fiscal year 2012.

On June 1, 2012, the Company converted $590,000 of its convertible notes into 1,180,000 shares of common stock.  On the conversion date, the Company determined a fair value of $955,179 for these convertible notes using the Black Scholes Option Pricing Model based upon the following: dividend yield of -0-%, volatility of 111.24%, risk free rate of 0.25% and an expected term of approximately 1.58 years.  The Company recognized a non-cash loss included in other income (expense) of $668,692 preceding conversion during fiscal year 2012.

During fiscal year 2012, the Company recognized a reduction of embedded derivative from the first installment of its convertible notes in the amount of $2,235,294.  This amount was recorded to additional paid-in capital.

October 14, 2011 Convertible Note Installments (Second Financing)

On June 7, 2012, the Company converted $1,590,000 of its convertible notes into 3,180,000 shares of common stock.  On the conversion date, the Company determined a fair value of $2,258,376 for these convertible notes using the Black Scholes Option Pricing Model based upon the following: dividend yield of -0-%, volatility of 102.93%, risk free rate of 0.27% and an expected term of approximately 2.35 years.  The Company recognized a non-cash loss included in other expense of $674,380 preceding conversion for the year ended December 31, 2012.

During fiscal year 2012, the Company recognized a reduction of embedded derivative from the second installment of its convertible notes in the amount of $2,258,376.  This amount was recorded to additional paid-in capital.

F-13

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

7.            Detachable Warrants

As described in Note 14, the Company issued convertible notes with detachable warrants. The Company accounted for these detachable warrants in accordance with ASC 470-20, which requires that the Company calculate the relative fair value of the warrants at the grant date and record the relative fair value as a discount to the related note payable with an offset to additional paid-in capital. The Company amortizes the debt discount associated with the warrants over the life of the convertible notes using the effective interest method.

On February 10, 2012, the Company determined a relative fair value of $61,354 for the detachable warrants for the fourth installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 110.77%, risk free rate of 1.04% and an expected term of approximately 5 years.

On March 30, 2012, the Company determined a relative fair value of $130,853 for the detachable warrants for the sixth installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 110.64%, risk free rate of 1.04% and an expected term of approximately 5 years.

On June 4, 2012, the Company determined a relative fair value of $97,313 for the detachable warrants for the fifth installment of the convertible notes. In calculating the relative fair value of the warrants the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 112.94%, risk free rate of 0.27% and an expected term of approximately 4.69 years.

A summary of warrant activity for the period from December 31, 2011 through December 31, 2012 is presented below:

	Number of Warrants		Weighted Average Exercise Price		Weighted Average Remaining Contract Term
Outstanding December 31, 2011		2,185,000	$	1.00	3.45 years
Issued		615,000	$	1.00	4.17 years
Exercised		-		-	-
Outstanding December  31, 2012		2,800,000	$	1.00	3.61 years
Exercisable, December  31, 2012		2,800,000	$	1.00	3.61 years

Shares Reserved for Future Issuance

The Company has reserved shares for future issuance upon of its warrants as follows:

Warrants	2,800,000
Reserved shares at December  31, 2012	2,800,000

F-14

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2011 AND 2010

7.            Detachable Warrants (Continued)

December 31, 2010 – Convertible Note Installments (First Financing)

On December 31, 2010, the Company determined a relative fair value of $45,434 for the detachable warrants for the first installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of: -0-%, volatility of 94.1%, risk free rate: 2.01% and an expected term of 5 years.

On January 20, 2011, the Company determined a relative fair value of $78,062 for the detachable warrants for the second installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of: -0-%, volatility of 104.65%, risk free rate: 2.06% and an expected term of 5 years.

On March 9, 2011, the Company determined a relative fair value of $106,132 for the detachable warrants for the third installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 105.22%, risk free rate of 2.16% and an expected term of approximately 5 years.

On June 20, 2011, the Company determined a relative fair value of $29,276 for the detachable warrants for the fourth installment of the convertible notes.  In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 105.87%, risk free rate of 1.55% and an expected term of approximately 5 years.

On June 30, 2011, the Company determined a relative fair value of $45,233 for the detachable warrants for the fifth installment of the convertible notes.  In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 107.39%, risk free rate of 1.76% and an expected term of approximately 5 years.

As described in Note 5, during fiscal year 2012, these notes associated with the first financing were converted into share of common stock.

October 14, 2011 – Convertible Note Installments (Second Financing)

On October 14, 2011, the Company determined a relative fair value of $157,388 for the detachable warrants for the first installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 108.61%, risk free rate of 1.12% and an expected term of approximately 5 years.

On November 29, 2011, the Company determined a relative fair value of $209,317 for the detachable warrants for the second installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 109.19%, risk free rate of .93% and an expected term of approximately 5 years.

On December 19, 2011, the Company determined a relative fair value of $13,788 for the detachable warrants for the third installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 109.32%, risk free rate of .82% and an expected term of approximately 5 years.

As described in Note 6, during fiscal year 2012, these notes associated with the second financing were converted into shares of common stock.

F-15

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

8.           Fair Value

The Company measures fair value in accordance with a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy are described below:

Level 1	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities;
Level 2	Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability; and
Level 3	Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (supported by little or no market activity).

The following table sets forth the Company's consolidated financial assets and liabilities measured at fair value by level within the fair value hierarchy. Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

	Total		Level 1		Level 2		Level 3
LIABILITIES:
2012- Conversion option liability	-		-		-		-
2011- Conversion option liability		-		-		-		1,138,989

F-16

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

8.           Fair Value (Continued)

The following is a reconciliation of the conversion option liability and detachable warrant liability for which Level 3 inputs were used in determining fair value:

Beginning balance January 1, 2011	$	116,905
Initial recognition of debt derivative from issuance of     January 20, 2011, $150,000 convertible note		333,652
Initial recognition of debt derivative from issuance of     March 9, 2011, $250,000 convertible note		376,698
Initial recognition of debt derivative from issuance of     June 20, 2011, $75,000 convertible note		95,155
Initial recognition of debt derivative from issuance of     June 30, 2011, $115,000 convertible note		142,246
Initial recognition of debt derivative from issuance of    October 14, 2011, $400,000 convertible note		504,896
Initial recognition of debt derivative from issuance of     November 29, 2011, $550,000 convertible note		655,150
Initial recognition of debt derivative from issuance of     December 19, 2011, $25,000 convertible note		29,690
Decrease in fair value of debt derivative		(1,115,403	)
Ending balance as of December  31, 2011	$	1,138,989
Initial recognition of debt derivative from issuance of     February 10, 2012, $150,000 convertible note		189,052
Initial recognition of debt derivative from issuance of     March 30, 2012, $250,000 convertible note		514,784
Initial recognition of debt derivative from issuance of    June 4, 2012, $215,000 convertible note		325,831
Mark to market of debt derivative		2,325,015
Other		1,017
Total debt derivative preceding conversion		4,494,688
Reduction of debt derivative from conversion		(4,494,688	)
Debt derivative as of December 31, 2012	$	-

During the year ended December 31, 2012, the loss on embedded derivatives in the condensed consolidated statement of operations consisted of a loss on the change in fair value of $2,326,032 and a loss of $704,186 which was the amount by which the embedded derivative liabilities exceeded the principal of the related notes payable on the date the notes were issued.

During the year ended December 31, 2011, the loss on embedded derivatives of $96,280 in the consolidated statement of operations consisted of a gain on the change in fair value of $1,115,403 noted above and a loss of $1,211,683 which was the amount by which the embedded derivative liabilities exceeded the principal of the related notes payable on the date the notes were issued.

F-17

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

8.           Fair Value (Continued)

The Company’s conversion option liabilities are valued using pricing models and the Company generally uses similar models to value similar instruments. Where possible, the Company verifies the values produced by its pricing models to market prices. Valuation models require a variety of inputs, including contractual terms, market prices, yield curves, credit spreads, measures of volatility and correlations of such inputs. These consolidated financial liabilities do not trade in liquid markets, and as such, model inputs cannot generally be verified and do involve significant management judgment. Such instruments are typically classified within Level 3 of the fair value hierarchy. See Note 6 for Black Scholes Option Pricing Model inputs.

9.           Oil and Gas Properties

During the twelve months ended December 31, 2012, the Company proposed workover procedures to third party working interest owners on properties for which the Company has ownership.  Third party working interests owners were allowed to avoid liability associated with the procedures by conveying their working interests and net royalty interests to the Company. Certain third party working interest partners conveyed various working interests and net royalty interests in their properties.  The Company has assumed production revenues, lease operating expenses and asset retirement obligations associated with the conveyance of the working interests and net royalty interests.

During 2012, United American Petroleum Corp. performed drilling and completion procedures on the McKenzie, Marcee and Gabriel Rosser properties of $27,225, $44,792 and $177,000.

During 2012, United American Petroleum Corp. entered and closed a purchase and sale agreement to purchase an undivided working interest rights for the RP Wilson lease for $25,000 providing, among other things, that United American Petroleum Corp. shall purchase a 28% working interest, and a 26% revenue interest to certain existing wells and to certain leases located in Texas.

On January 28, 2011, United American Petroleum Corp. entered and closed a purchase and sale agreement with Patriot Minerals, LLC, a Texas limited liability company for a $5,000 payment to a consultant. The Purchase Agreement provides, among other things, that United American Petroleum Corp. shall purchase multiple undivided working interests to certain existing wells and to certain leases located in Texas. In connection with the Purchase Agreement, United American Petroleum Corp. formed a wholly owned subsidiary, United Operating, LLC, a Texas limited liability company, for the purpose of operating the various interests set forth in the Purchase Agreement. The properties purchased from Patriot Minerals by United American Petroleum Corp. are producing at December 31, 2011. The Company is currently undergoing various reserve studies to assess potential production and to continue the development of the wells purchased.

On January 28, 2011, United American Petroleum Corp. entered and closed a purchase, sale and participation agreement with Gabriel Rosser, LP (“Gabriel”). The purchase agreement provided for the Company to purchase Gabriel's undivided 50.83% working interest and 39.131% revenue interest in the Gabriel 2 SWD Gabriel 3, 4, 5, 9, 15, Rosser #2 and #4 and Koi #1wells in exchange for consideration of $10 and the assumed and paid $84,975 of liabilities, which were owed to certain vendors of Gabriel. The properties purchased from Gabriel Rosser, LP by United American Petroleum Corp. are unevaluated and non-producing as of December 31, 2011, and the Company is currently undergoing various reserve studies to assess potential production and develop the wells purchased.

On November 4, 2011, United American Petroleum Corp. entered into and closed an Agreement with Alamo Energy Corp., a Nevada corporation pursuant to which United American acquired a 75% working interest in an oil and gas lease totaling approximately 110 gross acres located in Frio County, Texas and all wellbores and personal property related thereto for the total purchase price of $160,000. The Company currently has a 100% working interest in the Lozano lease, which is a producing property with three wells.

On November 30, 2011, the Company entered into and closed an agreement with McKenzie Oil Corp. pursuant to which United American acquired a 100% working interest in what is designated as the McKenzie State Well No. 1, located in Pecos County, Texas, in exchange for an aggregate cash sum of $550,000 and 50,000 shares of the Company’s common stock valued at $40,500. The McKenzie well currently has one producing well valued at $80,655. The remaining wells are classified as unproved. 

F-18

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

10.          Related Party Payable

The related party payables were fully paid in December 2011.

11.          Note Payable – Related Party

As part of the Reverse Merger, the Company assumed two notes payable owed to an individual who is a shareholder of the Company. The notes payable are unsecured and each has a face value of $25,000 with a fixed interest rate of 10% per annum. The notes payable were due on demand and were fully paid in January 2011.

12.         Other Payable

As of December 31, 2012, United Operating, LLC received cash in the amount of $451,939 to perform work on behalf of various working interest owners including repairs, drilling and production related costs.

13.          Convertible Note Payable

Credit Facility – October 14, 2011

On October 14, 2011, we entered into a Note and Warrant Purchase Agreement with an investor pursuant to which the investor agreed to lend the Company up to $1,500,000 in multiple installments in exchange for a senior secured convertible promissory note with a conversion price of $0.50 per share and five-year warrants to acquire shares of common stock at an exercise price of $1.00 per share in the amount of each installment. The first installment of $400,000 was delivered on the date of the Purchase Agreement and we issued 400,000 warrants to the investor in connection with the first installment. The notes mature on October 14, 2014, or upon default, whichever is earlier and bear interest at an annual rate of 10%.

The second installment of $550,000 was delivered on November 29, 2011 and we granted warrants to purchase 550,000 shares in connection with the second installment.

The third installment of $25,000 was delivered on December 19, 2011 and we granted warrants to purchase 25,000 shares in connection with the third installment.

The fourth installment of $150,000 was delivered on February 10, 2012 and we granted warrants to purchase 150,000 shares in connection with the fourth installment.

The fifth installment of $250,000 was delivered on March 30, 2012 and we granted warrants to purchase 250,000 shares in connection with the fifth installment.

The sixth installment of $215,000 was delivered on June 4, 2012 and we granted warrants to purchase 430,000 shares in connection with the sixth installment.

F-19

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

13.          Convertible Note Payable (Continued)

Using a pro rata contribution, the Company allocated the proceeds of the February 10, 2012, March 30, 2012 and June 4, 2012, convertible notes (which were delivered during the nine months ended September 30, 2012) first to the relative fair value of the warrants and the remainder to the fair value of the embedded derivative on the date of grant as follows:

	February 10, 2012			March 30, 2012			June 4, 2012			Total
Total Proceeds	$	150,000		$	250,000		$	215,000		$	615,000
Allocated to:
Conversion Option Liability		189,052			514,783			325,831			1,029,666
Relative Fair Value of Warrants		61,354			130,853			97,313			289,520
Total Fair Value of Derivative		250,406			645,636			423,144			1,319,186
Debt Discount		(150,000	)		(250,000	)		(215,000	)		(615,000	)
Loss on debt derivative	$	100,406		$	395,636		$	208,144		$	704,186

During the years ended December 31, 2012 and 2011, the Company amortized $2,155,448 and $168,935 of the debt discount to interest expense.  The debt discount from the convertible notes was immediately expensed upon the conversion of the convertible notes during the period ended December 31, 2012.

On June 7, 2012, the Company issued 3,314,062 shares of common stock to one investor who elected to convert the outstanding principal amount of $1,590,000 and all of the accrued interest due on its convertible promissory notes dated October 14, 2011, November 29, 2011, December 19, 2011, February 10, 2012, March 30, 2012 and June 4, 2012 at a conversion price of $0.50 per share as provided in the note agreement.

Credit Facility – December 31, 2010

On December 31, 2010, the Company entered into a credit facility with one investor pursuant to which the investor agreed to lend up to $2,250,000 to us in multiple installments in exchange for a senior secured convertible promissory note with a conversion price of $0.50 per share and five-year warrants to acquire shares of common stock at an exercise price of $1.00 per share in the amount of each installment. The credit facility provides that the investor will lend additional installments to us in amounts as requested by us; provided however, that we provide the proposed use of proceeds for each requested amount. The investor shall have sole discretion in determining whether the proposed use of proceeds meets those requirements. The notes mature on December 31, 2013, or upon default, whichever is earlier and bear interest at an annual rate of 10%.

On April 13, 2012, the Company issued 1,240,000 shares of common stock to one investor who elected to convert the outstanding principal amount of $620,000 due on its convertible promissory note dated December 31, 2010 at a conversion price of $0.50 per share as provided in the note agreement.

On June 1, 2012, the Company issued 1,180,000 shares of common stock to one investor who elected to convert the outstanding principal amount of $590,000 due on its convertible promissory notes dated January 1, 2011, March 9, 2011, June 20, 2011 and June 30, 2011 at a conversion price of $0.50 per share as provided in the note agreement.

On June 11, 2012, the Company issued 300,481 shares of common stock to one investor who elected to convert all of their accrued interest in the amount of $150,240 on its convertible notes from its first financing at a conversion price of $0.50 per share as provided in the note agreement.

F-20

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2011 AND 2010

14.            Asset Retirement Obligation

The Company accounts for its future asset retirement obligations by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset.  The Company depletes the amount added to proved oil and gas property costs and gathering assets using the units-of-production method.  The Company’s asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties and gathering assets. The asset retirement liability is allocated to operating expense using a systematic and rational method. The information below reconciles the value of the asset retirement obligation for the periods presented.

	Year ended December 31, 2012		Year ended December 31, 2011
Beginning of the period	$	56,012	$	15,465
Liabilities incurred		9,790		37,955
Accretion expense		3,514		2,592
Balance at end of the period	$	69,316	$	56,012

15.          Equity

Fiscal Year 2012

On October 11, 2012, the Company filed with the Nevada Secretary of State, a Certificate of Designations, Establishing the Designations, Preferences, Limitations and Relative Rights of Its Series B Preferred Stock (the “Designation”).  The Designation, which was approved by the Board of Directors on October 9, 2012 and authorized under the Company’s Articles of Incorporation, provides the Board of Directors the right to designate series of preferred stock, provided for the designation of a series of 1,000 shares of Series B Preferred Stock, par value $0.001 per share (the “Series B Preferred Stock”).  The Series B Preferred Stock have no dividend rights, no liquidation preference, no redemption rights and no conversion rights. The Series B Preferred Stock have the right, voting in aggregate, to vote on all shareholder matters (including, but not limited to, at every meeting of the stockholders of the Company and upon any action taken by stockholders of the Company with or without a meeting) equal to fifty-one percent (51%) of the total vote (the “Super Majority Voting Rights”). Additionally, we are not allowed to adopt any amendments to our Bylaws, Articles of Incorporation, as amended, make any changes to the Certificate of Designations establishing the Series B Preferred Stock, or effect any reclassification of the Series B Preferred Stock, without the affirmative vote of at least 66-2/3% of the outstanding shares of the Series B Preferred Stock.

As described in Note 6, during the year ended December 31, 2012, certain notes payables were converted into 6,034,542 shares of common stock.  See Note 17 related to share based compensation issued by the Company in fiscal year 2012.

Fiscal Year 2011

On November 29, 2011, the Company issued 50,000 shares of common stock as consideration for the McKenzie working interest for $40,500 (0.81 per share).

16.          Share Based Compensation

On December 21, 2012 directors of the Company approved share based compensation plan for an employee, an advisor and independent investor relations advisor of 80,000, 125,000 and 100,000 shares of common stock as share based compensation.  These shares were issued at a market price of $0.10 per share.  During the twelve months ended December 31, 2012, the Company recognized $30,500 as share based compensation expense.

On December 26, 2012, the Company issued 500 shares of Series B Preferred Stock, each to Michael Carey, its Chief Executive Officer, President and Director, and Ryan Hudson, its Chief Operating Officer, Secretary and Director (1,000 shares of Series B Preferred Stock in aggregate), in consideration for services rendered to the Company as the Company’s Chief Executive Officer, President and Director, and Chief Operating Officer, Secretary and Director, respectively.  The Company has evaluated the fair value of the share based compensation is $1.

F-21

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

17.          Income taxes

As of December 31, 2012, our deferred tax asset amounting to $264,635 primarily related to our net operating losses of $794,519.  A 100% valuation allowance has been established using an effective tax rate of 35% due to the uncertainty of the utilization of the operating losses in future periods.  As a result, the deferred tax asset was reduced to zero and no income tax benefit was recorded. The net operating loss carryforward will begin to expire in 2031.

Section 382 of the Internal Code allows post-change corporations to use pre-change net operating losses, but limit the amount of losses that may be used annually to a percentage of the entity value of the corporation at the date of the ownership change.  The applicable percentage is the federal long-term tax-exempt rate for the month during which the change in ownership occurs.

18.          Supplemental Oil and Gas Reserve Information

Company Reserve Estimates. Our proved reserve information as of December 31, 2012 was estimated by Mire and Associates, Inc. (“Mire”), independent petroleum engineers.  In accordance with SEC guidelines, Mire’s estimates of future net revenues from our properties, and the PV-10 and standardized measure thereof, were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the period January 1, 2012 through December 31, 2012, except where such guidelines permit alternate treatment, including the use of fixed and determinable contractual price escalations.

The technical persons at Mire are responsible for preparing the reserves estimates presented herein and meets the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. Michael Carey, our officer and director, acted as the liaison with the technical persons at Nova and Mire. 

Reserve Technologies.  Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and 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.  If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered.  If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate.  To achieve reasonable certainty, Nova and Mire employed technologies that have been demonstrated to yield results with consistency and repeatability. The technologies and economic data used in the estimation of our proved reserves include, but are not limited to, well logs, geologic maps and available down well and production data, seismic data, well test data.

Oil and Gas Reserve Information.  The following reserve quantities for our proved reserves located in the State of Texas in the United States have been estimated as of December 31, 2012.  The determination of oil and gas reserves is based on estimates, which are highly complex and interpretive. The estimates are subject to continuing changes as additional information becomes available.

The following table sets forth the proved developed and proved undeveloped reserves for the three year period ended December 31, 2012.

F-22

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

18.           Supplemental Oil and Gas Reserve Information (Continued)

Reserve Category	At December 31,  2012		At December 31,  2011		At December 31,  2010
Proved Developed:
Crude Oil (Bbls)		61,180		29,802		2,274
Natural Gas (Mcf)		29,360		46,536		-
Total Oil Equivalent (BOE)		66,073		37,558		2,274
Proved Undeveloped:
Crude Oil (Bbls)		-		8,528		1,806
Natural Gas (Mcf)		-		2,870		-
Total Oil Equivalent (BOE)		-		9,006		1,806

The following table sets forth purchase, production and reserve adjustment activities for the three year period ended December 31, 2012.

Reserved Quantity	Oil (BBLS)			Natural Gas (MCF)
Balance, August 10, 2010		-			-
Purchases		4,204			-
Production		(124	)		-
Balance, December 31, 2010		4,080			-
Purchases		35,560			49,948
Production		(1,310	)		(542	)
Balance, December 31, 2011		38,330			49,406
Purchases
Production		5,823			1,404
Adjustments to existing reserves		22,850			(20,046	)
Balance, December 31, 2012		67,003			30,764

The standardized measure of discounted future net cash flows is provided using the 12-month unweighted arithmetic average and were held constant throughout the life of the properties. The oil price used as of December 31, 2012 was $94.71 per bbl of oil and $2.85 per MMbtu of natural gas. Future production costs are based on year-end costs and include severance and ad valorem taxes. Each property that is leased by us is also charged with field-level overhead in the reserve calculation. The present value of future cash inflows is based on a 10% discount rate.

Standardized Measure of Future Net Cash Flows:

	December 31, 2012			December 31, 2011			December 31, 2010
Future cash flows	$	5,962,350		$	3,278,186		$	231,430
Future production and development costs		(3,484,120	)		(1,377,560	)		(90,258	)
Future income taxes		-			-			-
Future net cash flows before discount		2,478,230			1,900,626			141,172
10% discount to percent value		(1,133,720	)		(769,576	)		(61,484	)
Standardized measure of discounted future net cash flows	$	1,344,510		$	1,131,050			79,688

F-23

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

18.          Supplemental Oil and Gas Reserve Information (Continued)

Changes in the Standard Measure of Discounted Cash Flows:

	December 31, 2012			December 31, 2011			December 31, 2010
Standardized measure of discounted future net cash flows    beginning of period	$	1,131,050		$	79,688		$	-
Purchases of reserves in place		-			1,064,368			-
Extension and discoveries, net of future production    and development costs		112,227			-			89,901
Sales of oil and gas produced, net of production costs		(111,914	)		(31,497	)		(10,213	)
Extension and discoveries, net of future production    and development costs		113,105			7,969			-
Revisions of previous quantity estimates		1,465,199			(68,859	)		-
Net change in prices and production costs		(1,186,254	)		26,611			-
Net change in income taxes		-			-			-
Changes in timing and other		(178,903	)		52,770			-
Standardized measure of discounted future net cash flows end of period	$	1,344,510		$	1,131,050		$	79,668

The information required by Items 1204 to 1208 of Regulation S-K are provided as follows:

Production. For the year ended December 31, 2012, we had production from our Lozano, Marcee, McKinney and Patriot leases located in six Texas counties: Erath, Gonzalez, Medina, Navarro, Shackleford and Wilbarger.  The Company produced approximately 5,823 barrels of oil and 1,404 Mcf (thousand cubic feet) of gas on a net basis.

For the year ended December 31, 2011, we only had production from our interest in the Lozano lease located in Frio County, Texas.  The Company produced approximately 1,310 barrels and 542 Mcf on a net basis.

Drilling Activity.  During the month of December 2011 and January 2012, we conducted unsuccessful drilling activity in Texas on the Gabriel #16 well to test an anticipated payzone in the Serpentine formation.  Based upon the Company’s current working capital and access to funding, the Company does not plan to conduct any new drilling during 2013.  The Company will focus on increasing existing producing properties and production from workover ventures on existing wells.

F-24

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

18.          Supplemental Oil and Gas Reserve Information (Continued)

We own mineral interests leases on the following productive wells, developed acreage and undeveloped acreage in Texas.  Other properties outside of Texas have been excluded from this table.

	December 31, 2012
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1
Gross & Net Developed Acreage		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29

	December 31, 2011
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1
Gross & Net Developed Acreage		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29

	December 31, 2011
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		3		11		-		-
Gross & Net Developed Acreage		110		83		-		-
Gross & Net Undeveloped Acreage		453		91		-		-

19.             Subsequent Events

During the three month period ended March 31, 2013, the Company secured certain funding from external sources including two convertible notes payable in the amount of $100,000 and $50,000.

The Company solicited $114,000 of funds from working interest partners to cover non-consenting working interest partners portions of workover costs on the Merrick Davis, Crouch and Lane Heady properties.  As of the date of this report, the Company has completed workovers on these properties and is awaiting production results.

F-25

Item 9.  Changes In and Disagreements With Accountants on Accounting and Financial Disclosure.

None.

Item 9A. Controls and Procedures.

Evaluation of disclosure controls and procedures.

We maintain controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management including our principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosures. Based upon their evaluation of those controls and procedures performed as of the end of the period covered by this report, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were not effective due to our over reliance on consultants in our accounting and financial statement closing processes.

Deficiencies in Our Control Environment.

Our control environment did not sufficiently promote effective internal control over financial reporting throughout the organization. This material weakness exists because of the aggregate effect of multiple deficiencies in internal control which affect our control environment, including: a) the lack of an effective risk assessment process for the identification of fraud risks; b) the lack of an internal audit function or other effective mechanism for ongoing monitoring of the effectiveness of internal controls; c) deficiencies in our accounting system and controls; d) and insufficient documentation and communication of our accounting policies and procedures as of December 31, 2012.

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Annual report on internal control over financial reporting.

Mr. Michael Carey, our Principal Executive and Financial Officer, is responsible for establishing and maintaining adequate internal control over financial reporting.  Internal control over financial reporting is defined in Rule 13a-15(f) and 15d-15(f) promulgated under the Securities Exchange Act of 1934, as amended, as a process designed by, or under the supervision of, our principal executive and principal financial officers and effected by our Board of Directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles and includes those policies and procedures that:

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

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

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

Because of its inherent limitations, our internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.  Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Our Principal Executive and Financial Officer assessed the effectiveness of our internal control over financial reporting as of December 31, 2012.   In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control — Integrated Framework.

Based on our assessment, our Principal Executive and Financial Officer believes that, as of December 31, 2012, our internal control over financial reporting is not effective based on those criteria, due to the following:

  ●  Deficiencies in Segregation of Duties.  Lack of proper segregation of functions, duties and responsibilities with respect to our cash and control over the disbursements related thereto due to our very limited staff, including our accounting personnel.

  ●  Deficiencies in Our Control Environment. Our control environment did not sufficiently promote effective internal control over financial reporting throughout the organization. This material weakness exists because of the aggregate effect of multiple deficiencies in internal control which affect our control environment, including: a) the lack of an effective risk assessment process for the identification of fraud risks; b) the lack of an internal audit function or other effective mechanism for ongoing monitoring of the effectiveness of internal controls; c) deficiencies in our accounting system and controls; and d) and insufficient documentation and communication of our accounting policies and procedures as of December 31, 2012.

  ● Deficiencies in the staffing of our financial accounting department. The number of qualified accounting personnel with experience in public company SEC reporting and GAAP is limited. This weakness does not enable us to maintain adequate controls over our financial accounting and reporting processes regarding the accounting for non-routine and non-systematic transactions. There is a risk that a material misstatement of the financial statements could be caused, or at least not be detected in a timely manner, by this shortage of qualified resources.

In light of this conclusion and as part of the preparation of this report, we have applied compensating procedures and processes as necessary to ensure the reliability of our financial reporting. Accordingly, management believes, based on its knowledge, that (1) this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made not misleading with respect to the period covered by this report, and (2) the financial statements, and other financial information included in this report, fairly present in all material respects our financial condition, results of operations and cash flows for the years and periods then ended.

This report does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting.  Management's report was not subject to attestation by our independent registered public accounting firm pursuant to temporary rules of the SEC that permit us to provide only management’s report in this report.

Changes in Internal Control over Financial Reporting

There were no significant changes in our internal control over financial reporting during the fourth quarter of the year ended December 31, 2012, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 9B. Other Information.

None.

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PART III

Item 10.  Directors, Executive Officers and Corporate Governance.

Executive Officers and Directors. Each of our officers is elected by the Board of Directors for a term of one year and serves until his or her successor is duly elected and qualified, or until he or she is removed from office. Our directors and principal executive officers are as specified on the following table:

Name	Age	Position
Michael Carey	32	Chief Executive Officer, Chief Financial Officer, President, Treasurer, and Director
Ryan Hudson	36	Chief Operating Officer, Secretary, and Director

The business experience of each of the persons listed above during the past five years is as follows:

Michael Carey.   Michael Carey was appointed as our Chief Executive Officer, President and a Director in December 2010 and was appointed as our Chief Financial Officer and Treasurer in February 2012.  From October 15, 2010 to December 31, 2010, the date the Merger Transaction closed, Mr. Carey was the Chief Executive Officer of United.  Prior to joining United, Mr. Carey previously worked for Trius Operations, LLC, and 4 Phoenix Oil & Gas LLC, doing business as Phoenix Oil & Gas LLC. From 2002 to 2004, Mr. Carey served as senior vice president at Richman Oil. Mr. Carey also previously served as junior vice president for CKG Energy.  Mr. Carey is not an officer or director of any other reporting company.

Director Qualifications:

Mr. Carey has extensive industry knowledge as well as a deep knowledge of the Company’s operations. Mr. Carey’s industry experience brings valued insight to all facets of the Company.

Ryan Hudson.   Ryan Hudson was appointed as our Chief Operating Officer and Secretary in December 2010.  Mr. Hudson was appointed as a Director in March 2011.  From October 15, 2010 to December 31, 2010, the date the Merger Transaction closed, Mr. Hudson was the Chief Operating Officer of United.  Prior to joining United, Mr. Hudson worked for Trius Operations, LLC, and 4 Phoenix Oil & Gas, doing business as Phoenix Oil & Gas LLC. From 2001 to 2004, Mr. Hudson served as senior vice president at Richman Oil.  Mr. Hudson is also a certified firefighter and received his firefighter certification from the Texas Commission on Fire Protection. Mr. Hudson is not an officer or director of any other reporting company.  

Director Qualifications:

Mr. Hudson has extensive industry knowledge as well as a deep knowledge of the Company’s operations. Mr. Hudson’s industry experience brings valued insight to all facets of the Company.

Involvement in Certain Legal Proceedings

None of our directors have been involved in any of the following events during the past ten years:

1.	any bankruptcy petition filed by or against any business of which such person was a general partner or executive officer either at the time of the bankruptcy or within two years prior to that time;
2.	any conviction in a criminal proceeding or being subject to a pending criminal proceeding (excluding traffic violations and other minor offenses);
3.	being subject to any order, judgment, or decree, not subsequently reversed, suspended or vacated, of any court of competent jurisdiction, permanently or temporarily enjoining, barring, suspending or otherwise limiting his involvement in any type of business, securities or banking activities; or
4.	being found by a court of competent jurisdiction (in a civil action), the Commission or the Commodity Futures Trading Commission to have violated a federal or state securities or commodities law, and the judgment has not been reversed, suspended, or vacated.

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Corporate Governance

The Company promotes accountability for adherence to honest and ethical conduct; endeavors to provide full, fair, accurate, timely and understandable disclosure in reports and documents that the Company files with the Securities and Exchange Commission (the “SEC”) and in other public communications made by the Company; and strives to be compliant with applicable governmental laws, rules and regulations. The Company has not formally adopted a written code of business conduct and ethics that governs the Company’s employees, officers and directors as the Company is not required to do so.

In lieu of an Audit Committee, the Company’s Board of Directors is responsible for reviewing and making recommendations concerning the selection of outside auditors, reviewing the scope, results and effectiveness of the annual audit of the Company's financial statements and other services provided by the Company’s independent public accountants. The Board of Directors reviews the Company's internal accounting controls, practices and policies.

Committees of the Board

Our Company currently does not have nominating, compensation, or audit committees or committees performing similar functions nor does our Company have a written nominating, compensation or audit committee charter. Our directors believe that it is not necessary to have such committees, at this time, because the functions of such committees can be adequately performed by the directors.

Nominating Process.   Our entire Board of Directors participates in consideration of director nominees. The Board of Directors will consider candidates who have experience as a board member or senior officer of a company or who are generally recognized in a relevant field as a well-regarded practitioner, faculty member or senior government officer.  The Board of Directors will also evaluate whether the candidates' skills and experience are complementary to the existing Board's skills and experience as well as the Board of Directors' need for operational, management, financial, international, technological or other expertise. The board of directors will interview candidates that meet the criteria and then select nominees that the Board of Directors believes best suit our needs.

The Board of Directors will consider qualified candidates suggested by stockholders for director nominations. Stockholders can suggest qualified candidates for director nominations by writing to our Corporate Secretary, at 9600 Great Hills Trail, Suite 150W, Austin, TX 78759. Submissions that are received that meet the criteria described above will be forwarded to the Board of Directors for further review and consideration. The board of directors will not evaluate candidates proposed by stockholders any differently than other candidates. There have been no material changes to the procedures by which our stockholders may recommend nominees to the Board of Directors.

Director Independence. The Over-The-Counter Bulletin Board does not have rules regarding director independence.  The Company will seek to appoint independent directors, if and when it is required to do so.

Board Meetings and Annual Meeting. During the fiscal year ended December 31, 2012, our Board of Directors held 3 meetings.  We did not hold an annual meeting in 2012. Each director attended at least 75% of the total number of meetings of the board.

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Audit Committee and Audit Committee Financial Expert.   Presently, the board of directors acts as the audit committee. The board of directors does not have an audit committee financial expert. The board of directors has not yet recruited an audit committee financial expert to join the board of directors because we have only recently commenced a significant level of financial operations.

Code of Ethics. We do not currently have a Code of Ethics that applies to all employees, including our principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions. The Board of Directors evaluated the business of the Company and the number of employees and determined that since the business is operated by a small number of persons, general rules of fiduciary duty and federal and state criminal, business conduct and securities laws are adequate ethical guidelines.   In the event our operations, employees and/or directors expand in the future, we may take actions to adopt a formal Code of Ethics.

Section 16 (A) Beneficial Ownership Reporting Compliance

Section 16(a) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) requires our directors and officers, and the persons who beneficially own more than ten percent of our common stock, to file reports of ownership and changes in ownership with the SEC. Copies of all filed reports are required to be furnished to us pursuant to Rule 16a-3 promulgated under the Exchange Act.  

Based solely on the reports received by us and on the representations of the reporting persons, we believe that all required directors, officers and greater than ten percent shareholders complied with applicable filing requirements during the fiscal years ended December 31, 2012, 2011 and 2010, except that:

(a)       (b) Ryan Hudson, our Chief Operating Officer, Secretary and Director, and a greater than ten percent shareholder of the Company inadvertently did not timely file (i) a Form 3 relating to his initial ownership of the Company’s common stock on December 31, 2010, which Form 3 was not filed until January 10, 2011; and (ii) a Form 4 filing relating to the transfer by him of 500,000 shares of common stock to a third party in consideration for the third party dismissing a lawsuit against him on November 28, 2012, which Form 4 was subsequently filed on December 26, 2012; and   Michael Carey, our Chief Executive Officer, President and Director, and a greater than ten percent shareholder of the Company inadvertently did not timely file (i) a Form 3 relating to his initial ownership of the Company’s common stock on December 31, 2010, which Form 3 was not filed until January 10, 2011; and (ii) a Form 4 filing relating to the transfer by him of 500,000 shares of common stock to a third party in consideration for the third party dismissing a lawsuit against him on November 28, 2012, which Form 4 was subsequently filed on December 26, 2012. 

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Item 11. Executive Compensation.

Summary Compensation Table.   The table set forth below summarizes the annual and long-term compensation for services in all capacities to us payable to our principal executive officers for the fiscal years ending December 31, 2012 and 2011.

SUMMARY COMPENSATION TABLE
Name and Principal Position	Year Ended	Salary $	Bonus $	Stock Awards $	Option Awards $	Non-Equity Incentive Plan Compensation $	Nonqualified Deferred Compensation Earnings $	All Other Compensation $	Total $
Michael Carey, Chief Executive Officer, and President	2012	$100,000	None	$0.50 (2)	None	None	None	None	$100,000.50
	2011	77,704	None	None	None	None	None	None	77,704
Ryan Hudson, Chief Operating Officer, and Secretary	2012	$100,000	None	$0.50 (2)	None	None	None	None	100,000.50
	2011	76,954	None	None	None	None	None	None	76,954
Christian Negri, Former Treasurer(1)	2012	----	None	None	None	None	None	None	----
	2011	59,538	None	None	None	None	None	None	59,538

(1) On December 31, 2010, Christian Negri resigned his positions as President and Secretary.  On February 28, 2012, Christian Negri resigned his positions as Treasurer and a Director.

(2) Represents 500 shares of the Company’s Series B Preferred Stock.

* Does not include perquisites and other personal benefits, or property, unless the aggregate amount of such compensation is more than $10,000.  The value of the Stock Awards and Option Awards in the table above, if any, were calculated based on the fair value of such securities calculated in accordance with Financial Accounting Standards Board Accounting Standards Codification Topic 718.

33

Employment Contracts and Termination of Employment.  

Michael Carey

On December 31, 2010, pursuant to the terms of the Merger Agreement, we assumed United’s employment agreement with Mr. Carey, dated October 15, 2010 (“Carey Employment Agreement”).  Under the terms of the Carey Employment Agreement, Mr. Carey will receive a salary of $6,000 per month with incremental raises on a quarterly basis.   Mr. Carey is not expected to receive any compensation from us for his service as a director.  For the year ended December 31, 2012, Mr. Carey received a salary of $100,000. The Carey Employment Agreement has a term of three years expiring on October 15, 2013, provided that the agreement automatically extends for additional one year terms unless either party provides the other party at least ninety days prior notice of their intent not to renew.  The Carey Employment Agreement also provides Mr. Carey the right to earn a bonus each year in the discretion of the Board of Directors.  Pursuant to the Carey Employment Agreement, Mr. Carey agreed to not compete with the Company during the term of the agreement and to not solicit certain employees of the Company for a period of 12 months after the termination of the agreement.  The agreement also required Mr. Carey to provide the Company the right of first refusal to purchase any interests of Trius Energy, LLC and 4 Phoenix Oil & Gas, LLC, entities which Mr. Carey beneficially owns, in the event he receives bona fide offers to sell such interests. If, during the term of the agreement, Mr. Carey’s employment is terminated either by the Company or Mr. Carey due to the death or disability of Mr. Carey, or by the Company other than for cause (as such term is defined in the agreement), the Company is required (subject to certain conditions) to pay Mr. Carey a severance benefit equal to three months of base salary.

Ryan Hudson

On December 31, 2010, pursuant to the terms of the Merger Agreement, we assumed United’s employment agreement with Mr. Hudson, dated October 15, 2010 (“Hudson Employment Agreement”).  Under the terms of the Hudson Employment Agreement, Mr. Hudson will receive a salary of $6,000 per month with incremental raises on a quarterly basis. For the year ended December 31, 2012, Mr. Hudson received a salary of $100,000. The Hudson Employment Agreement has a term of three years expiring on October 15, 2013, provided that the agreement automatically extends for additional one year terms unless either party provides the other party at least ninety days prior notice of their intent not to renew.  The Hudson Employment Agreement also provides Mr. Hudson the right to earn a bonus each year in the discretion of the Board of Directors.  Pursuant to the Hudson Employment Agreement, Mr. Hudson agreed to not compete with the Company during the term of the agreement and to not solicit certain employees of the Company for a period of 12 months after the termination of the agreement.  The agreement also required Mr. Hudson to provide the Company the right of first refusal to purchase any interests of Trius Energy, LLC and 4 Phoenix Oil & Gas, LLC, entities which Mr. Hudson beneficially owns, in the event he receives bona fide offers to sell such interests. If, during the term of the agreement, Mr. Hudson’s employment is terminated either by the Company or Mr. Hudson due to the death or disability of Mr. Hudson, or by the Company other than for cause (as such term is defined in the agreement), the Company is required (subject to certain conditions) to pay Mr. Hudson a severance benefit equal to three months of base salary.

Series B Preferred Stock

On October 11, 2012, the Company filed with the Nevada Secretary of State, a Certificate of Designations, Establishing the Designations, Preferences, Limitations and Relative Rights of Its Series B Preferred Stock (the “Designation”).  The Designation, which was approved by the Board of Directors on October 9, 2012 and authorized under the Company’s Articles of Incorporation, provides the Board of Directors the right to designate series of preferred stock, provided for the designation of a series of 1,000 shares of Series B Preferred Stock, par value $0.001 per share (the “Series B Preferred Stock”).  The Series B Preferred Stock have no dividend rights, no liquidation preference, no redemption rights and no conversion rights. The Series B Preferred Stock have the right, voting in aggregate, to vote on all shareholder matters (including, but not limited to, at every meeting of the stockholders of the Company and upon any action taken by stockholders of the Company with or without a meeting) equal to fifty-one percent (51%) of the total vote (the “Super Majority Voting Rights”). Additionally, we are not allowed to adopt any amendments to our Bylaws, Articles of Incorporation, as amended, make any changes to the Certificate of Designations establishing the Series B Preferred Stock, or effect any reclassification of the Series B Preferred Stock, without the affirmative vote of at least 66-2/3% of the outstanding shares of the Series B Preferred Stock.

On December 26, 2012, the Company issued 500 shares of Series B Preferred Stock, each to Michael Carey, its Chief Executive Officer, President and Director, and Ryan Hudson, its Chief Operating Officer, Secretary and Director (1,000 shares of Series B Preferred Stock in aggregate), in consideration for services rendered to the Company as the Company’s Chief Executive Officer, President and Director, and Chief Operating Officer, Secretary and Director, respectively.

Any compensation received by our officers, directors, and management personnel will be determined from time to time by our Board of Directors.  As of December 31, 2012, our directors are not paid any compensation for their service as directors. They are nevertheless reimbursed for their reasonable expenses incurred upon presentation of the appropriate documentary evidence.

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Outstanding Equity Awards.   As of December 31, 2012, the following named executive officers had the following unexercised options, stock that has not vested, and equity incentive plan awards:

Option  Awards						Stock Awards
Name	Number of Securities Underlying Unexercised Options # Exercisable	# Un-exercisable	Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Options	Option Exercise Price	Option Expiration Date	Number of Shares or Units of Stock Not Vested	Market Value of Shares or Units  Not Vested	Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights Not Nested	Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights Not Vested
Michael Carey Chief Executive Officer, President,  Director	-	-	-	-	-	-	-	-	-
Ryan Hudson Chief Operating Officer, Secretary, Director	-	-	-	-	-	-	-	-	-
Christian Negri Former Treasurer, Director*	-	-	-	-	-	-	-	-	-

* On February 28, 2012, Christian Negri resigned his positions as Treasurer and a Director.

Equity Compensation Plans. Effective on or around January 22, 2008, shareholders holding a majority of the Company’s voting securities approved the Company’s 2008 Incentive Plan (the “Plan”), which was previously approved by the then sole director of the Company on January 2, 2008. The Plan provided for the issuance of a total of up to 3,000,000 shares of common stock, options, restricted share units, share appreciation rights and other share based awards to acquire common stock to employees, directors and consultants.  A total of 1,877,000 options were granted during the year ended December 31, 2008, which options were subsequently forfeited during the years ended December 31, 2009 and 2008.  The Company does not anticipate issuing any additional shares of common stock under the Plan moving forward.

Stock Options/SAR Grants . No grants of stock options or stock appreciation rights were made during the fiscal year ended December 31, 2012.

Long-Term Incentive Plans . There are no arrangements or plans in which we provide pension, retirement or similar benefits for directors or executive officers. We do not have any material bonus or profit sharing plans pursuant to which cash or non-cash compensation is or may be paid to our directors or executive officers.

Director Compensation For the year ended December 31, 2012, we did not have any directors who did not also serve as executive officers of the Company and whose total compensation (including compensation as an officer and director) is included in the table above.

Name	Fees Earned or Paid in Cash	Stock Awards $	Option Awards $	Non-Equity Incentive Plan Compensation $	Non-Qualified Deferred Compensation Earnings $	All Other Compensation $	Total $
Michael Carey	-	-	-	-	-	-	-
Ryan Hudson	-	-	-	-	-	-	-
Christian Negri*	-	-	-	-	-	-	-

*   On February 28, 2012, Christian Negri resigned his positions as Treasurer and a Director.

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

The following table sets forth certain information regarding the beneficial ownership of our common stock as of April 14, 2013,by (i) each person or entity known by us to be the beneficial owner of more than 5% of the outstanding shares of common stock, (ii) each of our directors, (iii) our executive officers, and (iv) all of our   directors and executive officers as a group.

The number and percentage of shares beneficially owned is determined under Rule 13d-3 as promulgated under the Securities Exchange Act of 1934, as amended, by the Securities and Exchange Commission (SEC), and the information is not necessarily indicative of beneficial ownership for any other purpose. Under such rules, beneficial ownership includes any shares as to which the individual has sole or shared voting power or dispositive power and also any shares that the individual has the right to acquire within sixty (60) days of April 14, 2013 through the exercise of any stock option or other right.

We believe that, except as otherwise noted and subject to applicable community property laws, each person named in the following table has sole investment and voting power with respect to the shares of common stock shown as beneficially owned by such person. Unless otherwise indicated, the address for each of the officers or Directors listed in the table below is 9600 Great Hills Trail, Suite 150W, Austin, Texas 78759.

	Shares of Common Stock Beneficially Owned				Shares of Series B Preferred Stock Beneficially Owned		Total Voting Shares Beneficially Owned (2)
Name and Address of Beneficial Owner	Number		Percentage		Number	Percentage	Number	Percentage
Officers and Directors
Michael Carey		6,450,000 (1)		12.8%	500	50%	32,647,109 (2)	31.8%
Ryan Hudson		6,350,000 (3)		12.6%	500	50%	32,547,109 (2)	31.7%
(All of the Officers and Directors as a Group (2 persons))		12,800,000		25.6%	1,000	100%	64,876,769	63.5%
5% Shareholders
Mighty Falcon Ltd (4) Room 1004, Harvest Building 29-37 Wing Kut Street Central K3, Hong Kong		6,950,000		13.9%	-	-	6,950,000	6.8%
VP Bank (Switzerland) Ltd. (5) Bleicherweg 50, Zurich, Switzerland 8027		3,930,481(6)		7.6%	-	-	3,930,481	3.8%
Yaksha Industries Inc. (7) Hunkins Waterfront Plaza Main Street PO Box 556 Charlestown, Nevis, West Indies		4,051,173 (8)		7.8%	-	-	4,051,173	3.9%

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Percentage ownership in the table above is based on 50,339,543 shares of common stock issued and outstanding, 1,000 shares of Series B Preferred Stock issued and outstanding, which have the right to vote 52,394,218 voting shares (see Note 2), resulting in a total of 102,733,761 total voting shares outstanding as of April 14, 2013.

(1) Includes 5,000,000 shares of common stock held in the name of Carey Partners, Ltd., which entity and therefore which shares, are beneficially owned by Mr. Carey.

(2) The Series B Preferred Stock have the right, voting in aggregate, to vote on all shareholder matters (including, but not limited to at every meeting of the stockholders of the Company and upon any action taken by stockholders of the Company with or without a meeting) equal to fifty-one percent (51%) of the total vote, equal to 52,394,218 voting shares as of April 14, 2013.

(3) Includes 5,000,000 shares of common stock held in the name of CHITEX Family Limited Partnership, which entity and therefore which shares, are beneficially owned by Mr. Carey.

(4) Bill Cheung holds voting and dispositive power over the shares of Mighty Falcon Ltd.

(5) The information for VP Bank (Switzerland) Ltd. is based on the list of record holders maintained by our stock transfer agent.  Such shareholder has not filed a Schedule 13G with the SEC disclosing it has greater than five percent ownership of the Company’s common stock. The Company is not aware of the beneficial owner of the shares held by VP Bank (Switzerland) Ltd.

(6) Includes warrants to purchase 1,210,000 shares of the Company’s common stock at an exercise price of $1.00 per share.

(7) The information for Yaksha Industries Inc. is based on the list of record holders maintained by our stock transfer agent.  Such shareholder has not filed a Schedule 13G with the SEC disclosing it has greater than five percent ownership of the Company’s common stock. The Company is not aware of the beneficial owner of the shares held by Yaksha Industries Inc.

(8)  Includes warrants to purchase 1,590,000 shares of the Company’s common stock at an exercise price of $1.00 per share.

Changes in Control.   Our management is not aware of any arrangements which may result in “changes in control” as that term is defined by the provisions of Item 403(c) of Regulation S-K.

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

Related Party Transactions.

As part of the Merger Transaction, we also assumed two notes payable owed to an individual who is a shareholder.  The notes payable are unsecured and each has a face value of $25,000 with a fixed interest rate of 10.00% per annum.  The notes payable are due on demand and there is a total of $11,130 of accrued and unpaid interest owed as of December 31, 2010. Both of these notes were repaid in full on January 7, 2011.

As of December 31, 2012, the Company had a related party receivable in the amount of $13,196 due from two Companies with working interest amounts payable. This is a 51.31% (reduction) from an amount of $25,718 as of December 31, 2011.  Our directors are also officers in these two Companies.

Michael Carey, our Chief Executive Officer and President, and Ryan Hudson, our Chief Operating Officer and Secretary,  are members of 4 Phoenix Oil and Gas, LLC (“Phoenix”), which pays for fuel, meals, and other onsite location expenses, and field equipment to facilitate field activities. The Company reimburses Phoenix for such expenses and services on an ongoing basis.

Effective December 26, 2012, the Company issued 500 shares of its Series B Preferred Stock each to Mr. Carey and Mr. Hudson (1,000 shares of Series B Preferred Stock in aggregate), in consideration for services rendered to the Company as the Company’s Chief Executive Officer, President and Director, and Chief Operating Officer, Secretary and Director, respectively.

There have been no other related party transactions, or any other transactions or relationships required to be disclosed pursuant to Item 404 of Regulation S-K.

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Review, Approval and Ratification of Related Party Transactions

Given our small size and limited financial resources, we have not adopted formal policies and procedures for the review, approval or ratification of transactions, such as those described above, with our executive officers, directors and significant stockholders.  We intend to establish formal policies and procedures in the future, once we have sufficient resources and have appointed additional directors, so that such transactions will be subject to the review, approval or ratification of our Board of Directors, or an appropriate committee thereof.   On a moving forward basis, our directors will continue to approve any related party transaction.

Director Independence.   We do not have any independent directors.  

Item 14. Principal Accountant Fees and Services.

Audit Fees. The aggregate fees billed in the fiscal years ended December 31, 2012 and 2011 for professional services rendered by the principal accountant for the audit of our annual financial statements and quarterly review of the financial statements included in our Form 10-K or services that are normally provided by the accountant in connection with statutory and regulatory filings or engagements for those fiscal years was $77,000 and $91,000, respectively.

Tax Fees. For the fiscal years ended December 31, 2012 and 2011, our principal accountants did not render any services for tax compliance, tax advice, and tax planning work.

All Other Fees. None.

Pre-Approval Policies and Procedures. Prior to engaging our accountants to perform a particular service, our Board of Directors obtains an estimate for the service to be performed. All of the services described above were approved by the Board of Directors in accordance with its procedures.  

38

PART IV

Item 15.  Exhibits, Financial Statement Schedules.

(a) Documents filed as part of this report

(1) All financial statements

Index to Consolidated Financial Statements	Page
Report of Independent Registered Public Accounting Firm	F-2
Consolidated  Balance Sheets as of December 31, 2012 and 2011	F-3
Consolidated  Statements of  Operations for the years ended December 31, 2012 and 2011	F-4
Consolidated Statements of Stockholders’ Deficit for the years ended December 31, 2012 and 2011	F-5
Consolidated  Statements of Cash Flows for the years ended December 31, 2012 and 2011	F-6
Notes to Consolidated Financial Statements	F-8

(2) Financial Statement Schedules

All financial statement schedules have been omitted, since the required information is not applicable or is not present in amounts sufficient to require submission of the schedule, or because the information required is included in the consolidated financial statements and notes thereto included in this Form 10-K.

(3) Exhibits required by Item 601 of Regulation S-K

The information required by this Section (a)(3) of Item 15 is set forth on the exhibit index that follows the Signatures page of this Form 10-K.

39

SIGNATURES

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

	United American Petroleum Corp. a Nevada corporation
April 16, 2013	By:	/s/ Michael Carey
		Michael Carey
	Its:	Chief Executive Officer, Chief Financial Officer, President, Treasurer and a Director
		(Principal Executive, Financial and Accounting Officer)

In accordance with 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.

By:	/s/ Michael Carey	April 16, 2013
	Michael Carey
Its:	Chief Executive Officer, Chief Financial Officer, President, Treasurer and a Director

By:	/s/ Ryan Hudson	April 16, 2013
	Ryan Hudson
Its:	Chief Operating Officer, Secretary and a Director

40

EXHIBIT INDEX

Exhibit                    Description of Exhibit

2.1	Agreement and Plan of Exchange by and between Northern Future Energy Corp. and NFE Acquisition Corp., dated December 16, 2009 (incorporated by reference to Exhibit 2.1 of the Company’s Current Report on Form 8-K, filed February 7, 2008).
2.2	Asset Purchase Agreement by and between Enforce Global Solutions, LLC and the Company, dated as of December 29, 2009 (incorporated by reference to Exhibit 2.5 of the Company's Annual Report on Form 10-K, filed May 14, 2010).
2.3	Membership Interest Purchase Agreement by and between the Company and John Britchford-Steel, dated as of December 31, 2009 (incorporated by reference to Exhibit 2.6 of the Company's Annual Report on Form 10-K, filed May 14, 2010.
2.4	Agreement and Plan of Merger, by and among the Company, United American Petroleum Corp. and United PC Acquisition Corp., dated December 31, 2010. (1)
2.5	Agreement and Plan of Merger and Reorganization dated December 31, 2010, by and between the Company and United American Petroleum Corp. (1)
3.1	Amended and Restated Articles of Incorporation, as filed with the Secretary of State of the State of Nevada, effective January 31, 2008 (incorporated by reference to Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2012, filed November 14, 2012)
3.2	Certificate of Designations of Series B Preferred Stock (incorporated by reference as Exhibit 3.2 to the Company’s Current Report on Form 8-K, filed November 14, 2012)
3.3	Certificate of Withdrawal of Certificate of Designation of Series A Convertible Preferred Stock (incorporated by reference as Exhibit 3.2 to the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2012, filed November 14, 2012)
3.4	Bylaws (incorporated by reference to Exhibit 3(ii) of the Company’s Registration Statement on Form SB-2, filed on April 15, 2005).
3.5	Articles of Merger, as filed with the Secretary of State of the State of Nevada, effective December 16, 2009.
3.6	Certificate of Correction to Articles of Merger, as filed with the Secretary of State of the State of Nevada, effective January 29, 2010 (incorporated by reference to Exhibit 3.6 of the Company’s Annual Report on Form 10-K, as amended, filed January 21, 2011).
3.7	Articles of Merger between United PC Acquisition Corp. and United American Petroleum Corp.(1)
3.8	Articles of Merger between United American Petroleum Corp. and Forgehouse, Inc. (1)
10.1	2008 Incentive Plan (incorporated by reference to Exhibit B of the Company’s definitive Information Statement on Schedule 14-C, filed January 2, 2008).
10.2	Form of Note and Warrant Purchase Agreement. (1)
10.3	Form of Senior Secured Convertible Promissory Note. (1)
10.4	Form of Warrant. (1)
10.5	Form of Security Agreement.  (1)
10.6	Stock Cancellation Agreement by and among the Company and Christian Negri, dated as of December 31, 2010. (1)
10.7	Employment Agreement of Michael Carey. (1)
10.8	Employment Agreement of Ryan Hudson. (1)
10.9	Purchase Agreement by and between the Registrant and Patriot Minerals, LLC, dated January 28, 2011. (2)
10.10	Sale and Participation Agreements by and between the Registrant and Gabriel Rosser, LP, dated January 28, 2011. (2)
10.11	Form of Note and Warrant Purchase Agreement.  (3)
10.12	Form of Convertible Promissory Note.  (3)
10.13	Form of Warrant.  (3)
10.14	Purchase and Sale Agreement by and between the Registrant and Alamo Energy Corp. dated October 28, 2011.  (4)
10.15	Purchase and Sale Agreement by and between the Registrant and McKenzie Corp. dated November 30, 2011.  (5)
10.16	$400,000 Promissory Note – JMJ Financial (January 31, 2013)(incorporated by reference as Exhibit 10.1 to the Company’s Current Report on Form 8-K, filed with the Commission on March 7, 2013)
10.17	Securities Purchase Agreement – Asher Enterprises, Inc. (February 19, 2013) (incorporated by reference as Exhibit 10.2 to the Company’s Current Report on Form 8-K, filed with the Commission on March 7, 2013)
10.18	$103,500 Convertible Promissory Note – Asher Enterprises, Inc. (February 19, 2013) (incorporated by reference as Exhibit 10.3 to the Company’s Current Report on Form 8-K, filed with the Commission on March 7, 2013)
21	List of Subsidiaries (6)
23.1	Consent of Mire and Associates, Inc. (6)
31.1	Certification of Principal Executive and Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.   (6)
32.1		Certification of Principal Executive and Financial Officer pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.   (7)
99.1		Reserve Reports of Properties located in Duval, Erath, Frio, Gonzales, Medina, Navarro, Pecos, Shackelford, and Wilbarger Counties, Texas (6)
101.INS		XBRL Instance Document (#)
101.SCH		XBRL Taxonomy Schema (#)
101.CAL		XBRL Taxonomy Calculation Linkbase (#)
101.DEF		XBRL Taxonomy Definition Linkbase (#)
101.LAB		XBRL Taxonomy Label Linkbase (#)
101.PRE		XBRL Taxonomy Presentation Linkbase (#)

(1)  Incorporated by reference to the Registrant's Current Report on Form 8-K filed on January 5, 2011.

(2)  Incorporated by reference to the Registrant's Current Report on Form 8-K filed on February 3, 2011.

(3)  Incorporated by reference to the Registrant's Current Report on Form 8-K filed on October 18, 2011.      

(4)  Incorporated by reference to the Registrant's Current Report on Form 8-K filed on November 8, 2011.

(5)  Incorporated by reference to the Registrant's Current Report on Form 8-K filed on December 5, 2011.

(6)  Filed herewith.  

(7) Furnished herewith.

 (#) XBRL (Extensible Business Reporting Language) information is furnished and not filed or a part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise is not subject to liability under these sections..

41

EX-21

Exhibit 21

List of Subsidiaries

Northern Future Energy Corp., a Nevada corporation.

United Operating, LLC., a Texas limited liability company.

UAP Management, LLC.,   a Texas limited liability company.

EX-23.3

Exhibit 23.1

1927 Hillgreen Drive Katy, TX 77494 Tel: 713-882-9598 www.mireandassociates.com

April 16, 2013

ATTN: Mr. Michael Carey

SUBJECT:  UNITED AMERICAN PETROLEUM CORPORATION

                     INDEPENDENT CONSULTANT CONSENT

Mire & Associates, Inc. hereby consents to the use of its name and information from its report dated March 26, 2013, generating estimated reserves and future net revenues for United American Petroleum Corporation for the year ended December 31, 2012.   This information may be used and a copy of the report may be included in United American Petroleum Corporation’s Form 10-K Annual Report for the year ended December 31, 2012.

Sincerely,

/s/ Kutt Mire
Kurt Mire

Petroleum Consultant

EX-31.1

Exhibit 31.1

Certification of Principal Executive and Financial Officer,

Required By Rule 13a-14(A) of the Securities Exchange Act of 1934, As Amended,

As Adopted Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002

I, Michael Carey, certify that:

1. I have reviewed this annual report on Form 10-K of United American Petroleum Corp.;

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

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

4.  I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

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

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

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

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

5. I have disclosed, based on my most recent evaluation of internal control over financial reporting , to the registrant’s auditors and the audit committee of the registrant’s Board of Directors (or persons performing the equivalent functions):

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

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

Date: April 16, 2013

/s/ Michael Carey

Michael Carey

Chief Executive Officer and Chief Financial Officer, (Principal Executive and Financial Officer)

EX-32.1

Exhibit 32.1

Certification of Principal Executive and Financial Officer

Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to

Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Annual Report of United American Petroleum Corp., a Nevada corporation (the “Company”) on Form 10-K for the year ending December 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Michael Carey, Chief Executive Officer, Chief Financial Officer, President, Treasurer and a director of the Company, certifies to the best of his knowledge, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

A signed original of this written statement required by Section 906 has been provided to United American Petroleum Corp., and will be retained by United American Petroleum Corp. and furnished to the Securities and Exchange Commission or its staff upon request.

/s/ Michael Carey

Michael Carey

Chief Executive Officer and Chief Financial Officer,

(Principal Executive Officer and Principal Financial Officer)

April 16, 2013

EX-99.3

EXHIBIT 99.1

          1927 Hillgreen Drive Katy, TX 77494 Tel:  713-882-9598 www.mireandassociates.com

March 26, 2013

United American Petroleum Corporation

9600 Great Hills Trail, Suite 150W

Austin, TX 78759

ATTN:  Mr. Michael Carey

SUBJECT:  2012 Year End Reserves

Mr. Carey,

Mire and Associates, Inc. (MAI) has updated the proved reserves as of January 1, 2013 for oil and gas properties owned by United American Petroleum Corporation (UAPC).  These properties are located in nine (9) Texas counties.  Reserves and cash flows were generated for the UAPC interests using SEC pricing ($2.85 / MMBTU and $94.71 / barrel).  These estimates were done as per the Securities and Exchange Commission’s standards as described in the December 2008 amendment of Section 210.4-10 of Regulation S – X. This report is provided to United American Petroleum Corporation to satisfy the requirements contained in Item 1202(a)(8) of U.S. Securities and Exchange Commission Regulation S-K.

As of January 1, 2013 we estimate the UAPC net proved reserves to about 68,270 barrels of oil (68.27 MBO) and 29,360 thousand cubic feet of gas (29.36 MMCF).  Projected future cash flows show a discounted net present value (NPV10%) of $1,344,510.

DISCUSSION

UAPC has ownership interest in twenty five (25) oil & gas leases with about ninety seven (97) producing wells.  UAPC is the operator of seven (7) of the leases and eighteen (18) of the producing wells.   The properties are located in Duval, Erath, Frio, Gonzales, Medina, Navarro, Pecos, Shackelford, and Wilbarger Counties.  At the end of 2012 total gross production was about fifty seven (57) barrels of oil per day.

1

UAPC 2012 Year End Reserves Page 2

METHOD OF APPRAISAL

The purpose of this report is to estimate proved oil and gas reserves for United American Petroleum Corporation using industry standard assumptions and methods.  Significant data was collected and examined using volumetric calculations and decline curve analysis.  Offset production, logs, maps, analog information and accounting statements were all studied.

The properties have been evaluated on the basis of future net cash flow or income.  This income will accrue to the appraised interest as the wells are produced to their economic limits.  The future net income has also been shown discounted at ten (10%) percent to determine its present worth as required by Regulation S - X.

ECONOMIC ASSUMPTIONS

For the cash flow analysis an oil price of $94.71 per barrel and a gas price of $2.85 per MMBtu were used as per SEC pricing guidelines for 2012.  Local field price differentials were applied.  This price was held constant (no escalations).

Operating expense data were supplied by UAPC.  MAI analyzed these expenses and average values were included in our cash flows. These expenses were held constant through the life of the properties (no escalations). Lease restoration and well abandonment costs are not included in our analysis as the equipment salvage value should cover these costs.

RESERVE DETERMINATION

Reserves were estimated for the wells by using engineering and geologic methods widely accepted in the industry.  For the producing reservoirs, performance methods were used to estimate reserves.  Extrapolations were made of various historical data including oil, gas and water production and pressure data.

Titles to the evaluated property have not been examined or independently confirmed.  The data used in this evaluation was supplied by United American Petroleum Corporation or was obtained from public sources.

Mire & Associates, Inc. have made use of all data, appropriate methods, and procedures that are needed to prepare this report according to SEC regulation S-X Section 210.4-10 as amended on December 2008.

2

UAPC 2012 Year End Reserves Page 3

All estimates are a function of the quality of the available data and are subject to the existing economic conditions, operating methods, and government regulations in effect at the time of the report.  The reserves presented in this report are estimates only and should not be interpreted as being exact amounts.  Actual volumes recovered could be higher or lower than estimated.

Not only are such reserves and revenue estimates based on that information which is currently available, but such estimates are also subject to the uncertainties inherent in the application of judgmental factors in interpreting such information.

New regulations could have an adverse effect on the reserves calculated in this report.  Importantly changes to regulations on water disposal or well re-injection could significantly decrease or eliminate this report’s proved reserves.

Kurt Mire supervised or performed all of the relevant technical work during the creation of this report.  He is a petroleum consultant and officer of Mire & Associates, Inc., a Texas company.   Kurt Mire has a B.S. degree in Petroleum Engineering from the University of Louisiana at Lafayette.  He has 28 years of experience in creating reserve reports and completing reserve analysis for conventional and unconventional fields in the United States.

In my opinion the reserve estimates presented in this report are reasonable and were made with generally accepted engineering and evaluation principles.

The Economic Summary Projection and Economic One-Liners tables are attached.

Thanks for letting us help with this.

Sincerely,

 /s/ Kurt Mire

Kurt Mire

Petroleum Consultant

3

								ECONOMIC SUMMARY PROJECTION																				Total
Partner :		All Cases
									UNITED AMERICAN PETROLEUM CORP
												All Cases
												Discount Rate :			10.00
												As of :		01/01/2013
Est. Cum Oil (Mbbl) :			10,798.75						2012 YE Reserves
Est. Cum Gas (MMcf) :			285.43						SEC Prices $94.71/BBL & 2.85/MMBTU
Est. Cum Water (Mbbl) :			1,617.41
Year		Oil Gross (Mbbl)		Gas Gross (MMcf)		Oil Net (Mbbl)			Gas Net (MMcf)			Oil Price ($/bbl)		Gas Price ($/Mcf)		Oil & Gas Rev. Net (M$)		Misc. Rev. Net (M$)		Costs Net (M$)		Taxes Net (M$)		Invest. Net (M$)		NonDisc. CF Annual (M$)		Cum Disc. CF (M$)
2013			25.58		65.29		4.46			3.70			86.18		2.56		393.80		0.00		148.57		28.23		60.45		156.55		148.45
2014			30.12		78.94		4.98			4.47			85.97		2.56		439.25		0.00		165.86		31.52		0.00		241.87		358.34
2015			28.01		61.51		4.66			3.49			85.93		2.56		409.03		0.00		160.40		29.30		0.00		219.33		531.35
2016			25.45		52.31		4.24			2.97			85.88		2.56		371.50		0.00		142.91		26.60		0.00		201.99		676.19
2017			23.68		46.11		4.00			2.61			85.80		2.56		349.62		0.00		139.65		25.02		0.00		184.95		796.73
2018			22.55		41.46		3.82			2.35			85.78		2.56		333.61		0.00		139.65		23.86		0.00		170.09		897.52
2019			21.49		37.31		3.65			2.12			85.77		2.56		318.48		0.00		139.65		22.77		0.00		156.05		981.59
2020			20.55		33.67		3.50			1.91			85.76		2.56		304.93		0.00		139.65		21.79		0.00		143.48		1,051.86
2021			19.56		30.22		3.34			1.71			85.75		2.56		290.43		0.00		139.65		20.75		0.00		130.03		1,109.75
2022			18.67		27.20		3.19			1.54			85.74		2.56		277.46		0.00		139.65		19.81		0.00		117.99		1,157.50
2023			17.74		17.62		3.05			1.01			85.72		2.56		263.73		0.00		138.34		18.80		0.00		106.59		1,196.72
2024			16.93		10.46		2.92			0.61			85.70		2.56		251.69		0.00		137.26		17.92		0.00		96.52		1,229.01
2025			16.14		9.39		2.78			0.55			85.70		2.56		240.05		0.00		137.26		17.08		0.00		85.71		1,255.08
2026			15.11		5.41		2.65			0.32			85.65		2.56		227.58		0.00		135.31		16.18		0.00		76.09		1,276.11
2027			13.90		0.00		2.50			0.00			85.57		0.00		214.32		0.00		132.02		15.22		0.00		67.09		1,292.97
Rem.			138.03		0.00		14.55			0.00			87.78		0.00		1,276.89		0.00		862.32		90.66		0.00		323.91		51.54
Total	38.92		453.49		516.90		68.27			29.36			86.24		2.56		5,962.35		0.00		2,998.16		425.51		60.45		2,478.23		1,344.51
Ult.			11,252.25		802.33
												Eco. Indicators
											Return on Investment (disc) :				24.256				Present Worth Profile (M$)
											Return on Investment (undisc) :				41.999			PW		5.00% :			1,756.02	PW		20.00% :			908.06
											Years to Payout :				0.32			PW		8.00% :			1,485.03	PW		30.00% :			685.92
											Internal Rate of Return(%) :			>1000				PW		10.00% :			1,344.51	PW		40.00% :			553.28
																		PW		12.00% :			1,227.39	PW		50.00% :			465.62
																		PW		15.00% :			1,084.71	PW		60.00% :			403.55
TRC Eco One Liner.rpt

4

		Economic One-Liners
Project Name :	UNITED AMERICAN PETROLEUM CORP
								As of Date:			1/1/2013
Ownership Group :	All Cases							2012 YE Reserves
						SEC Prices $94.71/BBL & 2.85/MMBTU
		Net Reserves				Net Revenue								Expense & Tax (M$)				Cash Flow
Lease Name  Risked / UnRisked	Reserve Category	Oil (Mbbl)		Gas (MMcf)		Oil (M$)			Gas (M$)			Other (M$)				Invest. (M$)		Non-Disc. (M$)		Disc. CF (M$)		Life (years)
Grand Total	Total		68.27		29.36		5,887.06			75.29			0.00		3,423.67		60.45		2,478.23		1,344.51		38.92
Proved Rsv Class	Total		68.27		29.36		5,887.06			75.29			0.00		3,423.67		60.45		2,478.23		1,344.51		38.92
Proved Rsv Class
Producing Rsv Category	Total		61.18		29.36		5,300.52			75.29			0.00		3,116.54		60.45		2,198.82		1,182.01		38.92
Non-Producing Rsv Category	Total		7.08		0.00		586.54			0.00			0.00		307.13		0.00		279.41		162.50		15.55
Shut-In Rsv Category	Total		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
DUVAL County	Total		5.79		0.00		541.59			0.00			0.00		201.41		18.85		321.33		131.94		38.92
WELDER STATE	P-DP		0.48		0.00		44.46			0.00			0.00		10.26		0.00		34.20		18.00		16.71
WELDER, J. F., HRS. -320-	P-DP		1.42		0.00		132.37			0.00			0.00		32.91		10.37		89.08		31.58		34.03
WELDER, J. F., HRS. -B-	P-DP		1.01		0.00		94.73			0.00			0.00		35.51		3.78		55.45		22.05		33.67
WELDER, J.F., HEIRS 'C'	P-DP		2.89		0.00		270.04			0.00			0.00		122.73		4.70		142.60		60.32		38.92
ERATH County	Total		0.24		29.36		22.98			75.29			0.00		50.41		16.30		31.56		20.00		13.63
CROUCH 1H	P-DP		0.18		14.04		16.67			35.99			0.00		28.80		8.98		14.87		9.70		10.45
LANE-HEADY 1	P-DP		0.07		15.33		6.31			39.30			0.00		21.61		7.32		16.69		10.30		13.63
WILSON R P 1H	P-SI		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
FRIO County
LOZANO HECTOR C	P-DP		21.42		0.00		1,963.85			0.00			0.00		1,169.52		0.00		794.33		442.47		24.53
GONZALES County
MARCEE 1	P-NP		7.08		0.00		586.54			0.00			0.00		307.13		0.00		279.41		162.50		15.55
MEDINA County	Total		7.85		0.00		661.71			0.00			0.00		473.36		0.00		188.35		110.25		22.05
BAILEY, JAMES & REGINA	P-DP		1.70		0.00		143.07			0.00			0.00		85.42		0.00		57.65		27.44		22.05
FOHN, E. L. -A-	P-DP		0.32		0.00		26.56			0.00			0.00		25.66		0.00		0.91		0.83		2.62
FOHN, EDWARD UNIT II	P-DP		0.33		0.00		28.08			0.00			0.00		27.37		0.00		0.71		0.64		2.80
ROGERS -B-	P-DP		5.50		0.00		464.00			0.00			0.00		334.92		0.00		129.08		81.34		17.70
ROGERS, C. C. UNIT -1-	P-DP		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
BAILEY, JAMES & REGINA SR.	P-SI		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
FOHN, ELMER -B-	P-SI		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
ROGERS, C.C. JR.	P-SI		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
ROGERS, C.C. UNIT -2-	P-SI		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
NAVARRO County
MCKINNEY	P-DP		1.07		0.00		98.66			0.00			0.00		60.03		0.00		38.63		28.06		13.64
PECOS County
MCKENZIE J F -STATE 1	P-DP		16.72		0.00		1,298.86			0.00			0.00		866.28		0.00		432.58		261.96		19.85
SHCKLFRD County	Total		6.48		0.00		564.50			0.00			0.00		207.47		19.03		338.00		150.86		37.42
DAVIS MERRICK	P-DP		4.50		0.00		395.28			0.00			0.00		154.83		14.50		225.94		99.34		36.43
DAVIS, MERRICK [A16 & B17]	P-DP		1.97		0.00		169.23			0.00			0.00		52.64		4.52		112.06		51.51		37.42
WILBARGER County	Total		1.61		0.00		148.36			0.00			0.00		88.06		6.27		54.03		36.48		15.15
WALKER SMITH	P-DP		0.33		0.00		30.46			0.00			0.00		29.44		0.00		1.03		0.92		3.41
WALKER-SMITH 21D	P-DP		1.28		0.00		117.90			0.00			0.00		58.63		6.27		53.00		35.56		15.15
WALKER SMITH B 22D	P-SI		0.00		0.00		0.00			0.00			0.00		0.00		0.00		0.00		0.00		0.00
TRC Eco One Liner.rpt																					1

5

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Detachable Warrants (Details 1)	Dec. 31, 2012
Detachable Warrants Details 1
Warrants	2,800,000
Reserved shares at September 30, 2012	2,800,000

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Supplemental Oil and Gas Activities (Details 1) (USD $)	0 Months Ended	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2012	Dec. 31, 2011
Extractive Industries [Abstract]
Future cash flows	$ 231,430	$ 5,962,350	$ 3,278,186
Future production and development costs	(90,258)	(3,484,120)	(1,377,560)
Future income taxes
Future net cash flows before discount	141,172	2,478,230	1,900,626
10% discount to percent value	(61,484)	(1,133,720)	(769,576)
Standardized measure of discounted future net cash flows	$ 79,688	$ 1,344,510	$ 1,131,050

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Asset Retirement Obligation (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligation Details
Beginning of the period	$ 56,012	$ 15,465
Liabilities incurred	9,790	37,955
Accretion expense	3,514	2,592
Balance at end of the period	$ 69,316	$ 56,012

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Supplemental Oil and Gas Activities (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Supplemental Oil And Gas Activities Details 2
Standardized measure of discounted future net cash flows beginning of period	$ 1,131,050	$ 79,668
Purchases of reserves in place		1,064,368
Extension and discoveries, net of future production and development costs	112,227		89,901
Sales of oil and gas produced, net of production costs	(111,914)	(31,497)	(10,213)
Extension and discoveries, net of future production and development costs	113,105	7,969
Revisions of previous quantity estimates	1,465,199	(68,859)
Net change in prices and production costs	(1,186,254)	26,611
Net change in income taxes
Changes in timing and other	(178,903)	52,770
Standardized measure of discounted future net cash flows end of period	$ 1,344,510	$ 1,131,050	$ 79,668

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Convertible Note Payable (Details Narrative) (USD $)	12 Months Ended			12 Months Ended							0 Months Ended			12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012 Convertible Note - 1st Installment	Dec. 31, 2012 Convertible Note - 2nd Installment	Dec. 31, 2012 Convertible Note - 3rd Installment	Dec. 31, 2012 Convertible Note - 4th Installment	Dec. 31, 2012 Convertible Note - 5th Installment	Dec. 31, 2012 Convertible Note - 6th Installment	Dec. 31, 2012 Convertible Note - Total	Jun. 11, 2012 Credit Facility - Senior Secured Convertible Promissory Note	Jun. 01, 2012 Credit Facility - Senior Secured Convertible Promissory Note	Apr. 13, 2012 Credit Facility - Senior Secured Convertible Promissory Note	Dec. 31, 2012 Credit Facility - Senior Secured Convertible Promissory Note
Installment amounts				$ 400,000	$ 550,000	$ 25,000	$ 150,000	$ 250,000	$ 215,000	$ 1,500,000
Date of issuance				Oct. 14, 2011	Nov. 29, 2011	Dec. 19, 2011	Feb. 10, 2012	Mar. 30, 2012	Jun. 04, 2012	Oct. 14, 2011				Dec. 31, 2010
Maturity Date										Oct. 14, 2014				Dec. 31, 2013
Interest rate										10.00%				10.00%
Number of warrants issued with installment	2,800,000	2,185,000	2,185,000	400,000	550,000	25,000	150,000	250,000	430,000
Exercise price of warrants	1.00									1.00				1.00
Conversion price										$ 0.50				$ 0.50
Amortization of debt discount	2,176,996	168,935								2,155,448
Stock issued upon conversion of convertible debt, (shares)	6,034,542									3,314,062	300,481	1,180,000	1,240,000
Stock issued upon conversion of convertible debt										1,590,000	150,240	590,000	620,000
Borrowing capacity														$ 2,250,000

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Summary of Significant Accounting Policies (Details Narrative)	12 Months Ended
	Dec. 31, 2012
Furniture and Fixtures
Depreciation period	5 years
Automobiles
Depreciation period	5 years
Equipment
Depreciation period	10 years

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Subsequent Events (Details narrative) (USD $)	3 Months Ended
	Mar. 31, 2013
Funds solicited from working interest partners to cover workover costs	$ 114,000
Convertible Note Payable #1
Funding from external sources	100,000
Convertible Note Payable #2
Funding from external sources	$ 50,000

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Subsequent Events

12 Months Ended

Dec. 31, 2012

Subsequent Events [Abstract]

Subsequent Events

19.             Subsequent Events

During the three month period ended March 31, 2013, the Company secured certain funding from external sources including two convertible notes payable in the amount of $100,000 and $50,000.

The Company solicited $114,000 of funds from working interest partners to cover non-consenting working interest partners portions of workover costs on the Merrick Davis, Crouch and Lane Heady properties.  As of the date of this report, the Company has completed workovers on these properties and is awaiting production results.

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Share Based Compensation (Details Narrative) (Stock Compensation, USD $)	12 Months Ended
	Dec. 31, 2012
Employee
Shares granted as share based compensation	80,000
Market price of shares issued	$ 0.10
Advisor
Shares granted as share based compensation	125,000
Market price of shares issued	$ 0.10
Independent Investor Relations Advisor
Shares granted as share based compensation	100,000
Market price of shares issued	$ 0.10

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Fair Value (Details 1) (USD $)	0 Months Ended								3 Months Ended	5 Months Ended	12 Months Ended
	Feb. 10, 2012	Dec. 19, 2011	Nov. 29, 2011	Oct. 14, 2011	Jun. 30, 2011	Jun. 20, 2011	Mar. 09, 2011	Jan. 20, 2011	Mar. 30, 2012	Jun. 04, 2012	Dec. 31, 2012	Dec. 31, 2011
Fair Value Details 1
Beginning balance									$ 1,138,989	$ 1,138,989	$ 1,138,989	$ 116,905
Initial recognition of debt derivative from issuance of convertible notes	189,052	29,690	655,150	504,896	142,246	95,155	376,698	333,652	514,784	325,831
decrease in fair value of debt derivative											2,325,015	(1,115,403)
Other											1,017
Total debt derivative preceding conversion											4,494,688
Reduction of debt derivative from conversion											(4,494,688)
Ending Balance											$ 0	$ 1,138,989

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Detachable Warrants (Details Narrative) (USD $)	0 Months Ended												2 Months Ended
	Jun. 04, 2012	Apr. 13, 2012	Mar. 30, 2012	Feb. 10, 2012	Dec. 19, 2011	Nov. 29, 2011	Oct. 14, 2011	Jun. 30, 2011	Jun. 20, 2011	Mar. 09, 2011	Jan. 20, 2011	Dec. 31, 2010	Jun. 01, 2012	Jun. 07, 2012
Detachable Warrants Details Narrative
Warrants Not Settleable in Cash, Fair Value Disclosure (in Dollars)	$ 97,313		$ 130,853	$ 61,354	$ 13,788	$ 209,317	$ 157,388	$ 45,233	$ 29,276	$ 106,132	$ 78,062	$ 45,434
Fair Value Assumptions, Expected Dividend Rate	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%
Fair Value Assumptions, Expected Volatility Rate	112.94%	108.17%	110.64%	110.77%	109.32%	109.19%	108.61%	107.39%	105.87%	105.22%	104.65%	94.10%	111.24%	102.93%
Fair Value Assumptions, Risk Free Interest Rate	0.27%	0.27%	1.04%	1.04%	0.82%	0.93%	1.12%	1.76%	1.55%	2.16%	2.06%	2.01%	0.25%	0.27%
Fair Value Assumptions, Expected Term	4 years 8 months	1 year 262 days	5 years	5 years	5 years	5 years	5 years	5 years	5 years	5 years	5 years	5 years	1 year 211 days	2 years 127 days

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Supplemental Oil and Gas Activities (Details Narrative)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2012 Six Texas Counties Mcf Boe	Dec. 31, 2011 Frio County, Texas Mcf Boe	Dec. 31, 2012 Crude Oil and NGL	Dec. 31, 2012 Natural Gas, Per Thousand Cubic Feet
Probability that quantities actually recovered will equal or exceed estimate	90.00%
Prices used for standardized measue of future cash flows				2.85	94.71
Discount rate	10.00%
Production, barrels		5,823	1,310
Production, mcf		1,404	542

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Convertible Note Payable (Details) (USD $)	0 Months Ended	3 Months Ended	5 Months Ended	12 Months Ended
	Feb. 10, 2012	Mar. 30, 2012	Jun. 04, 2012	Dec. 31, 2012
Convertible Note Payable Details
Total Proceeds	$ 150,000	$ 250,000	$ 215,000	$ 615,000
Conversion Option Liability	189,052	514,783	325,831	1,029,666
Relative Fair Value of Warrants	61,354	130,853	97,313	289,520
Total Fair Value of Derivative	250,406	645,636	423,144	1,319,186
Debt Discount	(150,000)	(250,000)	(215,000)	(615,000)
Loss on debt derivative	$ 100,406	$ 395,636	$ 208,144	$ 704,186

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Going Concern

12 Months Ended

Dec. 31, 2012

Going Concern

Going Concern

3.           Going Concern

The Company has incurred a net loss and negative operating cash flows since inception through December 31, 2012. These factors raise substantial doubt about the Company's ability to continue as a going concern. The Company's management is implementing plans to sustain the Company’s cash flow from operating activities and/or acquire additional capital funding. The consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

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Oil and Gas Properties (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011 Patriot Minerals, LLC	Dec. 31, 2011 Gabriel Rosser LP	Dec. 31, 2011 Alamo Energy Corp. acre	Dec. 31, 2011 McKenzie Oil Corp.	Dec. 31, 2012 McKenzie Property	Dec. 31, 2012 Marcee Property	Dec. 31, 2012 Gabriel Rosser Property
Drilling and completion procedure						$ 27,225	$ 44,792	$ 1,770,002
Date of the agreement		Jan. 28, 2011	Jan. 28, 2011	Nov. 04, 2011	Nov. 30, 2011
Purchase of working interest (percent)	28.00%		50.83%	75.00%	100.00%
Purchase of revenue interest to certain existing wells and to certain leases (percent)	26.00%		39.131%
Payment to consultant		5,000
Consideration paid			10	160,000	550,000
Liabilities assumed			84,795
Number of gross acres oil and gas leases				110
Number of shares issued in acquisition					50,000
Value of producing well purchased					$ 80,655

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Fair Value (Tables)

12 Months Ended

Dec. 31, 2012

Fair Value Tables

Schedule of consolidated financial assets and liabilities measured at fair value by level within the fair value hierarchy

	Total		Level 1		Level 2		Level 3
LIABILITIES:
2012- Conversion option liability	-		-		-		-
2011- Conversion option liability		-		-		-		1,138,989

Reconciliation of the conversion option liability and detachable warrant liability for Level 3 inputs

The following is a reconciliation of the conversion option liability and detachable warrant liability for which Level 3 inputs were used in determining fair value: 

Beginning balance January 1, 2011	$	116,905
Initial recognition of debt derivative from issuance of     January 20, 2011, $150,000 convertible note		333,652
Initial recognition of debt derivative from issuance of     March 9, 2011, $250,000 convertible note		376,698
Initial recognition of debt derivative from issuance of     June 20, 2011, $75,000 convertible note		95,155
Initial recognition of debt derivative from issuance of     June 30, 2011, $115,000 convertible note		142,246
Initial recognition of debt derivative from issuance of    October 14, 2011, $400,000 convertible note		504,896
Initial recognition of debt derivative from issuance of     November 29, 2011, $550,000 convertible note		655,150
Initial recognition of debt derivative from issuance of     December 19, 2011, $25,000 convertible note		29,690
Decrease in fair value of debt derivative		(1,115,403	)
Ending balance as of December  31, 2011	$	1,138,989
Initial recognition of debt derivative from issuance of     February 10, 2012, $150,000 convertible note		189,052
Initial recognition of debt derivative from issuance of     March 30, 2012, $250,000 convertible note		514,784
Initial recognition of debt derivative from issuance of    June 4, 2012, $215,000 convertible note		325,831
Mark to market of debt derivative		2,325,015
Other		1,017
Total debt derivative preceding conversion		4,494,688
Reduction of debt derivative from conversion		(4,494,688	)
Debt derivative as of December 31, 2012	$	-

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Detachable Warrants (Tables)

12 Months Ended

Dec. 31, 2012

Detachable Warrants Tables

Schedule of warrant activitiy

A summary of warrant activity for the period from December 31, 2011 through December 31, 2012 is presented below:

	Number of Warrants		Weighted Average Exercise Price		Weighted Average Remaining Contract Term
Outstanding December 31, 2011		2,185,000	$	1.00	3.45 years
Issued		615,000	$	1.00	4.17years
Exercised		-		-	-
Outstanding December  31, 2012		2,800,000	$	1.00	3.61 years
Exercisable, December  31, 2012		2,800,000	$	1.00	3.61 years

Schedule of reserved shares for future issuance

The Company has reserved shares for future issuance upon of its warrants as follows:

Warrants	2,800,000
Reserved shares at December  31, 2012	2,800,000

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Supplemental Oil and Gas Activities (Details 3)	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Number of oil wells, gross	88	88	3
Number of oil wells, net	11	11	11
Number of gas wells, gross	1	1
Number of gas wells, net	1	1
Crude Oil
Developed acreage, gross	1,553	1,553	110
Developed acreage, net	480	480	83
Undeveloped acreage, gross	1,572	1,572	453
Undeveloped acreage, net	344	344	91
Natural Gas
Developed acreage, gross	325	325
Developed acreage, net	149	149
Undeveloped acreage, gross	557	557
Undeveloped acreage, net	29	29

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Note Payable Related Party (Details Narrative) (Shareholder Notes Payable, USD $)	Dec. 31, 2010
Shareholder Notes Payable
Face Value	$ 25,000
Interest rate	10.00%

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Convertible Note Payable (Tables)

12 Months Ended

Dec. 31, 2012

Convertible Note Payable Tables

Schedule of fair value of the warrants and the remainder to the fair value of the embedded derivative on the grant date

	February 10, 2012			March 30, 2012			June 4, 2012			Total
Total Proceeds	$	150,000		$	250,000		$	215,000		$	615,000
Allocated to:
Conversion Option Liability		189,052			514,783			325,831			1,029,666
Relative Fair Value of Warrants		61,354			130,853			97,313			289,520
Total Fair Value of Derivative		250,406			645,636			423,144			1,319,186
Debt Discount		(150,000	)		(250,000	)		(215,000	)		(615,000	)
Loss on debt derivative	$	100,406		$	395,636		$	208,144		$	704,186

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Asset Retirement Obligation (Tables)

12 Months Ended

Dec. 31, 2012

Asset Retirement Obligation Disclosure [Abstract]

Schedule of asset retirement obligation

	Year ended December 31, 2012		Year ended December 31, 2011
Beginning of the period	$	56,012	$	15,465
Liabilities incurred		9,790		37,955
Accretion expense		3,514		2,592
Balance at end of the period	$	69,316	$	56,012

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2012

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

2.           Summary of Significant Accounting Policies

Concentration of Credit Risk

The Company collects its receivables on its working interests in oil and gas properties from well operators. As such, the Company generally has relatively few customers. These receivables are unsecured and the Company performs ongoing credit evaluations of the well operators’ financial condition whenever necessary. Bad debt is recognized on an account-by-account review after all means of collection have been exhausted and recovery is not probable. There has been no bad debt expense for the period ended December 31, 2012 and 2011, respectively.

Revenue Recognition- Oil and Gas

The Company recognizes oil and gas revenue from interests in producing wells using the “sales method.” Under this method of accounting, revenues are recognized based on volumes sold, which may differ from the volume to which we are entitled based on our working interest. An imbalance is recognized as a liability only when the estimated remaining reserves will not be sufficient to enable the under–produced owner(s) to recoup its entitled share through future production. Under the sales method, no receivables are recorded where we have taken less than our share of production. Our net imbalance position at December 31, 2012 and December 31, 2011, was immaterial.

Revenue Recognition – Well Operator Income

The Company will record revenue for well operator income only on properties for which the Company has no ownership in accordance with ASC 605.

For properties in which the Company has ownership, well operator income amounts may be recorded as reductions of the costs incurred, to the extent of identifiable and specific costs of the specific services for which the Company has been reimbursed. No income in excess of those specific costs was recorded and the Company recorded no offset to the full cost pool.

Oil and Gas Properties

The Company follows the full cost method of accounting for its investments in oil and gas properties. Under the full cost method, all costs associated with the exploration of properties are capitalized into appropriate cost centers within the full cost pool. Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities. Cost centers are established on a country-by-country basis.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

For each cost center, capitalized costs are subject to an annual ceiling test, in which the costs shall not exceed the cost center ceiling. The cost center ceiling is equal to i) the present value of estimated future net revenues computed by applying current prices of oil and gas reserves (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; plus ii) the cost of properties not being amortized; plus iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; less iv) income tax effects related to differences between the book and tax basis of the properties. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs.

Asset Retirement Obligations

ASC 410, Asset Retirement and Environmental Obligations addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. Specifically, ASC 410 requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. In addition, the asset retirement cost is capitalized as part of the asset’s carrying value and subsequently allocated to expense over the asset’s useful life.

Fair Value of Financial Instruments

Unless otherwise indicated, the fair value of all reported assets and liabilities which represent financial instruments approximate the carrying values of such instruments due to their short-term maturity.

Recoverability of Long-Lived Assets

The Company has adopted Accounting Standards Codification subtopic 360-10, Property, Plant and Equipment (“ASC 360-10”). ASC 360-10 requires that long-lived assets and certain identifiable intangibles held and used by the Company be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

Events relating to recoverability may include significant unfavorable changes in business conditions or a forecasted inability to achieve break-even operating results over an extended period. The Company evaluates the recoverability of long-lived assets based upon forecasted undiscounted cash flows. Should impairment in value be indicated, the carrying value of intangible assets would be adjusted, based on estimates of future discounted cash flows resulting from the use and ultimate disposition of the asset. ASC 360-10 also requires assets to be disposed of be reported at the lower of the carrying amount or the fair value less costs to sell.

Share-Based Compensation

The Company accounts for share-based compensation in accordance with Accounting Standards Codification subtopic 718-10, Stock Compensation (“ASC 718-10”). This requires the measurement and recognition of compensation expense for all share-based payment awards made to employees and directors, including employee stock options and employee stock purchases related to an Employee Stock Purchase Plan based on the estimated fair values.

As of December 31, 2012, there were no outstanding employee stock options.

Income Taxes

The Company has adopted Accounting Standards Codification subtopic 740-10, Income Taxes (“ASC 740-10”). ASC 740-10 requires the recognition of deferred tax liabilities and assets for the expected future tax consequences of events that have been included in the financial statement or tax returns. Under this method, deferred tax liabilities and assets are determined based on the difference between financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. Valuation allowances are established, when necessary, to reduce deferred tax assets to amounts that are expected to be realized.

Basic and Diluted Earnings (Loss) Per Share

Basic earnings (loss) per common share is computed by dividing net income (loss) available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per common share is computed in the same way as basic earnings (loss) per common share except that the denominator is increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued and if the additional common shares were dilutive.

Property and Equipment

Property and equipment is recorded at cost and depreciated over the estimated useful lives of the assets using principally the straight-line method. When items are retired or otherwise disposed of, income is charged or credited for the difference between net book value and proceeds realized. Ordinary maintenance and repairs are charged to expense as incurred, and replacements and betterments are capitalized.

The range of estimated useful lives used to calculated depreciation for principal items of property and equipment are as follow:

Asset Category	Depreciation Period
Furniture and Fixtures	5 Years
Automobiles	5 Years
Equipment	10 Years

Recent Accounting Pronouncements

In September 2011, the FASB issued Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350) - Testing Goodwill for Impairment (ASU 2011-08), to allow entities to use a qualitative approach to test goodwill for impairment. ASU 2011-08 permits an entity to first perform a qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying value. If it is concluded that this is the case, it is necessary to perform the currently prescribed two-step goodwill impairment test. Otherwise, the two-step goodwill impairment test is not required. ASU 2011-08 is effective for us in fiscal 2012 and earlier adoption is permitted. The Company is currently evaluating the impact of our pending adoption of ASU 2011-08 on our consolidated financial statements.

Management does not expect the adoption of recently issued accounting pronouncements to have a significant impact on our results of operations, consolidated financial position or cash flow.

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Supplemental Oil and Gas Activities (Tables)

12 Months Ended

Dec. 31, 2012

Extractive Industries [Abstract]

Schedule of proved developed and undeveloped oil and gas reserves

Reserve Category	At December 31,  2012		At December 31,  2011		At December 31,  2010
Proved Developed:
Crude Oil (Bbls)		61,180		29,802		2,274
Natural Gas (Mcf)		29,360		46,536		-
Total Oil Equivalent (BOE)		66,073		37,558		2,274
Proved Undeveloped:
Crude Oil (Bbls)		-		8,528		1,806
Natural Gas (Mcf)		-		2,870		-
Total Oil Equivalent (BOE)		-		9,006		1,806

The following table sets forth purchase, production and reserve adjustment activities for the three year period ended December 31, 2012. 

Reserved Quantity	Oil (BBLS)			Natural Gas (MCF)
Balance, August 10, 2010		-			-
Purchases		4,204			-
Production		(124	)		-
Balance, December 31, 2010		4,080			-
Purchases		35,560			49,948
Production		(1,310	)		(542	)
Balance, December 31, 2011		38,330			49,406
Purchases
Production		5,823			1,404
Adjustments to existing reserves		22,850			(20,046	)
Balance, December 31, 2012		67,003			30,764

Schedule of discounted future cash flows

Standardized Measure of Future Net Cash Flows:

	December 31, 2012			December 31, 2011			December 31, 2010
Future cash flows	$	5,962,350		$	3,278,186		$	231,430
Future production and development costs		(3,484,120	)		(1,377,560	)		(90,258	)
Future income taxes		-			-			-
Future net cash flows before discount		2,478,230			1,900,626			141,172
10% discount to percent value		(1,133,720	)		(769,576	)		(61,484	)
Standardized measure of discounted future net cash flows	$	1,344,510		$	1,131,050			79,688

Schedule of changes in discounted future net cash flows

Changes in the Standard Measure of Discounted Cash Flows:

	December 31, 2012			December 31, 2011			December 31, 2010
Standardized measure of discounted future net cash flows    beginning of period	$	1,131,050		$	79,688		$	-
Purchases of reserves in place		-			1,064,368			-
Extension and discoveries, net of future production    and development costs		112,227			-			89,901
Sales of oil and gas produced, net of production costs		(111,914	)		(31,497	)		(10,213	)
Extension and discoveries, net of future production    and development costs		113,105			7,969			-
Revisions of previous quantity estimates		1,465,199			(68,859	)		-
Net change in prices and production costs		(1,186,254	)		26,611			-
Net change in income taxes		-			-			-
Changes in timing and other		(178,903	)		52,770			-
Standardized measure of discounted future net cash flows end of period	$	1,344,510		$	1,131,050		$	79,668

Schedule of productive wells

We own mineral interests leases on the following productive wells, developed acreage and undeveloped acreage in Texas.  Other properties outside of Texas have been excluded from this table. 

	December 31, 2012
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1
Gross & Net Developed Acreage		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29

	December 31, 2011
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1
Gross & Net Developed Acreage		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29

	December 31, 2011
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		3		11		-		-
Gross & Net Developed Acreage		110		83		-		-
Gross & Net Undeveloped Acreage		453		91		-		-

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Fair Value Disclosure (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Gain (loss) on change in fair value of embedded derivatives	$ (2,326,032)	$ 1,115,403
Loss of embedded derivative liabilities exceeded the principal of the related notes on date notes were issued	(704,186)	(1,211,683)
Loss on embedded derivative, net	$ (3,030,218)	$ (96,280)

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Supplemental Oil and Gas Activities (Details)	Dec. 31, 2012 Boe	Dec. 31, 2011 Boe	Dec. 31, 2010 Boe
Total Oil Equivalent, developed (BOE)	66,073	37,558	2,274
Total Oil Equivalent, undeveloped (BOE)		9,006	1,806
Crude Oil
Proved Developed, reserves	61,180	29,802	2,274
Proved Undeveloped		8,528	1,806
Natural Gas
Proved Developed, reserves	29,360	45,536
Proved Undeveloped		2,870

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CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2012	Dec. 31, 2011
CURRENT ASSET
Cash	$ 572,784	$ 593,469
Accounts receivable	133,258	35,405
Related party receivables	13,196	25,718
Other receivable		160,302
Total current assets	719,238	814,894
Evaluated, net of accumulated depletion of $137,120 and $23,135 as of December 31, 2012 and 2011, respectively	1,054,322	528,336
Unevaluated	261,975	617,630
TOTAL ASSETS	2,035,535	1,960,860
CURRENT LIABILITIES
Accounts payable and accrued liabilities	407,284	217,702
Other payable	451,939	431,151
Total current liabilities	859,223	648,853
Accrued interest		141,255
Convertible note payable, net of discount of $- and $1,561,997 as of December 31, 2012 and 2011, respectively		623,003
Embedded derivative liability		1,138,989
Asset retirement obligation	69,316	56,012
TOTAL LIABILITIES	928,539	2,608,112
STOCKHOLDERS' DEFICIT
Preferred Stock, Series B, $0.001 par value, 1,000 shares authorized, 1,000 shares issued and 1,000 share outstanding and no shares issued and outstanding, respectively	1
Common stock, $.0001 par value, 100,000,000 shares authorized, 50,339,543 shares issued and 50,339,542 and 44,000,000 shares outstanding, respectively	50,339	44,000
Additional paid-in capital	8,313,299	487,739
Accumulated deficit	(7,256,643)	(1,178,991)
Total stockholders' deficit	1,106,996	(647,252)
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT	$ 2,035,535	$ 1,960,860

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Other Payables (Details Narrative) (USD $)	Dec. 31, 2012
Payables and Accruals [Abstract]
Advances from working interest owners	$ 451,939

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CONSOLIDATED STATEMENTS OF CASH FLOW (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Statement of Cash Flows [Abstract]
Net (loss)	$ (6,077,652)	$ (1,083,341)
to net cash used in operating activities:
Depreciation expense
Depletion expense	113,985	19,225
Accretion expense	3,514	2,592
Share based compensation	30,501
Amortization of debt discount	2,176,996	168,935
Loss on embedded derivatives	3,030,218	96,280
Change in assets and liabilities
Accounts receivable	(97,853)	(31,835)
Related party receivable	12,522	(44,362)
Other receivable	160,302	(141,658)
Accounts payable and accrued expenses	189,582	(26,192)
Accrued interest	75,939	120,330
Other payable	20,788	431,151
Net cash (used in) operating activities	(361,158)	(488,875)
Acquisition of oil and gas properties	(274,527)	(715,000)
Net cash used in investing activities	(274,527)	(715,000)
Proceeds from convertible notes	615,000	1,565,000
Payment of note payable		(250,000)
Payment of related party payable		(25,000)
Payment of related party notes payable		(50,000)
Net cash provided by financing activities	615,000	1,240,000
NET INCREASE IN CASH AND CASH EQUIVALENTS	(20,685)	36,125
CASH AND CASH EQUIVALENTS - BEGINNING OF PERIOD	593,469	557,344
CASH AND CASH EQUIVALENTS - END OF PERIOD	572,784	593,469
Interest
Taxes
NON CASH TRANSACTIONS:
Asset retirement liability incurred	9,790	37,955
Stock repurchase and cancellation
Common stock issued for oil and gas property		40,500
Acquisition of oil and gas properties with payables		84,975
Discount from derivative liabilities	324,541	880,373
Discount to additional paid-in capital from relative fair value of warrants	290,459	684,627
Conversion of convertible notes payable	2,800,000
Conversion of accrued interest	217,271
Settlement of derivative liabilities to additional paid-in capital	$ 4,493,670

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Related Party Receivable (Details Narrative) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Related Party Receivable Details Narrative
Accounts Receivable, Related Parties	$ 13,196	$ 25,718
Reduction in accounts receivable, related parties (percentage)	51.31%

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Share Based Compensation

12 Months Ended

Dec. 31, 2012

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Share Based Compensation

16.          Share Based Compensation

On December 21, 2012 directors of the Company approved share based compensation plan for an employee, an advisor and independent investor relations advisor of 80,000, 125,000 and 100,000 shares of common stock as share based compensation.  These shares were issued at a market price of $0.10 per share.  During the twelve months ended December 31, 2012, the Company recognized $30,500 as share based compensation expense.

On December 26, 2012, the Company issued 500 shares of Series B Preferred Stock, each to Michael Carey, its Chief Executive Officer, President and Director, and Ryan Hudson, its Chief Operating Officer, Secretary and Director (1,000 shares of Series B Preferred Stock in aggregate), in consideration for services rendered to the Company as the Company’s Chief Executive Officer, President and Director, and Chief Operating Officer, Secretary and Director, respectively.  The Company has evaluated the fair value of the share based compensation is $1.

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Embedded Derivative Liabilities (Details Narrative) (USD $)	0 Months Ended												2 Months Ended
	Jun. 04, 2012	Apr. 13, 2012	Mar. 30, 2012	Feb. 10, 2012	Dec. 19, 2011	Nov. 29, 2011	Oct. 14, 2011	Jun. 30, 2011	Jun. 20, 2011	Mar. 09, 2011	Jan. 20, 2011	Dec. 31, 2010	Jun. 01, 2012	Jun. 07, 2012
Embedded Derivative Liabilities Details Narrative
Debt Conversion, Original Debt, Amount (in Dollars)		$ 620,000											$ 590,000	$ 1,590,000
Debt Conversion, Converted Instrument, Shares Issued (in Shares)		1,240,000											1,180,000	3,180,000
Fair Value, Convertible Debt, Valuation Techniques		1,280,115											955,179	2,258,376
Fair Value Assumptions, Expected Dividend Rate	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%
Fair Value Assumptions, Expected Volatility Rate	112.94%	108.17%	110.64%	110.77%	109.32%	109.19%	108.61%	107.39%	105.87%	105.22%	104.65%	94.10%	111.24%	102.93%
Fair Value Assumptions, Risk Free Interest Rate	0.27%	0.27%	1.04%	1.04%	0.82%	0.93%	1.12%	1.76%	1.55%	2.16%	2.06%	2.01%	0.25%	0.27%
Fair Value Assumptions, Expected Term	4 years 8 months	1 year 262 days	5 years	5 years	5 years	5 years	5 years	5 years	5 years	5 years	5 years	5 years	1 year 211 days	2 years 127 days
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt, Subsequent Adjustments (in Dollars)													$ 2,235,294	$ 2,258,376

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Supplemental Oil and Gas Activities

12 Months Ended

Dec. 31, 2012

Extractive Industries [Abstract]

Supplemental Oil and Gas Activities

18.          Supplemental Oil and Gas Reserve Information

Company Reserve Estimates. Our proved reserve information as of December 31, 2012 was estimated by Mire and Associates, Inc. (“Mire”), independent petroleum engineers.  In accordance with SEC guidelines, Mire’s estimates of future net revenues from our properties, and the PV-10 and standardized measure thereof, were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the period January 1, 2012 through December 31, 2012, except where such guidelines permit alternate treatment, including the use of fixed and determinable contractual price escalations.

The technical persons at Mire are responsible for preparing the reserves estimates presented herein and meets the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. Michael Carey, our officer and director, acted as the liaison with the technical persons at Nova and Mire. 

Reserve Technologies.  Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and 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.  If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered.  If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate.  To achieve reasonable certainty, Nova and Mire employed technologies that have been demonstrated to yield results with consistency and repeatability. The technologies and economic data used in the estimation of our proved reserves include, but are not limited to, well logs, geologic maps and available down well and production data, seismic data, well test data.

Oil and Gas Reserve Information.  The following reserve quantities for our proved reserves located in the State of Texas in the United States have been estimated as of December 31, 2012.  The determination of oil and gas reserves is based on estimates, which are highly complex and interpretive. The estimates are subject to continuing changes as additional information becomes available.

The following table sets forth the proved developed and proved undeveloped reserves for the three year period ended December 31, 2012.

Reserve Category	At December 31,  2012		At December 31,  2011		At December 31,  2010
Proved Developed:
Crude Oil (Bbls)		61,180		29,802		2,274
Natural Gas (Mcf)		29,360		46,536		-
Total Oil Equivalent (BOE)		66,073		37,558		2,274
Proved Undeveloped:
Crude Oil (Bbls)		-		8,528		1,806
Natural Gas (Mcf)		-		2,870		-
Total Oil Equivalent (BOE)		-		9,006		1,806

The following table sets forth purchase, production and reserve adjustment activities for the three year period ended December 31, 2012.

Reserved Quantity	Oil (BBLS)			Natural Gas (MCF)
Balance, August 10, 2010		-			-
Purchases		4,204			-
Production		(124	)		-
Balance, December 31, 2010		4,080			-
Purchases		35,560			49,948
Production		(1,310	)		(542	)
Balance, December 31, 2011		38,330			49,406
Purchases
Production		5,823			1,404
Adjustments to existing reserves		22,850			(20,046	)
Balance, December 31, 2012		67,003			30,764

The standardized measure of discounted future net cash flows is provided using the 12-month unweighted arithmetic average and were held constant throughout the life of the properties. The oil price used as of December 31, 2012 was $94.71 per bbl of oil and $2.85 per MMbtu of natural gas. Future production costs are based on year-end costs and include severance and ad valorem taxes. Each property that is leased by us is also charged with field-level overhead in the reserve calculation. The present value of future cash inflows is based on a 10% discount rate.

Standardized Measure of Future Net Cash Flows:

	December 31, 2012			December 31, 2011			December 31, 2010
Future cash flows	$	5,962,350		$	3,278,186		$	231,430
Future production and development costs		(3,484,120	)		(1,377,560	)		(90,258	)
Future income taxes		-			-			-
Future net cash flows before discount		2,478,230			1,900,626			141,172
10% discount to percent value		(1,133,720	)		(769,576	)		(61,484	)
Standardized measure of discounted future net cash flows	$	1,344,510		$	1,131,050			79,688

Changes in the Standard Measure of Discounted Cash Flows:

	December 31, 2012			December 31, 2011			December 31, 2010
Standardized measure of discounted future net cash flows    beginning of period	$	1,131,050		$	79,688		$	-
Purchases of reserves in place		-			1,064,368			-
Extension and discoveries, net of future production    and development costs		112,227			-			89,901
Sales of oil and gas produced, net of production costs		(111,914	)		(31,497	)		(10,213	)
Extension and discoveries, net of future production    and development costs		113,105			7,969			-
Revisions of previous quantity estimates		1,465,199			(68,859	)		-
Net change in prices and production costs		(1,186,254	)		26,611			-
Net change in income taxes		-			-			-
Changes in timing and other		(178,903	)		52,770			-
Standardized measure of discounted future net cash flows end of period	$	1,344,510		$	1,131,050		$	79,668

The information required by Items 1204 to 1208 of Regulation S-K are provided as follows:

Production. For the year ended December 31, 2012, we had production from our Lozano, Marcee, McKinney and Patriot leases located in six Texas counties: Erath, Gonzalez, Medina, Navarro, Shackleford and Wilbarger.  The Company produced approximately 5,823 barrels of oil and 1,404 Mcf (thousand cubic feet) of gas on a net basis.

For the year ended December 31, 2011, we only had production from our interest in the Lozano lease located in Frio County, Texas.  The Company produced approximately 1,310 barrels and 542 Mcf on a net basis.

Drilling Activity.  During the month of December 2011 and January 2012, we conducted unsuccessful drilling activity in Texas on the Gabriel #16 well to test an anticipated payzone in the Serpentine formation.  Based upon the Company’s current working capital and access to funding, the Company does not plan to conduct any new drilling during 2013.  The Company will focus on increasing existing producing properties and production from workover ventures on existing wells.

We own mineral interests leases on the following productive wells, developed acreage and undeveloped acreage in Texas.  Other properties outside of Texas have been excluded from this table.

	December 31, 2012
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1
Gross & Net Developed Acreage		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29

	December 31, 2011
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		88		11		1		1
Gross & Net Developed Acreage		1,553		480		325		149
Gross & Net Undeveloped Acreage		1,572		344		557		29

	December 31, 2011
	Oil				Gas
	Gross		Net		Gross		Net
United States - Texas
Gross & Net Productive Wells		3		11		-		-
Gross & Net Developed Acreage		110		83		-		-
Gross & Net Undeveloped Acreage		453		91		-		-

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Nature of Operations and Basis of Presentation

12 Months Ended

Dec. 31, 2012

Nature Of Operations And Basis Of Presentation

Nature of Operations and Basis of Presentation

1. Nature of Operations and Basis of Presentation

Nature of Operations

4 Phoenix Oil & Gas, LLC, a limited liability company, was formed under the laws of the state of Texas on October 19, 2009 (“Predecessor”).   On August 10, 2010, we formed United American Petroleum Corp. a company incorporated under the laws of the state of Nevada.  United American Petroleum Corp.’s principal business is the acquisition and management of leasehold interests in petroleum and natural gas rights, either directly or indirectly, and the exploitation and development of properties subject to these leases.  In these notes, the terms “United,” “Company,” “we,” “us,” “successor," or “our” mean United American Petroleum Corp.

On December 31, 2010, the Company entered into a Plan of Merger (the “Merger”) with Forgehouse, Inc. and their newly formed wholly-owned subsidiary United PC Acquisition Corp. Following the closing and pursuant to the Plan of Merger, effective as of December 31, 2010, the Company merged with and into United PC Acquisition Corp. with the Company surviving (the “Reverse Merger”). The Company, as a wholly-owned subsidiary of Forgehouse, Inc. was then merged with and into Forgehouse, Inc. and Forgehouse, Inc. changed its name to United American Petroleum Corp. For accounting purposes, the Merger was treated as a reverse merger and a recapitalization of United American Petroleum Corp.

On January 13, 2011, the Company formed a wholly owned subsidiary, UAP Management, LLC, a Texas limited liability company, for the purpose of managing the Gabriel Rosser, LP (see Note 9).

On January 13, 2011, the Company formed a wholly owned subsidiary, United Operating, LLC, a Texas limited liability company, for the purpose of operating and managing the various interests acquired from Patriot Minerals, LLC (see Note 9).

 Basis of Presentation

The accompanying consolidated financial statements include United American Petroleum Corp. and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated. The accompanying financial statements have been prepared in accordance with the Generally Accepted Accounting Principles in the United States of America ("GAAP"). We made certain reclassifications to prior-period amounts to conform to the current presentation.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reported periods.  Actual results could materially differ from those estimates.

Cash and Cash Equivalents

All highly liquid investments purchased with an original maturity of three months or less at the time of acquisition are considered to be cash equivalents.

Fair Value of Financial Instruments

The Company is required to estimate the fair value of all financial instruments included on its balance sheet.  The carrying value of cash, accounts receivable, accounts payable and accrued liabilities approximate their fair value due to the short period to maturity of these instruments.

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CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Consolidated Balance Sheets Parenthetical
Evaluated, net of accumulated depletion (in Dollars)	$ 137,120	$ 23,135
Convertible note payable, net of discount (in Dollars)		$ 1,561,997
Preferred stock, par value (in Dollars per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized (in Shares)	1,000	1,000
Preferred stock, shares issued (in Shares)	1,000
Preferred stock, shares outstanding (in Shares)	1,000
Common stock par value (in Dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized (in Shares)	100,000,000	100,000,000
Common stock, shares issued (in Shares)	50,339,543	50,339,543
Common stock, shares outstanding (in Shares)		44,000,000

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Note Payable Related Party

12 Months Ended

Dec. 31, 2012

Note Payable Related Party

Note Payable Related Party

11.          Note Payable – Related Party

As part of the Reverse Merger, the Company assumed two notes payable owed to an individual who is a shareholder of the Company. The notes payable are unsecured and each has a face value of $25,000 with a fixed interest rate of 10% per annum. The notes payable were due on demand and were fully paid in January 2011.

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Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2012	Apr. 14, 2013	Jun. 30, 2012
Document And Entity Information
Entity Registrant Name	United American Petroleum Corp.
Document Type	10-K
Current Fiscal Year End Date	--12-31
Amendment Flag	false
Entity Central Index Key	0001321516
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Document Period End Date	Dec. 31, 2012
Entity Public Float			$ 14,884,543
Entity Common Stock, Shares Outstanding		50,339,543
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2012

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Other Payable

12 Months Ended

Dec. 31, 2012

Other Payable

Other Payable

12.         Other Payable

As of December 31, 2012, United Operating, LLC received cash in the amount of $451,939 to perform work on behalf of various working interest owners including repairs, drilling and production related costs.

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
REVENUE
Oil sales	$ 512,088	$ 141,362
Well operator income	39,207	69,452
TOTAL REVENUE	551,295	210,814
OPERATING EXPENSES (INCOME)
Lease operating expenses	400,174	63,389
Accretion expense	3,514	2,592
Depletion expense	113,985	19,225
General and administrative	828,141	823,379
TOTAL OPERATING EXPENSES	1,345,814	908,584
NET LOSS BEFORE OTHER EXPENSE	(794,519)	(697,770)
OTHER INCOME (EXPENSE)
Interest Expense	(2,252,915)	289,291
Loss on embedded derivatives	(3,030,218)	(96,280)
Total other expense	(5,283,133)	(385,571)
NET INCOME (LOSS)	$ (6,077,652)	$ (1,083,341)
INCOME (LOSS) PER SHARE - BASIC	$ (0.13)	$ (0.02)
WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING - BASIC	47,633,640	43,954,258
INCOME (LOSS) PER SHARE - DILUTED	$ (0.13)	$ (0.02)
WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING - DILUTED	47,633,640	43,954,258

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Embedded Derivative Liabilities

12 Months Ended

Dec. 31, 2012

Embedded Derivative Liabilities

Embedded Derivative Liabilities

6.            Embedded Derivative Liabilities

Conversion Option Liability

As described in Note 14, the Company issued a convertible note with certain reset provisions. The Company accounted for these reset provisions in accordance with ASC 815-40, which requires that the Company bifurcate the embedded conversion option as a liability at the grant date and to record changes in fair value relating to the conversion option liability in the statement of operations as of each subsequent balance sheet date.   The debt discount related to the convertible note is amortized over the life of the note using the effective interest method.  See Note 8 for a reconciliation of the changes in fair value of the Company’s embedded derivative.  

December 31, 2010 Convertible Note Installments (First Financing)

On April 13, 2012, the Company converted a $620,000 convertible note into 1,240,000 shares of common stock.  On the conversion date, the Company determined a fair value of $1,280,115 for the conversion option liability for this convertible note using the Black Scholes Option Pricing Model based upon the following:  dividend yield of -0-%, volatility of 108.17%, risk free rate of 0.27% and an expected term of approximately 1.72 years.  The Company recognized a non-cash loss included in other income (expense) of $982,960 preceding conversion during fiscal year 2012.

On June 1, 2012, the Company converted $590,000 of its convertible notes into 1,180,000 shares of common stock.  On the conversion date, the Company determined a fair value of $955,179 for these convertible notes using the Black Scholes Option Pricing Model based upon the following: dividend yield of -0-%, volatility of 111.24%, risk free rate of 0.25% and an expected term of approximately 1.58 years.  The Company recognized a non-cash loss included in other income (expense) of $668,692 preceding conversion during fiscal year 2012.

During fiscal year 2012, the Company recognized a reduction of embedded derivative from the first installment of its convertible notes in the amount of $2,235,294.  This amount was recorded to additional paid-in capital.

October 14, 2011 Convertible Note Installments (Second Financing)

On June 7, 2012, the Company converted $1,590,000 of its convertible notes into 3,180,000 shares of common stock.  On the conversion date, the Company determined a fair value of $2,258,376 for these convertible notes using the Black Scholes Option Pricing Model based upon the following: dividend yield of -0-%, volatility of 102.93%, risk free rate of 0.27% and an expected term of approximately 2.35 years.  The Company recognized a non-cash loss included in other expense of $674,380 preceding conversion for the year ended December 31, 2012.

During fiscal year 2012, the Company recognized a reduction of embedded derivative from the second installment of its convertible notes in the amount of $2,258,376.  This amount was recorded to additional paid-in capital.

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Related Party Recceivable

12 Months Ended

Dec. 31, 2012

Related Party Recceivable

Related Party Receivable

5.            Related Party Receivable

As of December 31, 2012, the Company had a related party receivable in the amount of $13,196 due related to working interest amounts payable. This is a 51.31% (reduction) from an amount of $25,718 as of December 31, 2011.  Our directors are also officers in this Company.

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Income taxes

12 Months Ended

Dec. 31, 2012

Income Taxes

Income taxes

17.          Income taxes

As of December 31, 2012, our deferred tax asset amounting to $264,635 primarily related to our net operating losses of $794,519.  A 100% valuation allowance has been established using an effective tax rate of 35% due to the uncertainty of the utilization of the operating losses in future periods.  As a result, the deferred tax asset was reduced to zero and no income tax benefit was recorded. The net operating loss carryforward will begin to expire in 2031.

Section 382 of the Internal Code allows post-change corporations to use pre-change net operating losses, but limit the amount of losses that may be used annually to a percentage of the entity value of the corporation at the date of the ownership change.  The applicable percentage is the federal long-term tax-exempt rate for the month during which the change in ownership occurs.

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Convertible Note Payable

12 Months Ended

Dec. 31, 2012

Convertible Note Payable

13.          Convertible Note Payable

Credit Facility – October 14, 2011

On October 14, 2011, we entered into a Note and Warrant Purchase Agreement with an investor pursuant to which the investor agreed to lend the Company up to $1,500,000 in multiple installments in exchange for a senior secured convertible promissory note with a conversion price of $0.50 per share and five-year warrants to acquire shares of common stock at an exercise price of $1.00 per share in the amount of each installment. The first installment of $400,000 was delivered on the date of the Purchase Agreement and we issued 400,000 warrants to the investor in connection with the first installment. The notes mature on October 14, 2014, or upon default, whichever is earlier and bear interest at an annual rate of 10%.

The second installment of $550,000 was delivered on November 29, 2011 and we granted warrants to purchase 550,000 shares in connection with the second installment.

The third installment of $25,000 was delivered on December 19, 2011 and we granted warrants to purchase 25,000 shares in connection with the third installment.

The fourth installment of $150,000 was delivered on February 10, 2012 and we granted warrants to purchase 150,000 sharesin connection with the fourth installment.

The fifth installment of $250,000 was delivered on March 30, 2012 and we granted warrants to purchase 250,000 shares in connection with the fifth installment.

The sixth installment of $215,000 was delivered on June 4, 2012 and we granted warrants to purchase 430,000 shares in connection with the sixth installment.

UNITED AMERICAN PETROLEUM CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

13.          Convertible Note Payable (Continued)

Using a pro rata contribution, the Company allocated the proceeds of the February 10, 2012, March 30, 2012 and June 4, 2012, convertible notes (which were delivered during the nine months ended September 30, 2012) first to the relative fair value of the warrants and the remainder to the fair value of the embedded derivative on the date of grant as follows:

	February 10, 2012			March 30, 2012			June 4, 2012			Total
Total Proceeds	$	150,000		$	250,000		$	215,000		$	615,000
Allocated to:
Conversion Option Liability		189,052			514,783			325,831			1,029,666
Relative Fair Value of Warrants		61,354			130,853			97,313			289,520
Total Fair Value of Derivative		250,406			645,636			423,144			1,319,186
Debt Discount		(150,000	)		(250,000	)		(215,000	)		(615,000	)
Loss on debt derivative	$	100,406		$	395,636		$	208,144		$	704,186

During the years ended December 31, 2012 and 2011, the Company amortized $2,155,448 and $168,935 of the debt discount to interest expense.  The debt discount from the convertible notes was immediately expensed upon the conversion of the convertible notes during the period ended December 31, 2012.

On June 7, 2012, the Company issued 3,314,062 shares of common stock to one investor who elected to convert the outstanding principal amount of $1,590,000 and all of the accrued interest due on its convertible promissory notes dated October 14, 2011, November 29, 2011, December 19, 2011, February 10, 2012, March 30, 2012 and June 4, 2012 at a conversion price of $0.50 per share as provided in the note agreement.

Credit Facility – December 31, 2010

On December 31, 2010, the Company entered into a credit facility with one investor pursuant to which the investor agreed to lend up to $2,250,000 to us in multiple installments in exchange for a senior secured convertible promissory note with a conversion price of $0.50 per share and five-year warrants to acquire shares of common stock at an exercise price of $1.00 per share in the amount of each installment. The credit facility provides that the investor will lend additional installments to us in amounts as requested by us; provided however, that we provide the proposed use of proceeds for each requested amount. The investor shall have sole discretion in determining whether the proposed use of proceeds meets those requirements. The notes mature on December 31, 2013, or upon default, whichever is earlier and bear interest at an annual rate of 10%.

On April 13, 2012, the Company issued 1,240,000 shares of common stock to one investor who elected to convert the outstanding principal amount of $620,000 due on its convertible promissory note dated December 31, 2010 at a conversion price of $0.50 per share as provided in the note agreement.

On June 1, 2012, the Company issued 1,180,000 shares of common stock to one investor who elected to convert the outstanding principal amount of $590,000 due on its convertible promissory notes dated January 1, 2011, March 9, 2011, June 20, 2011 and June 30, 2011 at a conversion price of $0.50 per share as provided in the note agreement.

On June 11, 2012, the Company issued 300,481 shares of common stock to one investor who elected to convert all of their accrued interest in the amount of $150,240 on its convertible notes from its first financing at a conversion price of $0.50 per share as provided in the note agreement.

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Oil and Gas Properties

12 Months Ended

Dec. 31, 2012

Extractive Industries [Abstract]

Oil and Gas Properties

9.           Oil and Gas Properties

During the twelve months ended December 31, 2012, the Company proposed workover procedures to third party working interest owners on properties for which the Company has ownership.  Third party working interests owners were allowed to avoid liability associated with the procedures by conveying their working interests and net royalty interests to the Company. Certain third party working interest partners conveyed various working interests and net royalty interests in their properties.  The Company has assumed production revenues, lease operating expenses and asset retirement obligations associated with the conveyance of the working interests and net royalty interests.

During 2012, United American Petroleum Corp. performed drilling and completion procedures on the McKenzie, Marcee and Gabriel Rosser properties of $27,225, $44,792 and $177,000.

During 2012, United American Petroleum Corp. entered and closed a purchase and sale agreement to purchase an undivided working interest rights for the RP Wilson lease for $25,000 providing, among other things, that United American Petroleum Corp. shall purchase a 28% working interest, and a 26% revenue interest to certain existing wells and to certain leases located in Texas.

On January 28, 2011, United American Petroleum Corp. entered and closed a purchase and sale agreement with Patriot Minerals, LLC, a Texas limited liability company for a $5,000 payment to a consultant. The Purchase Agreement provides, among other things, that United American Petroleum Corp. shall purchase multiple undivided working interests to certain existing wells and to certain leases located in Texas. In connection with the Purchase Agreement, United American Petroleum Corp. formed a wholly owned subsidiary, United Operating, LLC, a Texas limited liability company, for the purpose of operating the various interests set forth in the Purchase Agreement. The properties purchased from Patriot Minerals by United American Petroleum Corp. are producing at December 31, 2011. The Company is currently undergoing various reserve studies to assess potential production and to continue the development of the wells purchased.

On January 28, 2011, United American Petroleum Corp. entered and closed a purchase, sale and participation agreement with Gabriel Rosser, LP (“Gabriel”). The purchase agreement provided for the Company to purchase Gabriel's undivided 50.83% working interest and 39.131% revenue interest in the Gabriel 2 SWD Gabriel 3, 4, 5, 9, 15, Rosser #2 and #4 and Koi #1wells in exchange for consideration of $10 and the assumed and paid $84,975 of liabilities, which were owed to certain vendors of Gabriel. The properties purchased from Gabriel Rosser, LP by United American Petroleum Corp. are unevaluated and non-producing as of December 31, 2011, and the Company is currently undergoing various reserve studies to assess potential production and develop the wells purchased.

On November 4, 2011, United American Petroleum Corp. entered into and closed an Agreement with Alamo Energy Corp., a Nevada corporation pursuant to which United American acquired a 75% working interest in an oil and gas lease totaling approximately 110 gross acres located in Frio County, Texas and all wellbores and personal property related thereto for the total purchase price of $160,000. The Company currently has a 100% working interest in the Lozano lease, which is a producing property with three wells.

On November 30, 2011, the Company entered into and closed an agreement with McKenzie Oil Corp. pursuant to which United American acquired a 100% working interest in what is designated as the McKenzie State Well No. 1, located in Pecos County, Texas, in exchange for an aggregate cash sum of $550,000 and 50,000 shares of the Company’s common stock valued at $40,500. The McKenzie well currently has one producing well valued at $80,655. The remaining wells are classified as unproved. 

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Detachable Warrants

12 Months Ended

Dec. 31, 2012

Detachable Warrants

Detachable Warrants

7.            Detachable Warrants

As described in Note 14, the Company issued convertible notes with detachable warrants. The Company accounted for these detachable warrants in accordance with ASC 470-20, which requires that the Company calculate the relative fair value of the warrants at the grant date and record the relative fair value as a discount to the related note payable with an offset to additional paid-in capital. The Company amortizes the debt discount associated with the warrants over the life of the convertible notes using the effective interest method.

On February 10, 2012, the Company determined a relative fair value of $61,354 for the detachable warrants for the fourth installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 110.77%, risk free rate of 1.04% and an expected term of approximately 5 years.

On March 30, 2012, the Company determined a relative fair value of $130,853 for the detachable warrants for the sixth installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 110.64%, risk free rate of 1.04% and an expected term of approximately 5 years.

On June 4, 2012, the Company determined a relative fair value of $97,313 for the detachable warrants for the fifth installment of the convertible notes. In calculating the relative fair value of the warrants the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 112.94%%, risk free rate of 0.27% and an expected term of approximately 4.69 years.

A summary of warrant activity for the period from December 31, 2011 through December 31, 2012 is presented below:

	Number of Warrants		Weighted Average Exercise Price		Weighted Average Remaining Contract Term
Outstanding December 31, 2011		2,185,000	$	1.00	3.45 years
Issued		615,000	$	1.00	4.17years
Exercised		-		-	-
Outstanding December  31, 2012		2,800,000	$	1.00	3.61 years
Exercisable, December  31, 2012		2,800,000	$	1.00	3.61 years

Shares Reserved for Future Issuance

The Company has reserved shares for future issuance upon of its warrants as follows:

Warrants	2,800,000
Reserved shares at December  31, 2012	2,800,000

December 31, 2010 – Convertible Note Installments (First Financing)

On December 31, 2010, the Company determined a relative fair value of $45,434 for the detachable warrants for the first installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of: -0-%, volatility of 94.1%, risk free rate: 2.01% and an expected term of 5 years.

On January 20, 2011, the Company determined a relative fair value of $78,062 for the detachable warrants for the second installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of: -0-%, volatility of 104.65%, risk free rate: 2.06% and an expected term of 5 years.

On March 9, 2011, the Company determined a relative fair value of $106,132 for the detachable warrants for the third installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 105.22% , risk free rate of 2.16% and an expected term of approximately 5 years.

On June 20, 2011, the Company determined a relative fair value of $29,276 for the detachable warrants for the fourth installment of the convertible notes.  In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 105.87%, risk free rate of 1.55% and an expected term of approximately 5 years.

On June 30, 2011, the Company determined a relative fair value of $45,233 for the detachable warrants for the fifth installment of the convertible notes.  In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 107.39%, risk free rate of 1.76% and an expected term of approximately 5 years.

As described in Note 5, during fiscal year 2012, these notes associated with the first financing were converted into share of common stock.

October 14, 2011 – Convertible Note Installments (Second Financing)

On October 14, 2011, the Company determined a relative fair value of $157,388 for the detachable warrants for the first installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 108.61%, risk free rate of 1.12% and an expected term of approximately 5 years.

On November 29, 2011, the Company determined a relative fair value of $209,317 for the detachable warrants for the second installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 109.19%, risk free rate of .93% and an expected term of approximately 5 years.

On December 19, 2011, the Company determined a relative fair value of $13,788 for the detachable warrants for the third installment of the convertible notes. In calculating the relative fair value of the warrants, the Company used the Black Scholes Option Pricing Model based upon the following assumptions: dividend yield of -0-%, volatility of 109.32%, risk free rate of .82% and an expected term of approximately 5 years.

As described in Note 6, during fiscal year 2012, these notes associated with the second financing were converted into shares of common stock.

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Fair Value

12 Months Ended

Dec. 31, 2012

Fair Value

Fair Value

8.           Fair Value

The Company measures fair value in accordance with a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy are described below:

Level 1	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities;
Level 2	Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability; and
Level 3	Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (supported by little or no market activity).

The following table sets forth the Company's consolidated financial assets and liabilities measured at fair value by level within the fair value hierarchy. Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

	Total		Level 1		Level 2		Level 3
LIABILITIES:
2012- Conversion option liability	-		-		-		-
2011- Conversion option liability		-		-		-		1,138,989

The following is a reconciliation of the conversion option liability and detachable warrant liability for which Level 3 inputs were used in determining fair value:

Beginning balance January 1, 2011	$	116,905
Initial recognition of debt derivative from issuance of     January 20, 2011, $150,000 convertible note		333,652
Initial recognition of debt derivative from issuance of     March 9, 2011, $250,000 convertible note		376,698
Initial recognition of debt derivative from issuance of     June 20, 2011, $75,000 convertible note		95,155
Initial recognition of debt derivative from issuance of     June 30, 2011, $115,000 convertible note		142,246
Initial recognition of debt derivative from issuance of    October 14, 2011, $400,000 convertible note		504,896
Initial recognition of debt derivative from issuance of     November 29, 2011, $550,000 convertible note		655,150
Initial recognition of debt derivative from issuance of     December 19, 2011, $25,000 convertible note		29,690
Decrease in fair value of debt derivative		(1,115,403	)
Ending balance as of December  31, 2011	$	1,138,989
Initial recognition of debt derivative from issuance of     February 10, 2012, $150,000 convertible note		189,052
Initial recognition of debt derivative from issuance of     March 30, 2012, $250,000 convertible note		514,784
Initial recognition of debt derivative from issuance of    June 4, 2012, $215,000 convertible note		325,831
Mark to market of debt derivative		2,325,015
Other		1,017
Total debt derivative preceding conversion		4,494,688
Reduction of debt derivative from conversion		(4,494,688	)
Debt derivative as of December 31, 2012	$	-

During the year ended December 31, 2012, the loss on embedded derivatives in the condensed consolidated statement of operations consisted of a loss on the change in fair value of $2,326,032 and a loss of $704,186 which was the amount by which the embedded derivative liabilities exceeded the principal of the related notes payable on the date the notes were issued.

During the year ended December 31, 2011, the loss on embedded derivatives of $96,280 in the consolidated statement of operations consisted of a gain on the change in fair value of $1,115,403 noted above and a loss of $1,211,683 which was the amount by which the embedded derivative liabilities exceeded the principal of the related notes payable on the date the notes were issued.

The Company’s conversion option liabilities are valued using pricing models and the Company generally uses similar models to value similar instruments. Where possible, the Company verifies the values produced by its pricing models to market prices. Valuation models require a variety of inputs, including contractual terms, market prices, yield curves, credit spreads, measures of volatility and correlations of such inputs. These consolidated financial liabilities do not trade in liquid markets, and as such, model inputs cannot generally be verified and do involve significant management judgment. Such instruments are typically classified within Level 3 of the fair value hierarchy. See Note 6 for Black Scholes Option Pricing Model inputs.

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Related Party Payable

12 Months Ended

Dec. 31, 2012

Related Party Payable

Related Party Payable

10.          Related Party Payable

The related party payables were fully paid in December 2011.

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Reclassification - Reclassification (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Oil sales	$ 512,088	$ 141,362
Well operator income	39,207	69,452
TOTAL REVENUE	551,295	210,814
Lease operating expenses	400,174	63,389
Accretion expense	3,514	2,592
Depletion expense	113,985	19,225
General and administrative	828,141	823,379
TOTAL OPERATING EXPENSES	1,345,814	908,584
NET LOSS BEFORE OTHER EXPENSE	(794,519)	(697,770)
Interest Expense	(2,252,915)	289,291
Loss on embedded derivatives	(3,030,218)	(96,280)
NET INCOME (LOSS)	(6,077,652)	(1,083,341)
Prior
Oil sales		141,362
Well operator income		215,178
TOTAL REVENUE		356,540
Lease operating expenses		109,865
Accretion expense		2,592
Depletion expense		19,225
General and administrative		922,628
TOTAL OPERATING EXPENSES		1,054,310
NET LOSS BEFORE OTHER EXPENSE		(697,770)
Interest Expense		289,291
Loss on embedded derivatives		(96,280)
NET INCOME (LOSS)		(1,083,341)
Reclassification of Previously Reported Activity
Well operator income		(145,726)
TOTAL REVENUE		(145,726)
Lease operating expenses		(46,476)
General and administrative		(99,249)
TOTAL OPERATING EXPENSES		(145,726)
NET LOSS BEFORE OTHER EXPENSE
NET INCOME (LOSS)

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Income taxes (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Deferred tax asset, net operating losses	$ 264,635
Net operating losses	$ 794,519
Operating loss carryforward valuation allowance (percent)	100.00%
Effective tax rate	35.00%

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Equity

12 Months Ended

Dec. 31, 2012

Equity [Abstract]

Equity

15.          Equity

Fiscal Year 2012

On October 11, 2012, the Company filed with the Nevada Secretary of State, a Certificate of Designations, Establishing the Designations, Preferences, Limitations and Relative Rights of Its Series B Preferred Stock (the “Designation”).  The Designation, which was approved by the Board of Directors on October 9, 2012 and authorized under the Company’s Articles of Incorporation, provides the Board of Directors the right to designate series of preferred stock, provided for the designation of a series of 1,000 shares of Series B Preferred Stock, par value $0.001 per share (the “Series B Preferred Stock”).  The Series B Preferred Stock have no dividend rights, no liquidation preference, no redemption rights and no conversion rights. The Series B Preferred Stock have the right, voting in aggregate, to vote on all shareholder matters (including, but not limited to, at every meeting of the stockholders of the Company and upon any action taken by stockholders of the Company with or without a meeting) equal to fifty-one percent (51%) of the total vote (the “Super Majority Voting Rights”). Additionally, we are not allowed to adopt any amendments to our Bylaws, Articles of Incorporation, as amended, make any changes to the Certificate of Designations establishing the Series B Preferred Stock, or effect any reclassification of the Series B Preferred Stock, without the affirmative vote of at least 66-2/3% of the outstanding shares of the Series B Preferred Stock.

As described in Note 6, during the year ended December 31, 2012, certain notes payables were converted into 6,034,542 shares of common stock.  See Note 17 related to share based compensation issued by the Company in fiscal year 2012.

Fiscal Year 2011

On November 29, 2011, the Company issued 50,000 shares of common stock as consideration for the McKenzie working interest for $40,500 (0.81 per share).

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Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2012

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The accompanying consolidated financial statements include United American Petroleum Corp. and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated. The accompanying financial statements have been prepared in accordance with the Generally Accepted Accounting Principles in the United States of America ("GAAP"). We made certain reclassifications to prior-period amounts to conform to the current presentation.

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reported periods.  Actual results could materially differ from those estimates.

Cash and Cash Equivalents

Cash and Cash Equivalents

All highly liquid investments purchased with an original maturity of three months or less at the time of acquisition are considered to be cash equivalents.

Fair Value of Financial Instruments

Fair Value of Financial Instruments

The Company is required to estimate the fair value of all financial instruments included on its balance sheet.  The carrying value of cash, accounts receivable, accounts payable and accrued liabilities approximate their fair value due to the short period to maturity of these instruments.

Concentration of Credit Risk

Concentration of Credit Risk

The Company collects its receivables on its working interests in oil and gas properties from well operators. As such, the Company generally has relatively few customers. These receivables are unsecured and the Company performs ongoing credit evaluations of the well operators’ financial condition whenever necessary. Bad debt is recognized on an account-by-account review after all means of collection have been exhausted and recovery is not probable. There has been no bad debt expense for the period ended December 31, 2012 and 2011, respectively.

Revenue Recognition- Oil and Gas

Revenue Recognition- Oil and Gas

The Company recognizes oil and gas revenue from interests in producing wells using the “sales method.” Under this method of accounting, revenues are recognized based on volumes sold, which may differ from the volume to which we are entitled based on our working interest. An imbalance is recognized as a liability only when the estimated remaining reserves will not be sufficient to enable the under–produced owner(s) to recoup its entitled share through future production. Under the sales method, no receivables are recorded where we have taken less than our share of production. Our net imbalance position at December 31, 2012 and December 31, 2011, was immaterial.

Revenue Recognition - Administrative Income

Revenue Recognition – Well Operator Income

The Company will record revenue for well operator income only on properties for which the Company has no ownership in accordance with ASC 605.

For properties in which the Company has ownership, well operator income amounts may be recorded as reductions of the costs incurred, to the extent of identifiable and specific costs of the specific services for which the Company has been reimbursed. No income in excess of those specific costs was recorded and the Company recorded no offset to the full cost pool.

Oil and Gas Properties

Oil and Gas Properties

The Company follows the full cost method of accounting for its investments in oil and gas properties. Under the full cost method, all costs associated with the exploration of properties are capitalized into appropriate cost centers within the full cost pool. Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities. Cost centers are established on a country-by-country basis.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

For each cost center, capitalized costs are subject to an annual ceiling test, in which the costs shall not exceed the cost center ceiling. The cost center ceiling is equal to i) the present value of estimated future net revenues computed by applying current prices of oil and gas reserves (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; plus ii) the cost of properties not being amortized; plus iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; less iv) income tax effects related to differences between the book and tax basis of the properties. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs.

Asset Retirement Obligations

Asset Retirement Obligations

ASC 410, Asset Retirement and Environmental Obligations addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. Specifically, ASC 410 requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. In addition, the asset retirement cost is capitalized as part of the asset’s carrying value and subsequently allocated to expense over the asset’s useful life.

Fair Value of Financial Instruments

Fair Value of Financial Instruments

Unless otherwise indicated, the fair value of all reported assets and liabilities which represent financial instruments approximate the carrying values of such instruments due to their short-term maturity.

Recoverability of Long-Lived Assets

Recoverability of Long-Lived Assets

The Company has adopted Accounting Standards Codification subtopic 360-10, Property, Plant and Equipment (“ASC 360-10”). ASC 360-10 requires that long-lived assets and certain identifiable intangibles held and used by the Company be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

Events relating to recoverability may include significant unfavorable changes in business conditions or a forecasted inability to achieve break-even operating results over an extended period. The Company evaluates the recoverability of long-lived assets based upon forecasted undiscounted cash flows. Should impairment in value be indicated, the carrying value of intangible assets would be adjusted, based on estimates of future discounted cash flows resulting from the use and ultimate disposition of the asset. ASC 360-10 also requires assets to be disposed of be reported at the lower of the carrying amount or the fair value less costs to sell.

Share-Based Compensation

Share-Based Compensation

The Company accounts for share-based compensation in accordance with Accounting Standards Codification subtopic 718-10, Stock Compensation (“ASC 718-10”). This requires the measurement and recognition of compensation expense for all share-based payment awards made to employees and directors, including employee stock options and employee stock purchases related to an Employee Stock Purchase Plan based on the estimated fair values.

As of December 31, 2012, there were no outstanding employee stock options.

Income taxes

Income Taxes

The Company has adopted Accounting Standards Codification subtopic 740-10, Income Taxes (“ASC 740-10”). ASC 740-10 requires the recognition of deferred tax liabilities and assets for the expected future tax consequences of events that have been included in the financial statement or tax returns. Under this method, deferred tax liabilities and assets are determined based on the difference between financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. Valuation allowances are established, when necessary, to reduce deferred tax assets to amounts that are expected to be realized.

Basic and Diluted Earnings (Loss) Per Share

Basic and Diluted Earnings (Loss) Per Share

Basic earnings (loss) per common share is computed by dividing net income (loss) available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per common share is computed in the same way as basic earnings (loss) per common share except that the denominator is increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued and if the additional common shares were dilutive.

Property and Equipment

Property and Equipment

Property and equipment is recorded at cost and depreciated over the estimated useful lives of the assets using principally the straight-line method. When items are retired or otherwise disposed of, income is charged or credited for the difference between net book value and proceeds realized. Ordinary maintenance and repairs are charged to expense as incurred, and replacements and betterments are capitalized.

The range of estimated useful lives used to calculated depreciation for principal items of property and equipment are as follow:

Asset Category	Depreciation Period
Furniture and Fixtures	5 Years
Automobiles	5 Years
Equipment	10 Years

Recent Accounting Pronouncements

Recent Accounting Pronouncements

In September 2011, the FASB issued Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350) - Testing Goodwill for Impairment (ASU 2011-08), to allow entities to use a qualitative approach to test goodwill for impairment. ASU 2011-08 permits an entity to first perform a qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying value. If it is concluded that this is the case, it is necessary to perform the currently prescribed two-step goodwill impairment test. Otherwise, the two-step goodwill impairment test is not required. ASU 2011-08 is effective for us in fiscal 2012 and earlier adoption is permitted. The Company is currently evaluating the impact of our pending adoption of ASU 2011-08 on our consolidated financial statements.

Management does not expect the adoption of recently issued accounting pronouncements to have a significant impact on our results of operations, consolidated financial position or cash flow.

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Equity (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011 McKenzie Oil Corp.
Stock issued upon conversion of convertible debt, (shares)	6,034,542
Stock issued upon acquisition of working interest		$ 40,500
Stock issued upon acquisition of working interest, (shares)		50,000
Stock issued upon acquisition of working interest, (per share)		$ 0.81

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Fair Value (Details) (USD $)	Dec. 31, 2012
Total
Conversion Option Liability
Level 1
Conversion Option Liability
Level 2
Conversion Option Liability
Level 3
Conversion Option Liability

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CONSOLIDATED STATEMENT OF STOCKHOLDERS' DEFICIT (USD $)	Preferred Stock	Common Stock Par Value	Additional Paid-In Capital	Accumulated Deficit	Total
Balance, beginning at Dec. 31, 2010		$ 43,950	$ (237,338)	$ (95,650)	$ (289,038)
Balance, beginning, shares at Dec. 31, 2010		43,950,000
Discount on convertible notes			684,627		684,627
Shares issued for oil and gas property		50	40,450		40,500
Shares issued for oil and gas property, shares		50,000
Net loss for the period				(1,083,341)	(1,083,341)
Balance, ending at Dec. 31, 2011		44,000	487,739	(1,178,991)	(647,252)
Balance, ending, shares at Dec. 31, 2011		44,000,000			44,000,000
Relative Fair value of warrants issued with Debt			290,459
Common stock issued for conversion of debt and accrued interest		6,035	3,011,236
Common stock issued for conversion of debt and accrued interest, shares		6,034,542			6,034,542
Reclassification of derivative liability to additional paid-in capital due to conversion of related notes payable			4,493,670
Shares issued for services	1	305	30,195
Shares issued for services, shares	1,000	305,000
Net loss for the period				(6,077,652)	(6,077,652)
Balance, ending at Dec. 31, 2012	$ 1	$ 50,339	$ 8,313,299	$ (7,256,643)	$ 1,106,996
Balance, ending, shares at Dec. 31, 2012	1,000	50,339,542

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Reclassification

12 Months Ended

Dec. 31, 2012

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Reclassification

4.           Reclassification

In accordance with the SEC’s Staff Accounting Bulletin No. 108, “Considering the Effects of Prior Year Misstatements when Quantifying Misstatements in Current Year Financial Statements” (“SAB 108”), the Company recorded a reclassification adjustment  for year ended December 31, 2011 of $145,726 which served to reduce Administrative income, Lease operating expenses and General & Administrative expenses.  This non-cash adjustment resulted from incorrectly recognizing revenue for administrative income collected from third party working interest owners of properties that were partially owned by the Company.   As a result of the Company’s evaluation of this error under SAB 108, the Company determined that this error was not material in relation to the current year, but not material to the year ended December 31, 2011.  Consequently, the December 31, 2011 income statement was adjusted to reflect the correction of this error.  In evaluating materiality and determining the appropriateness of applying SAB 108 to this error, the Company considered materiality both qualitatively and quantitatively as prescribed by the SEC’s Staff Accounting Bulletin No. 99.  The following table reflects the impact of the above error to the consolidated statements of operations as of and for the year ended December 31, 2011:

Certain amounts disclosed in prior periods have been reclassified to conform to current presentation. Such reclassifications are for presentation purposes only and have no effect on the Company’s net loss or financial position in any of the periods presented.

A summary of these changes by category is as follows:

	December 31, 2011			Reclassification of Previously Reported Activity			Adjusted December 31, 2011
Oil and Gas sales		141,362						141,362
Well Operator Income		215,178			(145,726	)		69,452
TOTAL REVENUE		356,540			(145,726	)		210,814
OPERATING EXPENSES (INCOME)
Lease operating expenses		109,865			(46,476	)		63,389
Accretion expense		2,592						2,592
Depletion expense		19,225						19,225
General and administrative		922,628			(99,249	)		823,379
TOTAL OPERATING EXPENSES		1,054,310			(145,726	)		908,584
NET LOSS BEFORE OTHER EXPENSE		(697,770	)		-			(697,770	)
OTHER INCOME (EXPENSE)
Interest Expense		(289,291	)					(289,291	)
Gain (Loss) on embedded derivatives		(96,280	)					(96,280	)
NET INCOME		(1,083,341	)		-			(1,083,341	)

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Reclassification (Tables)

12 Months Ended

Dec. 31, 2012

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Reclassification

	December 31, 2011			Reclassification of Previously Reported Activity			Adjusted December 31, 2011
Oil and Gas sales		141,362						141,362
Well Operator Income		215,178			(145,726	)		69,452
TOTAL REVENUE		356,540			(145,726	)		210,814
OPERATING EXPENSES (INCOME)
Lease operating expenses		109,865			(46,476	)		63,389
Accretion expense		2,592						2,592
Depletion expense		19,225						19,225
General and administrative		922,628			(99,249	)		823,379
TOTAL OPERATING EXPENSES		1,054,310			(145,726	)		908,584
NET LOSS BEFORE OTHER EXPENSE		(697,770	)		-			(697,770	)
OTHER INCOME (EXPENSE)
Interest Expense		(289,291	)					(289,291	)
Gain (Loss) on embedded derivatives		(96,280	)					(96,280	)
NET INCOME		(1,083,341	)		-			(1,083,341	)

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Detachable Warrants (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Detachable Warrants Details
Number of Warrants, outstanding, beginning	2,185,000	2,185,000
Number of Warrants, issued	615,000
Number of Warrants, outstanding, ending	2,800,000	2,185,000
Number of Warrants, exercisable, ending	2,800,000
Weighted Average Exercise Price, outstanding, beginning	$ 1.00
Weighted Average Exercise Price, issued	$ 1.00
Weighted Average Exercise Price, outstanding, ending	1.00
Weighted Average Exercise Price, exercisable, ending	$ 1.00	$ 1.00
Weighted Average Remaining Contract Term, outstanding	3 years 6 months	3 years 7 months
Weighted Average Remaining Contract Term, exercisable	4 years 2 months
Weighted Average Remaining Contract Term, issued	3 years 7 months

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Asset Retirement Obligation

12 Months Ended

Dec. 31, 2012

Asset Retirement Obligation [Abstract]

Asset Retirement Obligation

14.            Asset Retirement Obligation 

The Company accounts for its future asset retirement obligations by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset.  The Company depletes the amount added to proved oil and gas property costs and gathering assets using the units-of-production method.  The Company’s asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties and gathering assets. The asset retirement liability is allocated to operating expense using a systematic and rational method. The information below reconciles the value of the asset retirement obligation for the periods presented.

	Year ended December 31, 2012		Year ended December 31, 2011
Beginning of the period	$	56,012	$	15,465
Liabilities incurred		9,790		37,955
Accretion expense		3,514		2,592
Balance at end of the period	$	69,316	$	56,012