UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K/A
Amendment No. 1

| x | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended: September 30, 2011

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

For the transition period from ____________ to _____________
Commission file number: 000-53683

(Exact name of registrant as specified in its charter)

Nevada |  | 26-0693872
(State or other jurisdiction of incorporation or organization) |  | (I.R.S. Employer Identification No.)

16 Market Square Center
1400 16th Street Suite 400
Denver, CO 80202
(Address of principal executive offices)
Tel: 720.932.8389
Registrant’s telephone number, including area code

Securities registered pursuant to Section 12(b) of the Exchange Act: None
Securities registered pursuant to Section 12(g) of the Exchange Act: Common Stock, $0.001 par value
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

[ ] | Yes | [X] | No

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

[ ] | Yes | [X] | No

Indicate by checkmark 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 [ ] 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). [X] Yes [ ] No
Indicate by checkmark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [X]

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

Large accelerated filer | [ ] |
Accelerated filer | [ ] |
Non-accelerated filer | [ ] | (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).
[ ] Yes [X] No
As of March 31, 2011, the aggregate market value of the shares of the registrant’s common stock held by non-affiliates was approximately $35,147,904. As of March 31, 2011, American Power’s stock was trading at $0.80 per share and the Company had 43,934,880 shares outstanding held by non-affiliates. Shares of the registrant’s common stock held by each executive officer and director and each by each person who owns 10% or more of the outstanding common stock have been excluded from the calculation in that such persons may be deemed to be affiliates of the registrant. This determination of affiliate status is not necessarily a conclusive determination for other purposes.
There were 96,429, 358 shares of the registrant’s common stock outstanding as of December 29, 2011.
DOCUMENTS INCORPORATED BY REFERENCE
None.

EXPLANATORY NOTE
American Power Corp. is filing this Amendment No. 1 to our Annual Report on Form 10-K for the year ended September 30, 2011, filed with the Securities and Exchange Commission on January 5, 2012 (the “Original Filing”), to make the following amendments:

| 1. | This Amendment includes supplemental information concerning the anticipated market prices for coal in the Powder River and Unita Basins. .

| 2. | This Amendment includes supplemental information concerning (i) the nature of the Company’s ownership in its properties, (ii) how such ownership was acquired, (iii) the material terms of the agreements securing the Company’s ownership, and (iv) the mineral characteristics of such properties.

| 3. | This Amendment provides a map showing the location and access of the Company’s properties.

| 4. | This Amendment provides a description of the permitting requirements for the development of the Company’s properties.

| 5. | This Amendment provides a description of the Company’s quality estimates concerning its mineral discoveries as well as the Quality Assurance/Quality Control protocols the Company has developed concerning its sample collection and preparation process.

| 6. | This Amendment updates certain information concerning the Company’s drilling plan and geological report being prepared by Weir International, Inc.

In addition to the corrections above, this Amendment also restates “Item 15. Exhibits, Financial Statement Schedules” to include corrected and currently dated certifications pursuant to Section 302 and Section 906 of the Sarbanes-Oxley Act of 2002, which are attached as Exhibits 31.1, 31.2, 32.1 and 32.2 to this Amendment No. 1.
The Original Filing has not been amended, updated or otherwise modified, to not reflect events occurring after January 5, 2012, the date of the Original Filing, or modify or update those disclosures that may have been affected by subsequent events.
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AMERICAN POWER CORPORATION
TABLE OF CONTENTS
Page

PART I | 4

| ITEM 1. | BUSINESS. | 4
| ITEM 1A. | RISK FACTORS. | 5
| ITEM 1B. | UNRESOLVED STAFF COMMENTS. | 12
| ITEM 2. | PROPERTIES | 12
| ITEM 3. | LEGAL PROCEEDINGS. | 13
| Item 4. | (Removed and Reserved) | 13
PART II |  | 14
| ITEM 5. | MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES. | 14
| ITEM 6. | SELECTED FINANCIAL DATA. | 14
| ITEM 7. | MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS. | 15
| ITEM 7A. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK. | 16
| ITEM 8. | FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA. | 16
| ITEM 9. | CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE. | 16
| ITEM 9A. | CONTROLS AND PROCEDURES | 16
| ITEM 9B. | OTHER INFORMATION | 17
PART III |  | 17
| ITEM 10. | DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE. | 17
| ITEM 11. | EXECUTIVE COMPENSATION. | 19
| Item 12. | SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS. | 20
| ITEM 13. | CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE. | 21
| ITEM 14. | PRINCIPAL ACCOUNTANT FEES AND SERVICES. | 21
PART IV |  | 22
| ITEM 15. | EXHIBITS, FINANCIAL STATEMENT SCHEDULES. | 22

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FORWARD-LOOKING STATEMENTS
This report contains forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control. All statements, other than statements of historical fact, contained in this report, including statements regarding future events, our future financial performance, business strategy and plans and objectives of management for future operations, are forward-looking statements. We have attempted to identify forward-looking statements by terminology including “anticipates,” “believes,” “can,” “continue,” “could,” “estimates,” “expects,” “intends,” “may,” “plans,” “potential,” “predicts,” “should” or “will” or the negative of these terms or other comparable terminology. Although we do not make forward-looking statements unless we believe we have a reasonable basis for doing so, we cannot guarantee their accuracy. These statements are only predictions and involve known and unknown risks, uncertainties and other factors, including the risks outlined under “Risk Factors” or elsewhere in this report, which may cause our or our industry’s actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by these forward-looking statements. Moreover, we operate in a very competitive and rapidly changing environment. New risks emerge from time to time and it is not possible for us to predict all risk factors, nor can we address the impact of all factors on our business or the extent to which any factor, or combination of factors, may cause our actual results to differ materially from those contained in any forward-looking statements. The factors affecting these risks and uncertainties include, but are not limited to:

● |  | estimated quantities and quality of coal, oil and natural gas reserves;
● |  | fluctuations in the price of coal, oil, and natural gas;
● |  | inability to efficiently manage our operations;
● |  | the inability of management to effectively implement our strategies and business plans;
● |  | potential default under our secured obligations or material debt agreements;
● |  | inability to hire or retain sufficient qualified personnel;
● |  | inability to attract and obtain additional development capital;
● |  | increases in interest rates or our cost of borrowing;
● |  | deterioration in general economic conditions;
● |  | the occurrence of natural disasters, unforeseen weather conditions, or other events or circumstances that could impact our operations or could impact the operations of companies or contractors we depend upon in our operations;
● |  | inability to achieve future sales levels or other operating results; and
● |  | changes in U.S. GAAP or in the legal, regulatory and legislative environments in the markets in which we operate.

You should not place undue reliance on any forward-looking statement, each of which applies only as of the date of this report. Except as required by law, we undertake no obligation to update or revise publicly any of the forward-looking statements after the date of this report to conform our statements to actual results or changed expectations.
AVAILABLE INFORMATION
We file annual, quarterly and other reports and other information with the SEC. You can read these SEC filings and reports over the Internet at the SEC’s website at www.sec.gov. You can also obtain copies of the documents at prescribed rates by writing to the Public Reference Section of the SEC at 100 F Street, NE, Washington, DC 20549 on official business days between the hours of 10:00 am and 3:00 pm. Please call the SEC at (800) SEC-0330 for further information on the operations of the public reference facilities. We will provide a copy of our annual report to security holders, including audited financial statements, at no charge upon receipt of a written request to us at American Power Corporation, 16 Market Square Center, 1400 16th Street Suite 400, Denver, CO 80202.
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INDUSTRY AND MARKET DATA
The market data and certain other statistical information used throughout this report are based on independent industry publications, government publications, reports by market research firms or other published independent sources. In addition, some data is based on our good faith estimates.
USE OF TERMS
Except as otherwise indicated by the context, all references in this report to “we,” “us,” “our,” the “Company,” “AMPW,” and “American Power” refer to American Power Corporation, unless the context requires otherwise. We report our financial information on the basis of a September 30 fiscal year end.
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PART I

ITEM 1. | BUSINESS.

Overview
The Company was incorporated in the State of Nevada as a for-profit company on August 7, 2007. At the time of our incorporation, we were incorporated under the name “Teen Glow Makeup, Inc.” and our original business plan was to create a line of affordable teen makeup for girls. On November 20, 2009, Johannes Petersen acquired the majority of the shares of our issued and outstanding common stock in accordance with two stock purchase agreements by and between Mr. Petersen and Ms. Pamela Hutchinson and Ms. Andrea Mizushima, respectively. On March 30, 2010, we changed our intended business purpose to that of coal, oil, and natural gas exploration, development and production.
Our current primary business focus is to acquire, explore and develop coal, oil and gas properties in the United States, with a particular focus on the Rocky Mountains region. On March 30, 2010, our Board of Directors approved the proposal to change the Company’s name and to effect a 340-for-1 forward stock split. The Certificate of Change for the forward stock split was filed and approved by the Nevada Secretary of State on April 28, 2010. Also on April 28, 2010, Articles of Amendment were filed and approved with the Nevada Secretary of State to change the name of the Corporation to American Power Corporation. The Articles of Amendment also changed the authorized amount of capital stock to Five Hundred Million (500,000,000) shares of Common Stock, par value $0.001.
Business Description and Plan of Operation
We have acquired certain coal and minerals rights located in the Judith Basin County, Montana, collectively described as the “PACE Coal Project.” These rights are speculative in nature and additional exploration work is required to determine their value. Our plan of operation is to explore the PACE Coal Project and acquire and explore new properties which we believe are prospective for coal and/or hydrocarbons. To December 2011, the Company had completed a total of 14,076 feet of drilling for all three phases of its exploration drilling program at the PACE Coal Project. All drill locations corresponding to Phases I and II had been fully completed while one drill location corresponding to Phase III had been completed. Drilling operations were suspended in December 2011 due to weather considerations and are expected to resume in the spring of 2012. The Company is currently evaluating the preparation of a reserve study and mining plan for the PACE Coal property with the existing project data. Although we have obtained encouraging preliminary results from the first two phases of the exploration drilling program at the PACE Coal Project, there can be no assurance that an economic coal and/or hydrocarbon reserve exists on the PACE Coal Project or on any other the exploration prospects we could eventually acquire.
Even if we complete our proposed exploration programs and are successful in identifying the presence of coal and/or hydrocarbons, we will have to spend substantial funds on further drilling, engineering studies, environmental and mine feasibility studies before we will know if we have a commercially viable coal, oil, and gas deposit or reserve.
Market Overview for Plan of Operation
Coal production in the United States in 2010 reached a level of 1,084.4 million short tons (811.9 million short tons between January and September of 2011) according to data from the Energy Information Administration (EIA), an increase of 0.9% from the 2009 level. Wyoming continued to be the largest coal-producing state with 442.5 million short tons, 2.6% higher than the 2009 level. By rank, bituminous coal represented 46.9% of total coal production in 2010, followed closely by subbituminous coal with 46.2%, while lignite and anthracite coal represented 6.7% and 0.2% of the total, respectively.
Coal consumption in the United States rebounded in 2010, reaching a level of 1,051.3 million short tons (497.5 million short tons between January and June of 2011), an increase of 5.1% from the 2009 level, with all coal-consuming sectors, except commercial and institutional users, having higher consumption for the year. The 2010 increase in consumption, over 2009, restored about 40% of the previous drop in consumption in 2009 from 2008 levels. The electric power sector (electric utilities and independent power producers), which consumes about 93% of all coal in the US, is the overriding force for determining total domestic coal consumption. In 2010, the turnaround in the economy led to a large increase in coal consumption for the sector. Coal consumption in the electric power sector increased 4.4% to end 2010 at 975.1 million short tons (458.8 million short tons between January and June of 2011), while coal-based electricity generation in kilowatt hours increased at a slightly higher rate of 5.2%. The higher rate of production growth occurred because power plants consumed more high-Btu bituminous coal purchased from the Interior production region and out of stocks in areas predominantly burning bituminous coal to generate electricity. Coal consumption in the non-electric power sector (comprised of other industrial, coking coal, and the commercial and institutional sectors) increased in 2010 as the economy rebounded. Coal consumption at coke plants increased by 37.6% to end 2010 at 21.1 million short tons (10.6 million short tons between January and June of 2011).
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Total coal stocks fell to 233.6 million short tons at the end of 2010, compared to 244.8 million short tons at the end of 2009. Except for 2009 when stocks were slightly higher, the 2010 stocks surpassed stocks in all years dating back to 1980.
In 2010, most domestic coal prices continued to increase, rising for the seventh consecutive year. The majority of coal sold in the electric power sector is through long-term contracts (covering a time period of one year or longer), in conjunction with spot purchases to supplement the demand. As contracts expire and are renegotiated the prevailing spot price influences the contract price. According to preliminary data for 2010, coal prices at electric utilities (a subset of the electric power sector) increased for a tenth consecutive year, to $45.09 per short ton, an increase of 1.4% over the 2009 price, as compared to the previous year when these prices increased by 8.3%. Coal prices at independent power producers for 2010 increased to $41.49 per short ton, an increase of 3.9%. The average delivered price of coal to the other industrial sector decreased by 1.0% to an average price of $64.24 per short ton in 2010. In 2010, the delivered price of coal to US coke plants increased by 7.4% to reach an average price of $153.59 per short ton. The average delivered price of coal to the commercial and institutional sector fell in 2010 by 9.1% to $88.42 per short ton.
According to data for 2010, domestic coal prices averaged $35.61 per short ton. By coal rank, the average price in 2010 for bituminous coal was $60.88 per short ton, $14.11 per short ton for subbituminous coal, $18.76 per short ton for lignite coal and $59.51 per short ton for anthracite coal.
Western Region (includes Montana)
The Western Region is the largest coal–producing region in the US. In 2010, coal production increased by 1.1% to a total of 591.6 million short tons (429.4 million short tons between January and September 2011). Even with the increase in production, the production level was still below the 2008 level of 633.6 million short tons.
In 2010, Montana, the second largest coal–producing state in the Western region, produced a total of 44.7 million short tons (29.8 million short tons between January and September 2011), an increase of 13.3% or 5.2 million short tons from the 2009 level. A total of six mines in Montana produced 44.4 million short tons of subbituminous coal and 0.3 million short tons of lignite coal in 2010. Three mines had large increases in coal production in 2010, which were more than enough to offset the decrease of 1.5 million short tons at Decker Coal Company’s Decker mine. Spring Creek Coal’s Spring Creek mine had an increase of 1.7 million short tons, Western Energy’s Rosebud mine had an increase of 1.9 million short tons and Signal Peak Energy’s Bull Mountain No. 1 mine had an increase of 3.6 million short tons.
According to data from the U.S. Energy Information Administration (EIA), domestic coal prices in 2010 averaged $35.63 per short ton. By coal rank, the average price in 2010 for bituminous coal was $60.56 per short ton, $13.99 per short ton for subbituminous coal, $18.47 per short ton for lignite coal and $60.56 per short ton for anthracite coal.
The following chart shows the average market price by coal rank for the period 2006–2010:
Due to its characteristics (i.e., bituminous coal, high energy content and sulfur content), we consider the coal in the PACE Coal property to be more comparable to the Illinois Basin coal. According to the EIA, the Illinois Basin coal price (11,800 Btu, 5.0 SO2) was $49.50 per short ton on April 27, 2012.
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Internationally, Atlantic prices have declined as high European imports through the first half of 2011, combined with the warm Northern Hemisphere winter and falling industrial production, have left power plants with ample inventory. At the same time, the U.S. domestic market’s depression exacerbated the supply–side issues in the form of increased U.S. exports and decreased U.S. imports. This freed up additional tonnage from Colombia, as it exported almost 4.5Mt less coal to the U.S. in 2011 than 2010. China and India will likely be the key drivers of the global seaborne market, where robust electricity generation continues to drive strong thermal coal demand. We anticipate thermal coal prices to normalize over the course of 2012, gradually moving higher as inventories are worked down and the lingering effects of the warm Northern Hemisphere winter slowly drop out of the market. Beyond 2012, we expect prices to continue their steady upward trajectory in nominal terms as rising costs justify increasing prices.
Upon completion of the final reserve and mine feasibility studies, we will consider commissioning a market study to determine the relevant market price for our coal as well as the impact of transportation costs, access to ports and export facilities, among other variables, on the final sale price for both domestic and overseas markets.
Government Approvals
The Company requires to obtain drilling permits from the Montana Department of Environmental Quality in order to carry out drilling operations on its PACE Coal Project. In 2011, the Company received drilling permits that allowed it to carry out exploration activities on the project. Further drilling, or modifications to our drilling plan will require modification of our drilling permits by the Montana Department of Environmental Quality. The Company would also require additional permits from the state and federal governments once it moves, if at all, to the development and mining phase of the project.
Existing or Probable Governmental Regulations
Federal, state and local authorities regulate the U.S. coal mining industry with respect to matters such as employee health and safety, permitting and licensing requirements, air quality standards, water pollution, plant and wildlife protection, reclamation and restoration of mining properties after mining has been completed, discharge of materials into the environment, surface subsidence from underground mining and the effects of mining on groundwater quality and availability. Numerous federal, state and local governmental permits and approvals are required for coal mining activities.
We comply with all relevant government regulations at the federal, state and local level. We believe that we have obtained all permits currently required to conduct our mining exploration activities. We do not believe there are any matters that pose a material risk to maintaining our existing permits or that materially hinder our ability to secure future permits.
If we are able to move forward with the development and eventual operation of the Pace Coal Project, we would be subject to the following regulatory requirements.
Mine Safety and Health. Companies are subject to health and safety standards both at the federal and state level. The regulations are comprehensive and affect numerous aspects of mining operations, including training of mine personnel, mining procedures, blasting, the equipment used in mining operations and other matters. The Mine Safety and Health Administration (MSHA) is the agency responsible for monitoring compliance with the federal mine health and safety standards. MSHA has various enforcement tools that it can use, including the issuance of monetary penalties and orders of withdrawal from a mine or part of a mine. MSHA has recently taken a number of actions to identify mines with safety issues, and has engaged in targeted enforcement, awareness, outreach and rulemaking activities to reduce the number of mining fatalities, accidents and illnesses. There has also been an industry–wide increase in the monetary penalties assessed for citations of a similar nature.
Black Lung. Under the Black Lung Benefits Revenue Act of 1977 and the Black Lung Benefits Reform Act of 1977, as amended in 1981, each U.S. coal mine operator must pay federal black lung benefits and medical expenses to claimants who are current and former employees and last worked for the operator after July 1, 1973. Coal mine operators must also make payments to a trust fund for the payment of benefits and medical expenses to claimants who last worked in the coal industry prior to July 1, 1973. Historically, less than 7% of the miners currently seeking federal black lung benefits are awarded these benefits. The trust fund is funded by an excise tax on U.S. production of up to $1.10 per ton for deep–mined coal and up to $0.55 per ton for surface–mined coal, neither amount to exceed 4.4% of the gross sales price.
Environmental Laws. Coal companies are subject to various federal and state environmental laws. Some of these laws, discussed below, would place many requirements on any future coal mining operation. Federal and state regulations require regular monitoring of mines and other facilities to ensure compliance.
Surface Mining Control and Reclamation Act. In the U.S., the Surface Mining Control and Reclamation Act of 1977 (SMCRA), which is administered by the Office of Surface Mining Reclamation and Enforcement (OSM), established mining, environmental protection and reclamation standards for all aspects of U.S. surface mining as well as many aspects of deep mining. Mine operators must obtain SMCRA permits and permit renewals for mining operations from the OSM. Where state regulatory agencies have adopted federal mining programs under SMCRA, the state becomes the regulatory authority.
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The Abandoned Mine Land Fund, which is part of SMCRA, requires a fee on all coal produced in the U.S. The proceeds are used to rehabilitate lands mined and left unreclaimed prior to August 3, 1977 and to pay health care benefit costs of orphan beneficiaries of the Combined Fund created by the Coal Industry Retiree Health Benefit Act of 1992. The fee was $0.35 per ton of surface–mined coal and $0.15 per ton of deep–mined coal, effective through September 30, 2007. Pursuant to the Tax Relief and Health Care Act of 2006, from October 1, 2007 through September 30, 2012, the fee is $0.315 per ton of surface–mined coal and $0.135 per ton of underground mined coal. From October 1, 2012 through September 30, 2021, the fee will be reduced to $0.28 per ton of surface–mined coal and $0.12 per ton of underground-mined coal. SMCRA stipulates compliance with many other major environmental programs. These programs include the Clean Air Act; Clean Water Act; Resource Conservation and Recovery Act (RCRA); and Comprehensive Environmental Response, Compensation, and Liability Acts (CERCLA, commonly known as Superfund). Besides OSM, other federal regulatory agencies are involved in monitoring or permitting specific aspects of mining operations. The U.S. Environmental Protection Agency (EPA) is the lead agency for states or tribes with no authorized programs under the Clean Water Act, RCRA and CERCLA. The U.S. Army Corps of Engineers regulates activities affecting navigable waters and waters of the U.S., including wetlands, and the U.S. Bureau of Alcohol, Tobacco and Firearms regulates the use of explosive blasting materials.
Clean Air Act. The Clean Air Act and the comparable state laws that regulate the emissions of materials into the air affect U.S. coal mining operations both directly and indirectly. Direct impacts on coal mining and processing operations may occur through the Clean Air Act permitting requirements and/or emission control requirements relating to particulate matter. It is possible that the more stringent national ambient air quality standards (NAAQS) will directly impact future mining operations by, for example, requiring additional controls of emissions from mining equipment and vehicles. In addition, in September 2009, the EPA adopted new rules tightening and adding additional particulate-matter emissions limits for coal preparation and processing plants constructed, reconstructed or modified after April 28, 2008. The Clean Air Act indirectly, but more significantly, affects the coal industry by extensively regulating the air emissions of sulfur dioxide, nitrogen oxides, mercury, particulate matter and other substances emitted by coal–based electricity generating plants. Air emissions programs that may affect future operations, directly or indirectly, include, but are not limited to, the Acid Rain Program, NOx SIP Call, the Clean Air Interstate Rule (CAIR), New Source Performance Standards (NSPS), Maximum Achievable Control Technology (MACT) emissions limits for Hazardous Air Pollutants, the Regional Haze program and New Source Review. In addition, in recent years, the EPA has adopted more stringent NAAQS for particulate matter, nitrogen oxide and sulfur dioxide. The EPA has also proposed a more stringent ozone standard but withdrew it last year; the ozone standard is due for reconsideration in 2013. Many of these programs and regulations have resulted in litigation, which has not been completely resolved.
On July 6, 2011, the EPA finalized its final Cross State Air Pollution Rule (CSAPR) to address interstate transport of emissions from coal–based electrical generation plants. The rule, which was developed to replace CAIR and includes a supplemental rulemaking finalized on December 15, 2011, imposes state–by–state budgets on nitrogen oxides and sulfur dioxide emissions from coal–based electrical generation plants in 23 states from Texas eastward (not including the New England states or Delaware) and provides for an allowance trading program to meet those budgets. While CSAPR has an initial compliance deadline of January 1, 2012, the rule was challenged and, on December 30, 2011, the U.S. Court of Appeals for the District of Columbia stayed CSAPR and advised that the EPA is expected to continue administering CAIR until the pending challenges are resolved. Expedited briefing on the merits of the challenge is underway. On December 16, 2011, the EPA issued the Mercury and Air Toxic Standards, which impose MACT emission limits on hazardous air emissions from new and existing coal–based electric generating plants. The rule also revised NSPS for nitrogen oxides, sulfur dioxides and particulate matter for coal–based electricity generating plants. The rule provides three years for compliance, or up to four years for existing sources if necessary. In December 2009, the EPA published its finding that atmospheric concentrations of greenhouse gases endanger public health and welfare within the meaning of the Clean Air Act, and that emissions of greenhouse gases from new motor vehicles and new motor vehicle engines are contributing to air pollution that is endangering public health and welfare within the meaning of the Clean Air Act. In May 2010, the EPA published final greenhouse gas emission standards for new motor vehicles pursuant to the Clean Air Act. Both the endangerment finding and motor vehicle standards are the subject of litigation.
Because the Clean Air Act specifies that the prevention of significant deterioration (PSD) program applies once emissions of regulated pollutants exceed either 100 or 250 tons per year (depending on the type of source), millions of sources previously unregulated under the Clean Air Act could be subject to greenhouse gas reduction measures. The EPA published a rule in June 2010 to limit the number of greenhouse gas sources that would be subject to the PSD program. In the so–called “tailoring rule,” the EPA limited the regulation of greenhouse gases from certain stationary sources to those that emit more than 75,000 tons of greenhouse gases per year (for sources that would be subject to PSD permitting regardless of greenhouse gas emissions due to other emissions) or 100,000 tons of greenhouse gases per year (for sources not subject to PSD permitting for any other air emissions), measured by “carbon dioxide equivalent.” Whether the EPA has the statutory authority under the Clean Air Act to adopt the tailoring rule is the subject of litigation. In December 2010, the EPA announced a settlement with states and environmental groups that had filed litigation challenges to the EPA’s decisions not to establish greenhouse gas emission standards for fossil fuel–fired power plants and for petroleum refineries under section 111 of the Clean Air Act. In the settlement, the EPA agreed (1) to sign proposed new source performance standards for new and modified electric utility steam generating units under section 111(b), as well as proposed guidelines for states’ development of emission standards for existing electric utility steam generating units under section 111(d), by July 26, 2011; and (2) to take final action on the proposed section 111(b) standards and section 111(d) guidelines by May 26, 2012. The EPA has not yet proposed these rules. Whatever the EPA determines the new source performance standards to be, this will then be the minimum requirement for best available control technology requirements under the PSD program.
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Clean Water Act. The Clean Water Act of 1972 affects U.S. coal mining operations by requiring both technology–based and, if necessary, water quality–based effluent limitations and treatment standards for wastewater discharge through the National Pollutant Discharge Elimination System (NPDES). Regular monitoring, reporting requirements and performance standards are requirements of NPDES permits that govern the discharge of pollutants from mine–related point sources into water. Section 404 of the Clean Water Act requires mining companies to obtain U.S. Army Corps of Engineers permits to place material in streams for the purpose of creating slurry ponds, water impoundments, refuse areas, valley fills or other mining activities. States are empowered to develop and apply “in stream” water quality standards. These standards are subject to change and must be approved by the EPA. Discharges must either meet state water quality standards or be authorized through available regulatory processes such as alternate standards or variances. “In stream” standards vary from state to state. Additionally, through the Clean Water Act section 401 certification program, states have approval authority over federal permits or licenses that might result in a discharge to their waters. States consider whether the activity will comply with their water quality standards and other applicable requirements in deciding whether or not to certify the activity.
Resource Conservation and Recovery Act. RCRA, which was enacted in 1976, affects U.S. coal mining operations by establishing “cradle to grave” requirements for the treatment, storage and disposal of hazardous wastes. Typically, the only hazardous wastes generated at a mine site are those from products used in vehicles and for machinery maintenance. Coal mine wastes, such as overburden and coal cleaning wastes, are not considered hazardous wastes under RCRA. Subtitle C of RCRA exempted fossil fuel combustion wastes from hazardous waste regulation until the EPA completed a report to Congress and made a determination on whether the wastes should be regulated as hazardous. In a 1993 regulatory determination, the EPA addressed some high volume–low toxicity coal combustion materials generated at electric utility and independent power producing facilities. In May 2000, the EPA concluded that coal combustion materials do not warrant regulation as hazardous wastes under RCRA. The EPA has retained the hazardous waste exemption for these materials. The EPA is evaluating national waste guidelines for coal combustion materials placed at a mine. National guidelines for mine–fills may affect the cost of ash placement at mines. The EPA revisited its May 2000 determination and proposed new requirements for coal combustion residue (CCR) management on June 21, 2010. That proposal contains two options: (1) to continue to regulate CCR as a non–hazardous waste, or (2) to regulate CCR as special waste under the hazardous waste regulations.
CERCLA (Superfund). CERCLA affects U.S. coal mining and hard rock operations by creating liability for investigation and remediation in response to releases of hazardous substances into the environment and for damages to natural resources. Under CERCLA, joint and several liability may be imposed on waste generators, site owners or operators and others, regardless of fault. Under the EPA’s Toxic Release Inventory process, companies are required annually to report the use, manufacture or processing of listed toxic materials that exceed defined thresholds, including chemicals used in equipment maintenance, reclamation, water treatment and ash received for mine placement from power generation customers.
Endangered Species Act. The U.S. Endangered Species Act and counterpart state legislation is intended to protect species whose populations allow for categorization as either endangered or threatened. With respect to obtaining mining permits, protection of endangered or threatened species may have the effect of prohibiting, limiting the extent or causing delays that may include permit conditions on the timing of soil removal, timber harvesting, road building and other mining or agricultural activities in areas containing the affected species.
Use of Explosives. Surface mining operations are subject to numerous regulations relating to blasting activities. The storage of explosives is also subject to federal regulatory requirements.
Number of Employees
The Company has no employees and three consultants (of which two, Mr. Johannes Petersen and Mr. Alvaro Valencia, are directors).

ITEM 1A. | RISK FACTORS.

We operate in a highly competitive environment in which there are numerous factors which can influence our business, financial position, or results of operations and which can also cause the market value of our common stock to decline. Many of these factors are beyond our control and therefore, are difficult to predict. The following section sets forth what we believe to be the principal risks that could affect us, our business or our industry, and which could result in a material adverse impact on our financial results or cause the market price of our common stock to fluctuate or decline.
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RISKS ASSOCIATED WITH OUR BUSINESS
We have no history of revenues from operations, we may never operate profitably and investors may lose all of their investment in our company.
We have no history of revenues from operations. We are an exploration stage company with only a limited operating history upon which to base an evaluation of our current business and future prospects. Further, we do not have an established history of locating and developing mineral and oil and gas properties. As a result, the revenue and income potential of our business is unproven and there can be no assurance that we will ever operate profitably. The exploration and development of mineral properties requires substantial capital, often over a substantial period of time. We anticipate that we will incur increased operating expenses without realizing any revenues over the next several years. We therefore expect to incur significant losses into the foreseeable future. If we are unable to successfully develop the PACE Coal Property or other properties we acquire in the future, we will not be able to establish revenues, earn profits, or continue operations, and our stock may become worthless, causing our investors to lose all of their investment in our company.
We currently own rights with respect to a sole mineral property.
The PACE Coal Project is currently our sole project. The agreements under which we acquired the PACE property require us to make future payments to the sellers of the property, which payment obligations are secured by the property, and complete a reserve study and mining plan by April 2012. If we are unable to make these payments or complete these other obligations, we may lose our interest in the property. The Company plans to evaluate all available exploration data to delineate the extent of the potential resources, estimate their recoverability, and determine requirements for additional exploration and analytical testing. The Company is currently evaluating the preparation of a reserve study and mining plan for the PACE Coal property with the existing project data.
We are subject to all of the risks inherent in the mining industry.
As an exploration stage company, our work is highly speculative and involves unique and greater risks than are generally associated with other businesses. There can be no assurance that the PACE Coal Project or any the properties we acquire contain or will contain a commercially viable ore body or reserves until additional exploration work is done and an evaluation based on such work concludes that development of and production from the ore body is technically, economically, and legally feasible. We are subject to all of the risks inherent in the mining industry, including, without limitation, the following (some of which we discuss in more detail below):

● |  | Success in discovering and developing commercially viable quantities of minerals is the result of a number of factors, including the quality of management, the interpretation of geological data, the level of geological and technical expertise, and the quality of land available for exploration;
● |  | Exploration for minerals is highly speculative and involves substantial risks, even when conducted on properties known to contain significant quantities of mineralization, and most exploration projects do not result in the discovery of commercially mineable deposits of ore;
● |  | Operations are subject to a variety of existing laws and regulations relating to exploration and development, permitting procedures, safety precautions, property reclamation, employee health and safety, air and water quality standards, pollution and other environmental protection controls, all of which are subject to change and are becoming more stringent and costly to comply with;
● |  | A large number of factors beyond our control, including fluctuations in metal prices and production costs, inflation, the proximity and liquidity of precious metals markets and processing equipment, government regulations, including regulations relating to prices, taxes, royalties, land tenure, land use, importing and exporting of minerals, and environmental protection, and other economic conditions, will affect the economic feasibility of mining;
● |  | Once mineralization is discovered, it may take several years from the initial phases of drilling until production is possible, during which time the economic feasibility of production may change;
● |  | Substantial expenditures are required to establish proven and probable ore reserves through drilling, to determine metallurgical processes to extract the metals from the ore and, in the case of new properties, to construct mining and processing facilities; and
● |  | If we proceed to development of a mining operation, our mining activities would be subject to substantial operating risks and hazards, including metal bullion losses, environmental hazards, industrial accidents, labor disputes, encountering unusual or unexpected geologic formations or other geological or grade problems, encountering unanticipated ground or water conditions, cave-ins, pit-wall failures, flooding, rock falls, periodic interruptions due to inclement weather conditions or other unfavorable operating conditions and other acts of God. Some of these risks and hazards are not insurable or may be subject to exclusion or limitation in any coverage which we obtain or may not be insured due to economic considerations.

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Loss of key personnel and failure to attract qualified managers, technologists, independent engineers, and geologists could limit our growth and negatively impact our operations.
We depend upon our consultants to a substantial extent. In particular, we depend upon Mr. Alvaro Valencia, our President and Chief Executive Officer, and Mr. Johannes Petersen, our Secretary and Chief Financial Officer, for their skills, experience, knowledge of the company, and industry contacts. The loss of Mr. Valencia or Mr. Petersen could have a material adverse effect on our business, results of operations or financial condition.
As we grow, we may increasingly require field managers with experience in our industry and skilled engineers, geologists, and technologists to operate diagnostic, seismic, and 3D equipment. It is impossible to predict the availability of qualified managers, technologists, skilled engineers, and geologists or the compensation levels that will be required to hire them. In particular, there is a very high demand for qualified technologists who are particularly necessary to operate systems similar to the ones that we intend to operate. We may not be able to hire and retain a sufficient number of technologists, engineers, and geologists and we may be required to pay bonuses and higher independent contractor rates to our technologists, engineers, and geologists, which would increase our expenses. The loss of the services of any member of our senior management or our inability to hire qualified managers, technologists, skilled engineers, and geologists at economically reasonable compensation levels could adversely affect our ability to operate and grow our business.
Complying with federal and state regulations is an expensive and time-consuming process, and any failure to comply could result in substantial penalties.
Our exploration efforts are directly or indirectly subject to extensive and continually changing regulation affecting mining and the oil and natural gas industry. Many departments and agencies, both federal and state, are authorized by statute to issue, and have issued, rules and regulations binding on the mining and oil and natural gas industry and our individual participants. The failure to comply with such rules and regulations can result in substantial penalties. The regulatory burden on the mining and oil and natural gas industry increases our cost of doing business and, consequently, will affect our profitability.
If operations on the properties we acquire are found to be in violation of any of the laws and regulations to which we are subject, we may be subject to the applicable penalties associated with the violation, including civil and criminal penalties, damages, fines, and the curtailment of operations. Any penalties, damages, fines, or curtailment of operations, individually or in the aggregate, could adversely affect our ability to operate our business and our financial results. In addition, many of these laws and regulations have not been fully interpreted by the regulatory authorities or the courts, and their provisions are open to a variety of interpretations. Any action against us for violation of these laws or regulations, even if we successfully defend against it, could cause us to incur significant legal expenses and divert management’s attention from the operation of our business.
We may experience competition from other mining and energy exploration and production companies, and this competition could adversely affect our revenues and our business.
The market for coal, oil, and natural gas properties is generally highly competitive. Many existing competitors, as well as potential new competitors, have longer operating histories, greater name recognition, substantial track records, and significantly greater financial, technical, and technological resources than us. This may allow them to devote greater resources to the development and promotion of their coal, oil, and natural gas exploration and production projects. Many of these competitors offer a wider range of coal, oil, and natural gas opportunities not available to us and may attract business partners, consequently resulting in a decrease of our business opportunities. These competitors may also engage in more extensive research and development, adopt more aggressive strategies and make more attractive offers to existing and potential purchasers and partners. Furthermore, competitors may develop technology and exploration strategies that are equal or superior to us and achieve greater market recognition. In addition, current and potential competitors have established or may establish cooperative relationships among themselves or with third parties to better address the needs of our target market. As a result, it is possible that new competitors may emerge and rapidly acquire significant market share.
There can be no assurance that we will be able to compete successfully against our current or future competitors or that competition will not have a material adverse effect on our business, results of operations and financial condition.
We will need to increase the size of our organization, and may experience difficulties in managing growth.
We expect to experience a period of significant expansion in headcount, facilities, infrastructure, and overhead and anticipate that further expansion will be required to address potential growth and market opportunities. Future growth will impose significant added responsibilities on members of management, including the need to identify, recruit, maintain, and integrate additional independent contractors and managers. Our future financial performance and our ability to compete effectively will depend, in part, on our ability to manage any future growth effectively.
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Coal, oil and natural gas prices are volatile, and low prices could have a material adverse impact on our business.
Our growth and future profitability and the carrying value of our properties depend substantially on prevailing coal, oil, and natural gas prices. Prices also affect the amount of cash flow available for capital expenditures, if any, and our ability to borrow and raise additional capital. The amount we will be able to borrow under any credit facility will be based in part on changing expectations of future prices. Lower prices may also reduce the amount of coal, oil, and natural gas that we can economically produce and have an adverse effect on the value of our properties. Prices for coal, oil, and natural gas have increased significantly and have been more volatile over the past twelve months. Historically, the markets for coal, oil, and natural gas have been volatile, and they are likely to continue to be volatile in the future. Among the factors that can cause volatility are:

● |  | the domestic and foreign supply of coal, oil, and gas;
● |  | the ability of members of the Organization of Petroleum Exporting Countries, or OPEC, and other producing countries to agree upon and maintain oil prices and production levels;
● |  | the level of consumer product demand;
● |  | the growth of consumer product demand in emerging markets, such as China and India;
● |  | labor unrest in coal, oil, and natural gas producing regions;
● |  | weather conditions, including hurricanes and other natural disasters;
● |  | the price and availability of alternative fuels;
● |  | the price of foreign imports; and
● |  | worldwide economic conditions.

These external factors and the volatile nature of the energy markets make it difficult to estimate future prices of coal, oil, and natural gas and our resulting ability to raise capital.
Assets we acquire may prove to be worth less than we paid because of uncertainties in evaluating recoverable reserves and potential liabilities.
Our initial growth is expected to result from acquisitions of mineral and oil and gas properties. Successful acquisitions require an assessment of a number of factors, including estimates of recoverable reserves, exploration potential, future energy prices, operating and capital costs, and potential environmental and other liabilities. Such assessments are inexact and their accuracy is inherently uncertain. Typically, we acquire interests in properties on an “as is” basis with limited remedies for breaches of representations and warranties.
As a result of these factors, we may not be able to acquire coal, oil, and natural gas properties that contain economically recoverable reserves or be able to complete such acquisitions on acceptable terms.
Actual future production, coal, oil, and natural gas prices, revenues, taxes, development expenditures, operating expenses, and quantities of recoverable coal, oil, and natural gas reserves will vary from those estimated. Any significant variance could materially affect the estimated quantities and the value of any potential reserves.
Exploration and development drilling efforts may not be successful.
We require significant amounts of undeveloped leasehold acreage in order to further our development efforts. Exploration, development, drilling, and production activities are subject to many risks, including the risk that commercially productive reservoirs will not be discovered. We invest in property, including undeveloped leasehold acreage, which we believe will result in projects that will add value over time. However, we cannot guarantee that all of our prospects will result in viable projects or that we will not abandon our initial investments. Additionally, we cannot guarantee that the leasehold acreage we acquire will be profitably developed, that new wells drilled on the properties will be productive or that we will recover all or any portion of our investment in such leasehold acreage, mines, or wells. Drilling for oil and natural gas may involve unprofitable efforts, not only from dry wells but also from wells that are productive but do not produce sufficient net reserves to return a profit after deducting operating and other costs. We rely to a significant extent on 3D seismic data and other advanced technologies in identifying leasehold acreage prospects and in determining whether or not to participate in a new well. The 3D seismic data and other technologies we use do not allow us to know conclusively prior to acquisition of leasehold acreage or the drilling of a well whether oil or natural gas is present or may be produced economically.
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The unavailability or high cost of drilling rigs, equipment, supplies, personnel, and energy field services could adversely affect our ability to execute our exploration and development plans on a timely basis and within our budget.
Our industry is cyclical and, from time to time, there is a shortage of drilling rigs, equipment, supplies, or qualified personnel to operate our properties. During these periods, the costs and delivery times of rigs, equipment, and supplies are substantially greater. In addition, the demand for, and wage rates of, qualified drilling rig crews rise as the number of active rigs in service increases. As a result of increasing levels of exploration and production in response to strong prices of oil and natural gas, the demand for oilfield services has risen, and the costs of these services are increasing, while the quality of these services may suffer. If the unavailability or high cost of drilling rigs, equipment, supplies, or qualified personnel is particularly severe in Colorado and Montana, we could be materially and adversely affected because we expect our properties to be concentrated in those states.
Title to the properties in which we have, or will have, an interest in may be impaired by title defects.
We seek to confirm the validity of our rights to title to, or contract rights with respect to, each mineral property in which we have a material interest. Title insurance generally is not available, and our ability to ensure that we have obtained a secure claim to individual mineral properties or mining concessions is limited. We generally do not conduct surveys of our properties until they have reached the development stage, and therefore, the precise area and location of such properties could be in doubt. Accordingly, our mineral properties could be subject to prior unregistered agreements, transfers or claims, and title could be affected by, among other things, undetected defects. In addition, we might be unable to operate our properties as permitted or to enforce our rights with respect to our properties. Generally, under the terms of the operating agreements affecting our properties, any monetary loss is to be borne by all parties to any such agreement in proportion to their interests in such property. If there are any title defects or defects in the assignment of rights in properties in which we hold an interest, we will suffer a financial loss.
Our decision to acquire a property will depend in part on the evaluation of data obtained from engineering studies, geophysical and geological analyses, and seismic and other information, the results of which are often incomplete or inconclusive.
Our reviews of acquired properties may be inherently incomplete because it is not always feasible to perform an in-depth review of the individual properties involved in each acquisition. Even a detailed review of records and properties may not necessarily reveal existing or potential problems, nor will it permit a buyer to become sufficiently familiar with the properties to assess fully their deficiencies and potential. Inspections may not always be performed on every well and environmental problems, such as ground water contamination, plugging, or orphaned well liability are not necessarily observable even when an inspection is undertaken.
We are subject to complex laws and regulations, including environmental regulations, which can adversely affect the cost, manner, or feasibility of doing business.
The exploration and development of mineral and natural gas and oil properties in the United States is subject to extensive laws and regulations, including environmental laws and regulations. We may be required to make large expenditures to comply with environmental and other governmental regulations. Matters subject to regulation include, but are not limited to:

● |  | location and density of wells;
● |  | the handling of drilling fluids and obtaining discharge permits for drilling operations;
● |  | accounting for and payment of royalties on production from state, federal, and Indian lands;
● |  | bonds for ownership, development, and production of coal, natural gas, and oil properties;
● |  | transportation of natural gas and oil by pipelines;
● |  | operation of wells and reports concerning operations; and
● |  | taxation.

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Under these laws and regulations, we could be liable for personal injuries, property damage, oil spills, discharge of hazardous materials, remediation and clean-up costs, and other environmental damages. Failure to comply with these laws and regulations also may result in the suspension or termination of our operations and subject us to administrative, civil, and criminal penalties. Moreover, these laws and regulations could change in ways that substantially increase our costs. Accordingly, any of these liabilities, penalties, suspensions, terminations, or regulatory changes could materially adversely affect our financial condition and results of operations enough to possibly force us to cease our business operations.
RISKS ASSOCIATED WITH OUR COMMON STOCK
The price of our common stock may be volatile and you may not be able to resell your shares at a favorable price.
Regardless of whether an active trading market for our common stock develops, the market price of our common stock may be volatile and you may not be able to resell your shares at or above the price you paid for such shares. The following factors could affect our stock price:

● |  | our operating and financial performance and prospects;
● |  | quarterly variations in the rate of growth of our financial indicators, such as net income per share, net income, and revenues;
● |  | changes in revenue or earnings estimates or publication of research reports by analysts about us or the coal exploration and production industry;
● |  | potentially limited liquidity;
● |  | actual or anticipated variations in our reserve estimates and quarterly operating results;
● |  | changes in coal, natural gas, and oil prices;
● |  | sales of our common stock by significant stockholders and future issuances of our common stock;
● |  | increases in our cost of capital;
● |  | changes in applicable laws or regulations, court rulings, and enforcement and legal actions;
● |  | commencement of or involvement in litigation;
● |  | changes in market valuations of similar companies;
● |  | additions or departures of key management personnel;
● |  | general market conditions, including fluctuations in and the occurrence of events or trends affecting the price of natural gas and oil; and
● |  | domestic and international economic, legal, and regulatory factors unrelated to our performance.

We have no plans to pay dividends on our common stock.
We do not anticipate paying any cash dividends on our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to finance the expansion of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our business, financial condition, results of operations, capital requirements, investment opportunities, and restrictions imposed by our debentures and credit facility.
Because our common stock is deemed a “penny stock,” an investment in our common stock should be considered high risk and subject to marketability restrictions.
Since our common stock is a penny stock, as defined in Rule 3a51-1 under the Securities Exchange Act, it will be more difficult for investors to liquidate their investment even if and when a market develops for the common stock. Until the trading price of the common stock rises above $5.00 per share, if ever, trading in the common stock is subject to the penny stock rules of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) specified in Rules 15g-1 through 15g-10. Those rules require broker-dealers, before effecting transactions in any penny stock, to:
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● |  | Deliver to the customer, and obtain a written receipt for, a disclosure document;
● |  | Disclose certain price information about the stock;
● |  | Disclose the amount of compensation received by the broker-dealer or any associated person of the broker-dealer;
● |  | Send monthly statements to customers with market and price information about the penny stock; and
● |  | In some circumstances, approve the purchaser’s account under certain standards and deliver written statements to the customer with information specified in the rules.

Consequently, the penny stock rules may restrict the ability or willingness of broker-dealers to sell the common stock and may affect the ability of holders to sell their common stock in the secondary market and the price at which such holders can sell any such securities. These additional procedures could also limit our ability to raise additional capital in the future.
If we fail to remain current on our reporting requirements, we could be removed from the OTC Bulletin Board, which would limit the ability of broker-dealers to sell our securities and the ability of stockholders to sell their securities in the secondary market.
Companies trading on the OTC Bulletin Board, such as us, must be reporting issuers under Section 12 of the Exchange Act and must be current in their reports under Section 13, in order to maintain price quotation privileges on the OTC Bulletin Board. More specifically, FINRA has enacted Rule 6530, which determines the eligibility of issuers quoted on the OTC Bulletin Board by requiring an issuer to be current in its filings with the Commission. Pursuant to FINRA Rule 6530(e), if we file our reports late with the Commission three times in a two-year period or our securities are removed from the OTC Bulletin Board for failure to timely file twice in a two-year period then we will be ineligible for quotation on the OTC Bulletin Board. As a result, the market liquidity for our securities could be severely adversely affected by limiting the ability of broker-dealers to sell our securities and the ability of stockholders to sell their securities in the secondary market.
FINRA sales practice requirements may limit a stockholder’s ability to buy and sell our stock.
In addition to the “penny stock” rules described above, FINRA has adopted rules that require that, in recommending an investment to a customer, a broker-dealer must have reasonable grounds for believing that the investment is suitable for that customer. Prior to recommending speculative low-priced securities to their non-institutional customers, broker-dealers must make reasonable efforts to obtain information about the customer’s financial status, tax status, investment objectives and other information. Under interpretations of these rules, FINRA believes that there is a high probability that speculative low-priced securities will not be suitable for at least some customers. FINRA requirements make it more difficult for broker-dealers to recommend that their customers buy our common stock, which may limit your ability to buy and sell our stock and have an adverse effect on the market for our shares.
We will need additional capital to finance our planned growth, which we may not be able to raise or may only be available on terms unfavorable to us or our stockholders, which may result in our inability to fund our working capital requirements and harm our operational results.
We have and expect to continue to have substantial capital expenditure and working capital needs. We will need to rely on borrowings under our credit facility or raise additional cash to fund our exploration and acquisition plans, pay outstanding long-term debt, and implement our growth strategy.
If low coal, natural gas, and oil prices, operating difficulties or other factors, many of which are beyond our control, cause our revenues or cash flows from operations to decrease, we may be limited in our ability to spend the capital necessary to complete our development, production, and exploration programs. If our resources or cash flows do not satisfy our operational needs, we will require additional financing, in addition to anticipated cash generated from our operations, to fund our planned growth. Additional financing might not be available on terms favorable to us or at all. If adequate funds were not available or were not available on acceptable terms, our ability to fund our operations, take advantage of unanticipated opportunities, develop or enhance our business or otherwise respond to competitive pressures would be significantly limited. In such a capital restricted situation, we may curtail our acquisition, drilling, development, and exploration activities or be forced to sell some of our assets on an untimely or unfavorable basis.
If we raise additional funds through the issuance of equity or convertible debt securities, the percentage ownership of our stockholders would be reduced, and these newly issued securities might have rights, preferences, or privileges senior to those of existing stockholders.
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ITEM 1B. |  | UNRESOLVED STAFF COMMENTS.

Not applicable.

ITEM 2. |  | PROPERTIES.

Ownership of Coal Rights
On March 31, 2010, the Company, Future Gas Holdings, Ltd. (“Future Gas”) and JBM Energy entered into an Assignment and Assumption of Coal Agreement (the “Assignment and Assumption of Coal Agreement”) to transfer and assign all of the rights and obligations of Future Gas under a Coal Buy and Sell Agreement, dated as of February 4, 2010, by and between Future Gas and JBM Energy (the “Coal Buy and Sell Agreement”).
Pursuant to the Coal Buy and Sell Agreement, Future Gas agreed to purchase all coal mineral rights owned by JBM Energy in certain real property located in Judith Basin County, Montana, as described in the quit claim deed attached to the Coal Buy and Sell Agreement, for a purchase price of $1,950,000, with JBM Energy retaining a royalty interest of Twenty–Five Cents ($0.25) per ton on all coal when and as mined from the coal property. The purchase price of $1,950,000 was to be paid by Future Gas to JBM Energy on the following terms and schedules: Fifty Thousand U.S. Dollars ($50,000) upon execution of the Coal Buy and Sell Agreement and One Hundred Fifty Thousand U.S. Dollars ($150,000) on the closing date of the Coal Buy and Sell Agreement. The remaining balance of One Million Seven Hundred Fifty Thousand U.S. Dollars ($1,750,000) was to be paid by Future Gas executing and delivering to JBM on the closing date of the Coal Buy and Sell Agreement, a negotiable promissory note payable to JBM with payment terms as follows: $200,000 due 90 days following closing, $200,000 due 270 days following closing, and $100,000 due 90 days following completion of a reserve study and mining plan. The promissory note was to bear interest at the rate of five percent (5%) per annum, but no interest was due and payable by Future Gas during the first two (2) years following the closing date. Interest only payments were to be made quarterly during the third and fourth years following the closing date. Commencing the fifth year following the closing date, the principal balance of One Million Two Hundred Fifty Thousand U.S. Dollars ($1,250,000) was to be paid in eight (8) equal quarterly installments, plus accrued interest on unpaid principal balance to date of each principal payment. All of the above payments were to be secured by a mortgage on the coal property and the other mineral property being conveyed by JBM Energy to Future Gas at closing. Pursuant to the Assignment and Assumption of Coal Agreement, on April 9, 2010, we executed a promissory note in favor of JBM Energy on the same terms described above (the “2010 Coal Promissory Note”).
Upon repayment of the Coal Promissory Note, a quit claim deed will be delivery to us conveying the coal mineral rights which are the subject of the Coal Amendment.
Ownership of Mineral Rights
On March 31, 2010, the Company, Pace and Future Gas entered into an Assignment and Assumption of Mineral Agreement (the “Assignment and Assumption of Mineral Agreement”) to transfer and assign all of Future Gas’ rights and obligations under the Mineral Buy and Sell Agreement, dated February 4, 2010, by and between Pace and Future Gas (the “Mineral Buy and Sell Agreement”).
Pursuant to the Mineral Buy and Sell Agreement, Pace sold to Future Gas all of the oil, gas, iron ore and all other minerals of whatever nature, except coal, located in Judith Basin County, Montana, as described in the quit claim deed attached to the Mineral Buy and Sell Agreement, for a purchase price of $1,950,000, with Pace retaining a royalty interest equal to twenty percent (20%) of all royalties or other payments received by Future Gas as a result of any lease of the mineral property being conveyed to Future Gas in the Mineral Buy and Sell Agreement, or any portion thereof, and twenty percent (20%) of all net cash proceeds and/or other considerations received by Future Gas from the sale or other disposition of the mineral property being conveyed to Future Gas in the Mineral Buy and Sell Agreement or any portion thereof. The purchase price of $1,950,000 was to be paid by Future Gas executing and delivering to Pace on the closing date of the Mineral Buy and Sell Agreement a negotiable promissory note payable to Pace with the following payment terms: $200,000 due 180 days following closing date of the Mineral Buy and Sell Agreement, $200,000 due 360 days following closing date of the Mineral Buy and Sell Agreement, $100,000 due 90 days following completion of a reserve study and mining plan and $200,000 due 180 days following completion of such reserve study and mining plan. The promissory note was to bear interest at the rate of five percent (5%) per annum, but no interest was to be due and payable by Future Gas during the first two (2) years following the closing date. Interest only payments were to be made quarterly during the third and fourth years following the closing date. Commencing the fifth year following the closing date, the principal of $1,250,000 was to be paid in eight (8) equal quarterly installments, plus accrued interest on unpaid principal balance to date of each principal payment. All of the above payments were to be secured by a mortgage on the coal property and the other mineral property being conveyed by Pace. Pursuant to the Assignment and Assumption of Mineral Agreement, on April 9, 2010, we executed a promissory note in favor of Pace on the same terms described above (the “2010 Mineral Promissory Note”).
Upon repayment of the Mineral Promissory Note, a quit claim deed will be delivery to us conveying the mineral rights which are the subject of the Mineral Amendment.
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Location and Access
The PACE Coal property, which comprises our sole coal and mineral rights, is located approximately 60 miles east of Great Falls, Montana and covers approximately 29,000 acres. The property is located in Townships 14, 15, 16 and 17 North, and in Ranges 11, 12, 13, 14 and 15 East. The property is situated to the southeast and east of the town of Stanford and surrounding the town of Windham, Montana. The property is situated in the Great Falls–Lewistown coalfield, long recognized by the Montana Bureau of Mines and Geology as having bituminous coal. The surface is owned by a small number of ranchers, some non–resident, who raise cattle, hay and some grain crops.
A main line of the Burlington Northern Santa Fe (BNSF) railroad runs through the property, as well as a major East–West highway, Route 87. Two electric transmission lines, a 230 KV and a 115 KV line, run through the south and northwest ends of the property, providing power for any future development and operating phases. Existing infrastructure includes a large interstate natural gas pipeline running east–west along Interstate 90, approximately 150 miles south of the property; Cenex crude oil pipeline running through the property to a refinery at Laurel, Montana; Conoco crude oil pipeline crossing the property; and other natural gas pipelines running approximately 140 and 60 miles from the property.
Below is a map showing the location of the property.
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History of Property
A wholly–owned subsidiary of the Great Northern Railroad formerly operated the Lehigh Mine on a section of the Company’s property southwest of Windham, Montana between July 1915 and February 1921. While the operation was ultimately closed on account of the “general depression of business,” the mine did produce over 1.3 million tons of coal during its lifetime, and ended its run with a record of over 306,000 tons produced in its last year of operation, according to the Cottonwood Coal Company report located in Great Northern Railway files.
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Thirty stratigraphic test wells were drilled by Mobil Oil Corporation around 1979 on the property to estimate the magnitude of the coal deposits. Cores were taken in nine of these wells with proximate and ultimate analyses performed as well as some float analyses and washability studies. These studies show the coal to be high volatile bituminous B. The test wells found coal thickness up to 15 feet with an average of about 8.6 feet.
Pace and JBM Energy acquired the PACE Coal property in October 1969 from Griffin Coal Mines Company by quit claim deed. We acquired our interests in the property in 2010 as described above. In August 2010, we retained Weir to prepare an exploration drilling program and to supervise its execution to evaluate the coal reserve potential on the property. The program’s aim is to place a significant portion of the coal holdings in the proven and probable reserve classification, with an ultimate goal of establishing enough resources to support a greater than 20-year mine life.
To date, the PACE Coal property in Judith Basin County, Montana is without known reserves and the proposed program is exploratory in nature.
Title Review
On November 21, 2008, Meadowlark Search, a land title search company based in East Helena, Montana, conducted a title search on all the coal and other mineral interests that were conveyed to Pace by quit claim deed dated March 1, 1965 and recorded on October 15, 1969 in Book 156, page 186, Judith Basin Clerk and Recorder’s Office by Giffen Coal Mines Company. Based on this search, Pace acquired title to 100% of all such coal and other mineral interests transferred, with the exception of 480 acres that may be owned by the federal government and 160.9 acres that may be owned by the State of Montana. Meadowlark Search did not attempt to resolve the identity of the correct owner of these conflicting interests. From the deed descriptions, Meadowlark Search calculated that Pace and JBM Energy have 28,591.67 acres of coal and other mineral interest rights, plus an additional 320 acres of all minerals except coal, subject to the exception of a total of 640.9 acres that may be owned by the federal government and the State of Montana.
Drilling Activities
The Company retained Weir International, Inc. (“Weir”) in 2010 to design and supervise our exploration drilling program in Judith Basin County. In addition, we retained Mission Engineering, Inc. to assist us with the prospecting permit application process with the Montana Department of Environmental Quality. In September 2010, Weir delivered the scope of work of the exploration drilling program to the Company. This exploration program was designed to determine the presence of mineable coal seams on the PACE Coal property and provide data that can be used to estimate the quantity and quality of potentially mineable reserves and resources. The exploration program was designed to provide information relative to coal seam thickness, depth of cover, expected top and bottom conditions and coal quality.
The exploration drilling program was planned in three phases. Phase I originally consisted of drilling nine holes, on wide centers, to confirm the potential of mineable coal in the designated mine block. All of the drill holes would be cored to obtain quality information for the coal seam. Phase I also included one drilling hole to evaluate the potential for coalbed methane. When actual drilling of Phase I occurred in 2011, nine drill locations were completed while five holes were cored. Our technical team decided to postpone for Phase III the hole to evaluate the potential for coalbed methane. Phase II originally consisted of drilling eleven holes that, when combined with the Phase I holes, would place a large percentage of the coal holdings in the designated mine block in the proven and probable reserve classifications. Seven of the 11 drill holes would be cored to increase the reliability of the coal quality information for the designated mine block. When actual drilling of Phase II occurred in 2011, eight drill locations were completed while three holes were cored. Phase III originally consists of drilling forty holes, 35 of which are required to place all of the reserves in the designated mine block in the proven and probable reserve classifications. Five holes would be drilled on Pace Coal-controlled properties outside of the designated mine block to determine coal reserve potential. Eight of the drill holes in Phase III within the designated mine block would be cored. Those eight core holes, combined with the core holes from Phase I and Phase II, would provide coal quality information on approximately one-mile spacing, within the designated mine block area. One drill hole outside the designated mine block would be cored to determine the coal quality. To date, only one drill hole of Phase III has been completed and cored. According to the original scope of work prepared by Weir, the results from the Phase I and Phase II drilling would be evaluated prior to conducting the Phase III drilling. It may be necessary to revise the location of some drill holes in Phase III, based on the results of the Phase I and Phase II drilling. The results from Phase I and Phase II would be utilized to determine the final number and location of the drill holes required for Phase III. In April 2012, our technical team at Weir designated 14 Phase III drill holes as priority drill holes. These priority drill holes are expected to further define mineralization, provide additional coal quality data, and provide information to determine if any remaining Phase III drill holes will require coring.
Preliminary Results
Preliminary laboratory results for five core samples corresponding to Phase I of the drilling program showed an energy content with a range of 11,462 and 13,081 Btu/lb measured on a moisture and ash free basis (“MAF Btu”). Sulfur content ranged from 2.0% to 3.7% on a dry basis while ash content ranged from 30.6% to 51.9% on a dry basis. Preliminary laboratory results for three core samples corresponding to Phase II of the drilling program showed an energy content with a range of 12,210 to 13,056 MAF Btu. Sulfur content ranged from 3.2% to 4.9% on a dry basis while ash content ranged from 30.2% to 43.9% on a dry basis. Preliminary laboratory results for one drill location corresponding to Phase III of the drilling program showed an energy content of 12,530 MAF Btu. Sulfur content and ash content showed an average of 3.7% and 35.4% on a dry basis, respectively. We instructed Standard Laboratories, Inc. in Casper, Wyoming to prepare a washability study, including float/sink analysis to be performed on the coal cores, according to ASTM standards. The washability study will determine the amount of ash and sulfur content that could be reduced from the coal seam in order to improve its quality. The following table summarizes the laboratory results for the core samples from nine drill locations analyzed to date.
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|  | Thickness |  |  | Dry Basis |  |  |  |
Drill Hole |  | (feet) |  |  | Ash (%) |  |  | Sulfur (%) |  |  | Btu/lb |  |  | MAF Btu/lb |
PH1–1C |  |  | 4.60 |  |  |  |  | 46.62 |  |  |  | 2.25 |  |  |  | 6,432 |  |  |  | 11,462 |
PH1–5C |  |  | 10.20 |  |  |  |  | 30.55 |  |  |  | 3.74 |  |  |  | 9,093 |  |  |  | 13,081 |
PH1–6C |  |  | 14.50 |  |  |  |  | 37.86 |  |  |  | 3.59 |  |  |  | 7,903 |  |  |  | 12,602 |
PH1–8C |  |  | 1.95 |  |  |  |  | 43.92 |  |  |  | 2.01 |  |  |  | 7,027 |  |  |  | 12,530 |
PH1–9C |  |  | 2.30 |  |  |  |  | 51.92 |  |  |  | 3.36 |  |  |  | 6,044 |  |  |  | 12,571 |
PH2–6C (1) |  |  | 6.40 |  |  |  |  | 43.93 |  |  |  | 3.15 |  |  |  | 6,846 |  |  |  | 12,210 |
PH2–7C |  |  | 12.50 |  |  |  |  | 40.92 |  |  |  | 3.43 |  |  |  | 7,439 |  |  |  | 12,214 |
PH2–8C (2) |  |  | 4.10 |  |  |  |  | 30.18 |  |  |  | 4.87 |  |  |  | 9,116 |  |  |  | 13,056 |
PH3–21C |  |  | 10.90 |  |  |  |  | 35.40 |  |  |  | 3.72 |  |  |  | 8,278 |  |  |  | 12,530 |

(1) Thickness of the sample does not represent full seam thickness based on the geophysical log. There was an approximate 57.6% core recovery.
(2) Thickness of the sample does not represent full seam thickness based on the geophysical log. There was an approximate 43.6% core recovery.
Preliminary results from the first two phases of the exploration drilling program were encouraging in terms of coal thickness and high energy content; however, there can be no assurance that an economic coal and/or hydrocarbon reserve exists on the PACE Coal Project or on any other exploration projects we could eventually acquire. Even if we complete our proposed exploration programs and are successful in identifying the presence of coal and/or hydrocarbons, we will have to spend substantial funds on further drilling, engineering studies, environmental and mine feasibility studies before we will know if we have a commercially viable coal, oil and gas deposit or reserve.
Quality Assurance and Quality Control Protocols
To assure the adequacy of the sample collection, sample preparation and the analytical procedures used to develop our analytical results to date, we retained an experienced field geologist who was present during the first two phases of the drilling program. In addition to the general supervision of the project, the responsibility of the field geologist included, but was not limited to, the following: liaison among the Company, drilling contractors, geophysical logging contractor and contract coal quality laboratory personnel; log all drill cuttings and core samples; prepare core samples for laboratory analysis and transport samples from the field to a central location for shipment to the laboratory; maintain comprehensive records of drill holes, core logs, geophysical logs and daily activity; collect coal core from the designated hole for methane desorption testing and record results of the desorption tests; verify that all drill holes have been properly plugged and the drill sites reclaimed.
All recovered cores were logged by the field geologist and digital photographs taken of the cores, with graphical scales included in the photographs. The coal samples were placed in sealed boxes to maintain the integrity of the samples. Each sample was clearly identified, noting the depth of the top and bottom of the samples, along with the sample number. The samples were placed in core boxes, in stratigraphic order, with the boxes clearly marked on the outside to identify the intervals that were contained in the boxes.
All drill holes were geophysically logged by a reputable logging company, Century Wireline Services, familiar with logging coal, utilizing a standard coal suite of logs (i.e., natural gamma, gamma–gamma density, resistivity and caliper). This suite of logs permitted the determination of the depth and thickness of coal seams present in each drill hole. The geophysical logs from the rotary pilot holes were used to determine the intervals to be cored. Geophysical logs are invaluable for accurately determining the depth of the coal seam, coal seam thickness and presence of parting material within the coal seams. Also, the coal seam thickness from the geophysical log can be compared to the measured coal seam from the core holes to determine if core was lost. Copies of the logs were received in paper and digital format.
The commercial laboratory recommended and selected to analyze the samples was Standard Laboratories, Inc. of Casper, Wyoming, which is familiar with the analysis of coal seams in accordance with ASTM standards. A full proximate analysis and sample weight was performed on the coal seam as a raw sample. Partings that were encountered within the coal seam were included with the seam sample. A float/sink analysis has also been performed on the coal seam at a 1.70 specific gravity, according to ASTM standards.
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Other Property
In addition to the coal and mineral rights described above, we maintain our corporate offices at 16 Market Square Center, 1400 16th Street Suite 400, Denver, CO 80202. The premises are leased by the Company under a lease with Regus expiring July 31, 2012. The Company is currently negotiating a new lease agreement with Regus.

ITEM 3. |  | LEGAL PROCEEDINGS.

We are not a party to any pending legal proceedings and no such proceedings are known to be contemplated. No director, officer, or affiliate of the issuer and no owner of record or beneficially of more than 5% of our Common Stock, or any security holder is a party adverse to the Company or has a material interest adverse to the Company.

ITEM 4. |  | (REMOVED AND RESERVED)

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PART II

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

Market Information
Our Common Stock is quoted on the OTC Bulletin Board under the symbol “AMPW.” Prior to that, it was quoted under the symbol “TGMP.”
Our common stock has traded infrequently on the OTC Bulletin Board, which limits our ability to locate accurate high and low bid prices for each quarter within the last two fiscal years. Therefore, the following table lists the quotations for the high and low bid prices as reported by a Quarterly Trade and Quote Summary Report of the OTC Bulletin Board since American Power Corporation changed their name and symbol from Teen Glow Makeup, Inc. The quotations reflect inter-dealer prices without retail mark-up, markdown, or commissions and may not represent actual transactions.

| Period | Low | High |
| Quarter ended September 30, 2011 | $0.245 | $0.56 |
| Quarter ended June 30, 2011 | $0.36 | $0.86 |
| Quarter ended March 31, 2011 | $0.77 | $2.14 |
| Quarter ended December 31, 2010 | $0.75 | $1.45 |
| Quarter ended September 30, 2010 | $0.85 | $1.25 |

The last reported sale price of our common stock on the OTC Bulletin Board was $0.14 per share on December 28, 2011.
Holders of Common Stock
As of December 29, 2011, there were seven holders of record of our common stock.
Dividends
We have never paid or declared any cash dividends on our common stock. We currently intend to retain any future earnings to finance the growth and development of our business and we do not expect to pay any cash dividends on our common stock in the foreseeable future. Payment of future dividends, if any, will be at the discretion of our board of directors and will depend on our financial condition, results of operations, capital requirements, restrictions contained in current or future financing instruments, including the consent of debt holders, if applicable at such time, and other factors our board of directors deems relevant.
Securities Authorized for Issuance under Equity Compensation Plans
None.
Recent Sales of Unregistered Securities
All transactions have previously been disclosed.
Issuer Purchases of Equity Securities
We did not repurchase any of our equity securities during the fiscal years ended September 30, 2011 or 2010.
Transfer Agent
Our transfer agent is Signature Stock Transfer, Inc. located at 2632 Coachlight Court, Plano, TX 75093.

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.

The following discussion of our financial condition and results of operations should be read in conjunction with our financial statements and the related notes to our financial statements included elsewhere in this report. In addition to historical financial information, the following discussion and analysis contains forward-looking statements that involve risks, uncertainties, and assumptions. Our actual results and timing of selected events may differ materially from those anticipated in these forward-looking statements as a result of many factors, including those discussed under ITEM 1A. Risk Factors are elsewhere in this report.
General
The Company was incorporated in the State of Nevada as a for–profit company on August 7, 2007. Our primary business focus is to acquire, explore and develop coal, oil and gas properties in the United States, with a particular focus on the Rocky Mountains region. We have acquired certain coal and mineral rights located in the Judith Basin County, Montana, collectively described as the “PACE Coal Project.” Our plan of operation is to explore the PACE Coal Project and acquire and explore new properties which we believe are prospective for coal and/or hydrocarbons.
Plan of Operation
On August 3, 2010, we retained Weir to prepare an exploration drilling program for the PACE Coal Project and to supervise its execution. Weir is an internationally recognized consulting firm that has provided mining, geology and energy consulting services to the US and international mining and energy industries for over 75 years. In September 9, 2010, we approved an exploration drilling program consisting of 61 drilling locations and a total of 52,740 feet in three phases.
In 2011, the Company received the Prospecting Permit No. X2011335 which allowed it to carry out exploration activities on the project from July 29, 2011 to July 29, 2012. We applied for two amendments to the original exploration permit to obtain permits for Phase II and Phase III drill holes. The permits were obtained on September 12, 2011 and October 25, 2011. The current Prospecting Permit ID: X2011335 (and the Notice of Intent Permit ID: N2011007), which was issued, and renewed, by the Montana DEQ per a letter dated April 24, 2012, affects only privately owned surface and private minerals. Because both the mineral and surface ownership are privately owned, the only governmental permit that is required for our current exploration activities is by the Montana DEQ, and no additional permits are required by the Bureau of Land Management (BLM) or U.S. Forest Service.
On August 16, 2011, we started drilling operations for Phase I of the exploration drilling program. As of December 29, 2011, we had completed a total of 14,076 feet of drilling and 18 drilling locations involving all three phases of our exploration drilling program. All drill locations corresponding to Phases I and II have been fully completed, while one drill location corresponding to Phase III has been completed. Due to adverse weather conditions in Central Montana, we decided to halt drilling operations in December 2011. The decision took into consideration the decreasing returns in productivity and increasing operating costs that prevail when drilling activities occur with cold weather and snow on the ground. We plan to resume drilling activities for Phase III of the exploration drilling program in the summer of 2012 after finding capable drilling contractors and securing adequate financing.
We have commissioned our engineering consultant Weir with the preparation of a preliminary reserve study and mine feasibility study for the PACE Coal property using exploration data obtained during the first two phases of our drilling program in 2011 and data from previous exploration work carried out by Mobil Oil Co. Both studies are expected to be completed during June 2012. The purpose of the reserve study is to determine the scope of the project based on all available exploration data to date. Weir will also provide recommendations for additional exploration drilling to further delineate the mineralization on the PACE Coal property. The reserve study is expected to include the preparation of an electronic drill hole database for the property, verification of seam correlations, preparation of a seam reserve map and estimation of the mineable reserves and non-reserve mineralization. The preparation of reserve and coal quality tables will be done in accordance with US Geological Survey and SEC requirements. The preliminary mine feasibility study will include a mine plan suitable to geology and production requirements and projections for production capacity, productivity, staffing levels, equipment and facilities, capital expenditures and operating costs.
We expect to obtain a final reserve study setting forth the quantity and classification of proven and probable coal reserves and a valuation thereof and final mine feasibility study, which includes a mining plan to produce a minimum of fifty (50) million tons of coal, by April 9, 2013. These final studies will incorporate the drilling results of all three phases of the exploration program. The minimum production should be viewed as a desired target and not as a mandatory target and will be exclusively determined by the technical option of Weir.
RESULTS OF OPERATIONS FOR THE YEARS ENDED SEPTEMBER 30, 2011 AND 2010
Results
22

The Company had no revenue in the fiscal year ended September 30, 2011. Expenses, including office and general, management fees, professional fees and exploration costs, were $1,623,717 in fiscal 2011, compared to $342,040 during the previous fiscal year. This increase of $1,281,677 (375%) was primarily attributable to increased management fees of $802,500 (primarily attributable to the stock-based compensation of our officers), increased exploration costs of $440,894 (primarily attributable to the implementation of the PACE Coal Project) and increased office and general expenses of $169,605, partially offset by a decrease in professional fees of $139,322.
We experienced an operating loss of $1,952,064 during fiscal 2011 as compared to an operating loss of $777,221 during the previous fiscal year. This $1,174,843 (151%) increase in our operating loss is attributable to increased expense costs, as discussed in the preceding paragraph, and increased interest expense.
Liquidity and Capital Resources
Our net loss for the fiscal year ended September 30, 2011 was $1,952,064. During fiscal 2011, we experienced an increase in cash of $109,005. At September 30, 2011, we had a working capital deficit of $25,277, compared to working capital deficit of $73,136 at September 30, 2010. The $47,859 decreased deficit in working capital is attributable primarily to the $109,005 increase in cash and a $168,750 decrease in current portion of promissory notes, partially offset by a $222,909 increase in accounts payable and accrued liabilities.
Net cash flows used in operating activities were $690,365 for the fiscal year ended September 30, 2011, compared to $197,937 during the previous fiscal year. Negative operating cash flows in both periods are primarily attributable to net losses of $1,952,064 in fiscal 2011 and $777,221 in fiscal 2010. The $492,428 increase in cash used in operating activities from fiscal 2010 to fiscal 2011 is primarily attributable to an increase in net losses, partially offset by an increase in stock-based compensation and an increase in accretion of debt discount.
Net cash flows used in investing activities were $100,630 for the fiscal year ended September 30, 2011, compared to $386,148 during the previous fiscal year. The $285,518 decrease in cash used in investing activities from fiscal 2010 to fiscal 2011 is primarily attributable to the purchase of mineral property relating to the PACE Coal Project in fiscal 2010, partial offset by the purchase of a reclamation bond for the PACE Coal Project in fiscal 2011.
Net cash flows used in financing activities were $900,000 for the fiscal year ended September 30, 2011, compared to $1,104,790 during the previous fiscal year. The $204,790 decrease in cash used in financing activities from fiscal 2010 to fiscal 2011 is primarily attributable to the payment on a promissory note in fiscal 2011, partially offset by an increase in proceeds from the sale of Common Stock and a decrease in proceeds from notes payable.
Liquidity Outlook
We have substantial capital commitments over the next several years related to our interests in the PACE Coal property. Pursuant to the Coal Amendment and the related Coal Promissory Note, we are obligated to make payments to JBM Energy of (A) $100,000 upon the earlier of (i) sixty (60) days following the effective date of the registration statement of which this prospectus forms a part and (ii) December 9, 2012 and (B) monthly payments of $100,000 plus accrued interest commencing on April 9, 2013. Pursuant to the Mineral Amendment and the Mineral Promissory Note, we are obligated to make payments to Pace of (A) $100,000 upon the earlier of (i) sixty (60) days following the effective date of the registration statement of which this prospectus forms a part and (ii) December 9, 2012, (B) $200,000 upon the earlier of (i) ninety (90) days following the effective date of the registration statement of which this prospectus forms a part and (ii) December 9, 2012 and (C) monthly payments of $100,000 plus accrued interest commencing on April 9, 2013. Interest began to accrue under both the Coal Promissory Note and the Mineral Promissory Note on April 9, 2012, and interest payments begin on July 9, 2012. We plan to make payments under the Coal Amendment, the Coal Promissory Note, the Mineral Amendment and the Mineral Promissory Note utilizing cash on hand, proceeds from issuances under the SEDA and other financing sources, as necessary.
Further, we expect to use cash of $802,000 for office and general expenses, management fees, professional fees and exploration costs in 2012.
We have a Stock Issuance Agreement dated September 10, 2010 with Black Sands Holdings, Ltd., a Marshal Islands corporation (“Black Sands”), pursuant to which Black Sands has provided the Company with financing of in excess of $2.0 million in the past two years.
Our failure to secure additional funding to implement our business plan will significantly affect our ability to continue operations. We do not have sufficient working capital to enable us to carry out our stated plan of operation for the next twelve months.
Working Capital
23

|  | At September 30, 2011 |  |  | At September 30, 2010 |
Current assets |  | $ | 647,610 |  |  | $ | 545,592 |
Current liabilities |  |  | 672,887 |  |  |  | 618,728 |
Working capital |  | $ | (25,277 | ) |  | $ | (73,136 | )

Operating Activities
Net cash flows used in operating activities were $690,365 and $197,937 for the years ended September 30, 2011 and 2010, respectively. Negative cash flows in both periods are primarily attributable to a net loss of $1,952,064 ($777,221: 2010) furthermore changed by depreciation and amortization of $11,016 ($3,371: 2010), $692,500 ($160,000: 2010) in stock based compensation, $328,287 ($197,374: 2010) in accretion of debt discount, and $0 ($237,807: 2010) in loss recognized in extinguishment of debt. Net loss was further adjusted for the $0 ($8,000: 2010) gain on debt forgiveness, increase in prepaid expense of $11,429 ($6,324: 2010), decrease in advances of $18,416 (increase of $18,416: 2010), and increase in accounts payable of $222,909 ($13,472:2010).
Investing Activities
Net cash flows used in investing activities were $100,630 and $386,148 for the years ended September 30, 2011 and 2010, respectively. Negative cash flows for the year ended September 30, 2011 was due to the purchase of our website in the amount of $7,754 and a reclamation bond in the amount of $92,876.
Financing Activities
Net cash flows provided by financing activities were $900,000 and $1,104,790 for the years ended September 30, 2011 and 2010, respectively. Positive cash flows for the year ended September 30, 2011 were due to proceeds from the sale of common stock in the amount of $1,500,000 and repayment on promissory note in the amount of $600,000. Positive cash flows for the year ended September 30, 2010 were due to proceeds from the sale of common stock in the amount of $900,000, proceeds from a loan in the amount of $200,000 and loans from related parties in the amount of $4,790.

|  | Year Ended September 30, |
|  | 2011 |  |  | 2010 |
Net Cash Used in Operating Activities |  | $ | (690,365 | ) |  | $ | (197,937 | )
Net Cash Used in Investing Activities |  |  | (100,630 | ) |  |  | (386,148 | )
Net Cash Provided by Financing Activities |  |  | 900,000 |  |  |  | 1,104,790 |
Net Increase in Cash |  | $ | 109,005 |  |  | $ | 520,705 |

Off-Balance Sheet Arrangements
At September 30, 2011, we had no existing off-balance sheet arrangements, as defined under SEC rules that have or are reasonably likely to have a material current or future effect on our financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

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

Not applicable.

ITEM 8. |  | FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

Our financial statements and notes thereto, and other information required by this Item 8 are included in this report beginning on page F-1.

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

None.
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ITEM 9A. |  | CONTROLS AND PROCEDURES

We maintain disclosure controls and procedures designed to ensure that information required to be disclosed in reports filed under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized and reported within the specified time periods. Our Chief Executive Officer and our Chief Financial Officer (collectively, the “Certifying Officers”) are responsible for maintaining our disclosure controls and procedures. The controls and procedures established by us are designed to provide reasonable assurance that information required to be disclosed by the issuer in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Commission’s rules and forms.
To evaluate the effectiveness of our internal controls over financial reporting, we have adopted the framework prescribed by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). We believe that this framework will assist in the provision of reasonable assurance of the effectiveness and efficiency of operations, the reliability of financial reporting, and compliance with applicable laws and regulations. In adopting the COSO framework, we maintain a control environment, perform risk assessments, carry out control activities, emphasize quality information and effective communication, and perform monitoring. In the maintenance of a control environment, we are committed to integrity and ethical values as well as to competence. We strive to assign authority and responsibility in a manner that supports our internal controls, and we also maintain human resources policies and procedures designed to support our internal controls. Our risk assessments are designed to ensure the achievement of company-wide and process-level objectives as well as to identify and analyze risks while managing change. We believe that all of these components together form a foundation for sound internal control through directed leadership, shared values and a culture that emphasizes accountability for control.
As of the end of the period covered by this report, the Certifying Officers evaluated the effectiveness of our disclosure controls and procedures. Based on the evaluation, the Certifying Officers concluded that our disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported, within the time periods specified in the applicable rules and forms, and that it is accumulated and communicated to our management, including the Certifying Officers, as appropriate to allow timely decisions regarding required disclosure. The Certifying Officers have also concluded, based on our evaluation of our controls and procedures that as of September 30, 2011, our internal controls over financial reporting are effective and provide a reasonable assurance of achieving their objective.
Due to its inherent limitations, internal control over financial reporting may not prevent or detect misstatements under all potential conditions. Therefore, effective internal control over financial reporting provides only reasonable, and not absolute, assurance that a restatement of our financial statements would be prevented or detected.

ITEM 9B. |  | OTHER INFORMATION.

None.
PART III

ITEM 10. |  | DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.

The following table sets forth certain information regarding our current directors and executive officers. Our directors and executive officers serve one-year terms.

Name |  | Age |  | Position | Date Appointed
Johannes Petersen |  |  | 39 |  | CFO, Secretary, and Director | November 20, 2009
Alvaro Valencia |  |  | 38 |  | President, CEO, and Director | August 1, 2010

Biographies
Alvaro Valencia
Mr. Valencia has been an officer and director of the Company since August 1, 2010. Mr. Valencia holds a BSc in Economics from Universidad del Pacifico (Peru) and an MA degree in Economics from Syracuse University in New York. He brings to the Company his experience in investment banking and corporate finance, with an emphasis in the mining and infrastructure sectors. Mr. Valencia has held positions of increasing seniority in New York, Washington D.C. and Latin America. He has worked on major corporate and government mining–related projects, including working in association with Credit Suisse on the privatization of two international mining units in the mid 1990s.
25

Mr. Valencia formerly worked for the investment banking division of Macroconsult S.A. from May 2007 to December 2010 and Europa Partners Latin America (formerly known as StandSure Corporate Advisors S.A.C.) in Lima, Peru from September 2006 to April 2007. He formerly worked in the United States for the following: CNY Works, Inc. (2004–2006), Inter–American Development Bank (2002), BBVA Securities Inc. (2000–2001) and Credit Lyonnais Securities Asia (1999).
In determining Mr. Valencia’s qualifications to serve on our board of directors, the board considered, among other things, his experience and expertise in the mining and finance industries.
Johannes Petersen
Mr. Petersen has been an officer in the Company since November 20, 2009. Mr. Petersen holds a BSc in Economics from Universidad del Pacifico (Peru) and an MBA degree from the London Business School (UK). He brings to the Company experience gained from multiple managerial and directorship positions within diverse private and public companies. Since completing his business school studies, Mr. Petersen gained business development and business planning experience with an emphasis in the resources industry. He has worked in business planning and development for natural resource projects and has also covered several functions within the financial services industry, ranging from fixed income to currency trading.
Mr. Petersen currently sits on the board of directors of Gold American Mining Corp. a U.S. public company, currently quoted on the OTC Bulletin Board. Mr. Petersen formerly served as CEO for Dragon Gold Resources Inc. from July 2004 to May 2007 and as CFO for Century Petroleum Corp. from May 2006 to December 2009, U.S. companies previously listed on the OTC Bulletin Board. He also served as CFO for American Sierra Gold Corp from October 2009 to September 2010, a U.S. company listed on the OTC Bulletin Board. He also sat on the board of Reflection Oil & Gas Partners Ltd (2005–2010) and Hainan Mining Corporation (2005–2011), private UK companies of which he was a founder. He formerly worked in Lima, Peru for the following: Peru Scan Trading SAC, Credibolsa SAB, Banco de Credito del Peru and CONASEV (Peruvian securities regulation agency equivalent to the SEC).
In determining Mr. Petersen’s qualifications to serve on our board of directors, the board considered, among other things, his experience in the mining industry and extensive managerial background.
Legal Proceedings
The Company is not aware of any legal proceedings in which any Director, nominee, officer or affiliate of the Company, any owner of record or beneficially of more than five percent of any class of voting securities of the Company, or any associate of any such Director, nominee, officer, affiliate of the Company, or security holder is a party adverse to the Company or any of its subsidiaries or has a material interest adverse to the Company or any of its subsidiaries.
Audit Committee
The Company does not have a separately designated standing audit committee. Pursuant to Section 3(a)(58)(B) of the Exchange Act, the entire Board of Directors acts as an audit committee for the purpose of overseeing the accounting and financial reporting processes, and audits of the financial statements of the Company. The Commission recently adopted new regulations relating to audit committee composition and functions, including disclosure requirements relating to the presence of an “audit committee financial expert” serving on its audit committee. In connection with these new requirements, the Company’s Board of Directors examined the Commission’s definition of “audit committee financial expert” and concluded that the Company does not currently have a person that qualifies as such an expert. The Company has had minimal operations for the past two (2) years. Presently, there are only two directors serving on the Company’s Board, and the Company is not in a position at this time to attract, retain, and compensate additional directors in order to acquire a director who qualifies as an “audit committee financial expert.” While our current directors do not meet the qualifications of an “audit committee financial expert”, the Company’s directors, by virtue of his past employment experience, has considerable knowledge of financial statements, finance, and accounting, and has significant employment experience involving financial oversight responsibilities. Accordingly, the Company believes that its current directors capably fulfill the duties and responsibilities of an audit committee in the absence of such an expert.
Section 16(a) Beneficial Ownership Reporting Compliance
Section 16(a) of the Exchange Act requires our executive officers and directors, and persons who beneficially own more than ten percent of our common stock, to file initial reports of ownership and reports of changes in ownership with the SEC. Executive officers, directors, and greater than ten percent beneficial owners are required by SEC regulations to furnish us with copies of all Section 16(a) forms they file. Based upon a review of the copies of such forms furnished to us and written representations from our executive officers and directors, we believe that as of the date of this report they were all current in their 16(a) reports.
26

Board of Directors
Our board of directors currently consists of two members, Mr. Alvaro Valencia and Mr. Johannes Petersen. Our directors serve one-year terms.
Committees of the Board of Directors
None.
Code of Ethics
We have not adopted a Code of Business Conduct and Ethics at this time. Presently, there are only two officers of the Company, each of whom is a director. We do not believe it necessary or in the Company’s best interests to adopt a code of ethics to govern the actions of two officers who also serve on the Company’s board of directors.
Limitation of Liability of Directors
Pursuant to the Nevada Revised Statutes, our Articles of Incorporation exclude personal liability for our directors for monetary damages based upon any violation of their fiduciary duties as directors, except as to liability for any breach of the duty of loyalty, acts or omissions not in good faith or which involve intentional misconduct or a knowing violation of law, or any transaction from which a director receives an improper personal benefit. This exclusion of liability does not limit any right which a director may have to be indemnified and does not affect any director’s liability under federal or applicable state securities laws. We have agreed to indemnify our directors against expenses, judgments and amounts paid in settlement in connection with any claim against a director if he acted in good faith and in a manner he believed to be in our best interests.
Insofar as indemnification by us for liabilities arising under the Securities Act may be permitted to our directors, officers, or persons controlling the company pursuant to provisions of our Articles of Incorporation and Bylaws, or otherwise, we have been advised that in the opinion of the SEC, such indemnification is against public policy as expressed in the Securities Act and is therefore unenforceable. In the event that a claim for indemnification by such director, officer, or controlling person of us in the successful defense of any action, suit, or proceeding is asserted by such director, officer, or controlling person in connection with the securities being offered, we will, unless in the opinion of our counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by us is against public policy as expressed in the Securities Act and will be governed by the final adjudication of such issue.

ITEM 11. |  | EXECUTIVE COMPENSATION.

The following table sets forth summary compensation information for the fiscal years ended September 30, 2011 and 2010 for our officers and directors. We did not have any other executive officers or directors as of the end of fiscal 2011.

SUMMARY COMPENSATION TABLE |
|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | Non-Equity |  |  | Nonqualified |  |  |  |  |  |  |
|  |  |  |  |  |  |  |  |  |  |  |  | Option |  |  | Incentive Plan |  |  | Deferred |  |  | All Other |  |  |  |
|  |  |  | Salary |  |  | Bonus |  |  | Stock Awards |  |  | Awards |  |  | Compensation |  |  | Compensation |  |  | Compensation |  |  | Total |
Name and principal position |  | Year |  | ($) |  |  | ($) |  |  | ($)(1) |  |  | ($) |  |  | ($) |  |  | Earnings ($) |  |  | ($) |  |  | ($) |
Johannes Petersen |  | 2010 |  | $ | 30,000 | (2) |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  | $ | 30,000 | (2)
Officer |  | 2011 |  | $ | 60,000 | (2) |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  | $ | 60,000 | (2)
Alvaro Valencia |  | 2010 |  | $ | 8,333 |  |  |  | 0 |  |  | $ | 160,000 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  | $ | 168,333 |
Officer |  | 2011 |  | $ | 50,000 |  |  |  | 0 |  |  | $ | 692,500 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  |  | 0 |  |  | $ | 742,500 |

________________

(1) | Calculated in accordance with FASB ASC Topic 718.

(2) | Mr. Petersen earns $5,000 per month based on a consulting arrangement with the Company for providing services as a financial officer of the Company.

The Company and Alvaro Valencia entered into an Independent Consulting Agreement effective (“Consulting Agreement”) on August 1, 2010. According to the terms of the Consulting Agreement, Mr. Valencia will serve as President, Chief Executive Officer and Director of the Company for a period of four (4) years beginning August 1, 2010. The Consulting Agreement is renewable upon the mutual consent of the parties on or before thirty (30) days prior to the end date of the Consulting Agreement. Any such renewal shall be for a period of twelve (12) months. The Company shall pay Mr. Valencia $50,000 per year, in equal monthly installments of $4,166,67. Mr. Valencia will also receive up to an aggregate of four million (4,000,000) restricted shares of the Company. Two hundred and fifty thousand (250,000) shares shall be issued at the end of each three–month period immediately following August 1, 2010.
27

We have entered into a consulting arrangement with Johannes Petersen, our Chief Financial Officer and Secretary, pursuant to which, we pay Mr. Petersen $5,000 per month for providing consulting services in his capacity as Chief Financial Officer and Secretary. However, such consulting arrangement has not been memorialized in a written agreement.
Potential Payments Upon Termination or Change in Control
In the event of a consolidation or merger or sale of all or substantially all of the assets of the Company in which outstanding shares of our Common Stock are exchanged for securities, cash or other property of any other corporation, firm, partnership, joint venture, association or business entity, the Company is otherwise acquired or there is a change of control of the Company (receipt of more than 50% of the outstanding shares of the Company, the Company otherwise being acquired, or a change in control of the Company are collectively referred to as an “Acquisition”), or in the event of liquidation of the Company, so much of the 4,000,000 shares that have not been issued to Alvaro Valencia shall immediately and fully vest and shall also be transferable by Alvaro Valencia immediately prior to such Acquisition or liquidation. The number of shares is subject to adjustment from time to time as set forth in Section 3(b) of the Consulting Agreement with Alvaro Valencia.
Outstanding Equity Awards at 2011 Fiscal Year-End
None.
Compensation Committee Interlocks
All members of our board of directors acted in lieu of a compensation committee during fiscal 2011. We had no compensation committee interlocks with any entity in fiscal 2011.
Compensation Committee Report
We, constituting all members of the Board of Directors, in lieu of a compensation committee, have reviewed and discussed the Compensation Discussion and Analysis (set forth above) with the management of the company, and, based on such review and discussion, have recommended to the Board of Directors the inclusion of the Compensation Discussion and Analysis in the registration statement of which this prospectus forms a part.

| Johannes Petersen
| Alvaro Valencia

ITEM 12. |  | SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.

The following table presents information, to the best of American Power’s knowledge, about the ownership of American Power’s common stock on December 29, 2011 relating to those persons known to beneficially own more than 5% of American Power’s capital stock and by American Power’s named executive officers, directors and directors and executive officers as a group. The percentage of beneficial ownership for the following table is based on 96,429,358 shares of common stock outstanding.
Beneficial ownership is determined in accordance with the rules of the Securities and Exchange Commission and does not necessarily indicate beneficial ownership for any other purpose. Under these rules, beneficial ownership includes those shares of common stock over which the stockholder has sole or shared voting or investment power. It also includes shares of common stock that the stockholder has a right to acquire within 60 days after December 29, 2011 pursuant to options, warrants, conversion privileges or other right. The percentage ownership of the outstanding common stock, however, is based on the assumption, expressly required by the rules of the Securities and Exchange Commission, that only the person or entity whose ownership is being reported has converted options or warrants into shares of American Power’s common stock.
OFFICERS, DIRECTORS AND BENEFICIAL OWNERS, AS OF DECEMBER 29, 2011
28

OFFICERS AND DIRECTORS

Title of Class |  | Name and Address of Shareholder |  | Office, If Any |  | Amount & Nature of Beneficial Ownership (1) |  | Percent of Class (2)
Common Stock |  | Johannes Petersen c/o American Power Corp 1600 14th Street, Ste 400 Denver CO 80202 |  | CFO, Secretary and Director |  | 47,600,000 Direct |  | 49.4%
Common Stock |  | Alvaro Valencia(3) c/o American Power Corp 1600 14th Street, Ste 400 Denver CO 80202 |  | President, CEO, Director |  | 1,250,000 |  | 1.3%
All Officers and Directors as a group |  |  |  |  |  | 48,850,000 |  | 50.7%

_____________________

(1) | Beneficial ownership is determined in accordance with the rules of the SEC and generally includes voting or investment power with respect to securities.

(2) | A total of 96,429,358 shares of our common stock outstanding are considered to be outstanding pursuant to SEC Rule 13d-3(d)(1) as of December 29, 2011.

Changes in Control
There are no arrangements known to us, including any pledge by any person of our securities, the operation of which may at a subsequent date result in a change in control of the Company.

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

We were not a party to any transactions or series of similar transactions that have occurred during this fiscal year in which the amounts involved exceeds the lesser of $120,000 or one percent of the average of our total assets at year end for the last two completed fiscal years.

ITEM 14. |  | PRINCIPAL ACCOUNTANT FEES AND SERVICES.

De Joya Griffith & Company, LLC served as our principal independent public accountants for fiscal 2010 and 2011. Aggregate fees billed to us for the fiscal years ended September 30, 2011 and 2010 by De Joya Griffith & Company, LLC were as follows:

| For the Fiscal Years Ended September 30, |
| 2011 |  | 2010 |
(1) Audit Fees(1) |  | $ | 22,250 |  |  | $ | 9,500 |
(2) Audit-Related Fees(2) |  |  | -0- |  |  |  | -0- |
(3) Tax Fees(3) |  |  | -0- |  |  |  | -0- |
(4) All Other Fees |  |  | -0- |  |  |  | -0- |
Total fees paid or accrued to our independent public accountants |  | $ | 22,250 |  |  | $ | 9,500 |

_____________________

(1) |  | Audit Fees include fees billed and expected to be billed for services performed to comply with Generally Accepted Auditing Standards (GAAS), including the recurring audit of the Company’s financial statements for such period included in this Annual Report on Form 10-K and for the reviews of the quarterly financial statements included in the Quarterly Reports on Form 10-Q filed with the Securities and Exchange Commission. This category also includes fees for audits provided in connection with statutory filings or procedures related to audit of income tax provisions and related reserves, consents and assistance with and review of documents filed with the SEC.

(2) |  | Audit-Related Fees include fees for services associated with assurance and reasonably related to the performance of the audit or review of the Company’s financial statements. This category includes fees related to assistance in financial due diligence related to mergers and acquisitions, consultations regarding Generally Accepted Accounting Principles, reviews and evaluations of the impact of new regulatory pronouncements, general assistance with implementation of Sarbanes-Oxley Act of 2002 requirements and audit services not required by statute or regulation.

(3) |  | Tax fees consist of fees related to the preparation and review of the Company’s federal and state income tax returns.

29

PART IV

ITEM 15. |  | EXHIBITS, FINANCIAL STATEMENT SCHEDULES.

(a) Financial Statements
See “Index to Financial Statements” on page F-3.
(b) and (c) Exhibits

Exhibit No. |  |
31.1* |  | Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2* |  | Certification of Principal Financial and Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.1* |  | Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.2* |  | Certification of Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

______________
*Filed herewith
30

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

| AMERICAN POWER CORPORATION
| By: /s/ Alvaro Valencia
| Director, Chief Executive Officer and President
| By: /s/ Johannes Petersen
| Director, Chief Financial Officer and Secretary
Date: June 21, 2011 |

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

| By: /s/ Alvaro Valencia
| Director, Chief Executive Officer and President
| By: /s/ Johannes Petersen
| Director, Chief Financial Officer and Secretary
Date: June 21, 2011 |

31

Report of Independent Registered Public Accounting Firm
To The Board of Directors and Stockholders
American Power Corp.
We have audited the accompanying balance sheets of American Power Corp. (An Exploration Stage Company) (the “Company”) as of September 30, 2011 and 2010, and the related statements of operations, stockholders’ equity (deficit), and cash flows for the years then ended, and from inception (August 7, 2007) through September 30, 2011. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the financial statements based on our audits.
We conducted our audits in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of American Power Corp. (An Exploration Stage Company) as of September 30, 2011 and 2010, and the results of their operations and cash flows for the years then ended, and from inception (August 7, 2007) through September 30, 2011 in conformity with accounting principles generally accepted in the United States.
The accompanying financial statements have been prepared assuming the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has suffered recurring losses from operations, which raise substantial doubt about its ability to continue as a going concern. Management’s plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.
/s/ De Joya Griffith & Company, LLC
Henderson, Nevada
December 27, 2011

2580 Anthem Village Drive, Henderson, NV 89052
Telephone (702) 563-1600 ● Facsimile (702) 920-8049
32

AMERICAN POWER CORP.
(An Exploration Stage Company)
FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)

33

AMERICAN POWER CORP. |
(An Exploration Stage Company) |
BALANCE SHEETS |
(Audited) |
|  | September 30, 2011 |  |  | September 30, 2010 |
ASSETS |  |  |  |  |  |
CURRENT ASSETS |  |  |  |  |  |
Cash |  | $ | 629,857 |  |  | $ | 520,852 |
Prepaids and deposit |  |  | 17,753 |  |  |  | 6,324 |
Advances to related party |  |  | - |  |  |  | 18,416 |
TOTAL CURRENT ASSETS |  |  | 647,610 |  |  |  | 545,592 |
LONG TERM ASSETS |  |  |  |  |  |  |  |
Mineral property (Note 5) |  |  | 2,670,500 |  |  |  | 2,670,500 |
Reclamation bond |  |  | 92,876 |  |  |  | - |
Equipment - net |  |  | 3,218 |  |  |  | 4,480 |
Website - net |  |  | 26,297 |  |  |  | 28,297 |
TOTAL LONG TERM |  |  | 2,792,891 |  |  |  | 2,703,277 |
TOTAL ASSETS |  | $ | 3,440,501 |  |  | $ | 3,248,869 |
LIABILITIES AND STOCKHOLDERS’ EQUITY |  |  |  |  |  |  |  |
CURRENT LIABILITIES |  |  |  |  |  |  |  |
Accounts payable and accrued liabilities |  | $ | 241,637 |  |  | $ | 18,728 |
Promissory notes, current portion |  |  | 431,250 |  |  |  | 600,000 |
TOTAL CURRENT LIABILITIES |  |  | 672,887 |  |  |  | 618,728 |
LONG TERM LIABILITIES |  |  |  |  |  |  |  |
Promissory notes, net of current portion, net of debt discount of $777,442 ($1,105,729 – September 30, 2010) |  |  | 1,691,308 |  |  |  | 1,794,271 |
TOTAL LONG TERM LIABILITIES |  |  | 1,691,308 |  |  |  | 1,794,271 |
TOTAL LIABILITIES |  |  | 2,364,195 |  |  |  | 2,412,999 |
STOCKHOLDERS’ EQUITY |  |  |  |  |  |  |  |
Capital stock |  |  |  |  |  |  |  |
Authorized |  |  |  |  |  |  |  |
500,000,000 shares of common stock, $0.001 par value, |  |  |  |  |  |  |  |
Issued and outstanding |  |  |  |  |  |  |  |
92,952,085 shares of common stock (90,480,000 September 30, 2010) |  |  | 92,951 |  |  |  | 90,480 |
Additional paid in capital |  |  | 2,957,037 |  |  |  | 528,098 |
Stock payable |  |  | 867,500 |  |  |  | 1,106,410 |
Accumulated deficit during the exploration stage |  |  | (2,841,182 | ) |  |  | (889,118 | )
TOTAL STOCKHOLDERS’ EQUITY |  |  | 1,076,306 |  |  |  | 835,870 |
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY |  | $ | 3,440,501 |  |  | $ | 3,248,869 |
The accompanying notes are an integral part of these financial statements. |

34

AMERICAN POWER CORP. |
(An Exploration Stage Company) |
STATEMENTS OF OPERATIONS |
(Audited) |
|  |  |  |  |  |  |  | Cumulative results |
|  |  |  |  |  |  |  | from inception |
|  | Year ended |  |  | Year ended |  |  | (August 7, 2007) to |
|  | September 30, 2011 |  |  | September 30, 2010 |  |  | September 30, 2011 |
REVENUE |  |  |  |  |  |  |  |  |
Revenues |  | $ | - |  |  | $ | - |  |  | $ | - |
Total revenues |  |  | - |  |  |  | - |  |  |  | - |
EXPENSES |  |  |  |  |  |  |  |  |  |  |  |
Office and general |  |  | 261,032 |  |  |  | 91,427 |  |  |  | 358,384 |
Management fees |  |  | 802,500 |  |  |  | - |  |  |  | 1,001,164 |
Professional fees |  |  | 119,291 |  |  |  | 258,613 |  |  |  | 210,142 |
Gain on debt forgiveness |  |  | - |  |  |  | (8,000 | ) |  |  | (8,000 | )
Exploration costs |  |  | 440,894 |  |  |  | - |  |  |  | 440,894 |
Total expenses |  |  | (1,623,717 | ) |  |  | (342,040 | ) |  |  | (2,002,584 | )
OTHER EXPENSE |  |  |  |  |  |  |  |  |  |  |  |
Interest expense |  |  | (328,347 | ) |  |  | (197,374 | ) |  |  | (525,721 | )
Loss on debt settlement |  |  | - |  |  |  | (237,807 | ) |  |  | (237,807 | )
Total other expenses |  |  | (328,347 | ) |  |  | (435,181 | ) |  |  | (763,528 | )
NET LOSS |  | $ | (1,952,064 | ) |  | $ | (777,221 | ) |  | $ | (2,766,112 | )
BASIC LOSS PER COMMON SHARE |  | $ | (0.02 | ) |  | $ | (0.01 | ) |  |  |  |
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING- BASIC |  |  | 92,125,873 |  |  |  | 88,689,041 |  |  |  |  |

The accompanying notes are an integral part of these financial statements.
35

AMERICAN POWER CORP. |
(An Exploration Stage Company) |
STATEMENT OF STOCKHOLDERS' EQUITY (DEFICIT) |
From inception (August 7, 2007) to September 30, 2011 |
(Audited) |
|  | Common Stock |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Number of shares |  |  | Amount |  |  | Additional Paid-in Capital |  |  | Share Subscription Receivable |  |  | Stock Payable |  |  | Accumulated deficit during the exploration stage |  |  | Total |
Balance, August 7, 2007 (Inception) |  |  | - |  |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | - |
Common stock issued for cash at $0.001per share on August 13, 2007 |  |  | 44,200,000 |  |  |  | 44,200 |  |  |  | - |  |  |  | (8,500 | ) |  |  | - |  |  |  | (35,700 | ) |  |  | - |
Net loss |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (2,525 | ) |  |  | (2,525 | )
Balance, September 30, 2007 |  |  | 44,200,000 |  |  |  | 44,200 |  |  |  | - |  |  |  | (8,500 | ) |  |  | - |  |  |  | (38,225 | ) |  |  | (2,525 | )
Subscription Receivable |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 8,500 |  |  |  | - |  |  |  | - |  |  |  | 8,500 |
Common stock issued for cash at $0.03per share July and August 2008 |  |  | 43,180,000 |  |  |  | 43,180 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (39,370 | ) |  |  | 3,810 |
Net loss |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | (12,964 | ) |  |  | (12,964 | )
Balance, September 30, 2008 |  |  | 87,380,000 |  |  |  | 87,380 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (90,559 | ) |  |  | (3,179 | )
Net loss |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (21,338 | ) |  |  | (21,338 | )
Balance, September 30, 2009 |  |  | 87,380,000 |  |  |  | 87,380 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (111,897 | ) |  |  | (24,517 | )
Forgiveness of debt by former director |  |  | - |  |  |  | - |  |  |  | 16,198 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 16,198 |
Common Stock, issued for mineral property at $0.05 per share April 9, 2010 |  |  | 2,300,000 |  |  |  | 2,300 |  |  |  | 112,700 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 115,000 |
Common stock issued for cash at $0.50per share June 25, 2010 |  |  | 800,000 |  |  |  | 800 |  |  |  | 399,200 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 400,000 |
Common stock to be issued on debt totaling $208,603 (including interest of $8,603) conversion at $0.50 per share September 10, 2010 |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 446,410 |  |  |  | - |  |  |  | 446,410 |
Common stock to be issued for services at $0.96 per share at September 30, 2010 |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 160,000 |  |  |  | - |  |  |  | 160,000 |
Private placement received in advance |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 500,000 |  |  |  | - |  |  |  | 500,000 |
Net loss |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (777,221 | ) |  |  | (777,221 | )
Balance, September 30, 2010 |  |  | 90,480,000 |  |  |  | 90,480 |  |  |  | 528,098 |  |  |  | - |  |  |  | 1,106,410 |  |  |  | (889,118 | ) |  |  | 835,870 |
Common stock issued for 595,238 units at $0.84 per unit on October 5, 2010 |  |  | 595,238 |  |  |  | 595 |  |  |  | 499,405 |  |  |  | - |  |  |  | (500,000 | ) |  |  | - |  |  |  | - |
Common stock issued for 449,438 units at $0.89 per unit on January 25, 2011 |  |  | 449,438 |  |  |  | 449 |  |  |  | 399,551 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 400,000 |
Common stock issued for 510,204 units at $0.98 per unit on February 23, 2011 |  |  | 510,204 |  |  |  | 510 |  |  |  | 499,490 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 500,000 |
Common stock issued for stock payable on April 5, 2011 |  |  | 417,205 |  |  |  | 417 |  |  |  | 445,993 |  |  |  | - |  |  |  | (446,410 | ) |  |  | - |  |  |  | - |
Common stock issued for services on April 5, 2011 , 250,000 shares vested on October 31, 2010 and 250,000 shares vested on January 31, 2011 |  |  | 500,000 |  |  |  | 500 |  |  |  | 584,500 |  |  |  | - |  |  |  | (160,000 | ) |  |  | - |  |  |  | 425,000 |
Common stock to be issued for 2,727,273 units at $0.22 per unit on August 9, 2011 |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 600,000 |  |  |  | - |  |  |  | 600,000 |
Common stock to be issued for services at September 30, 2011 |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 267,500 |  |  |  | - |  |  |  | 267,500 |
Net loss |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (1,952,064 | ) |  |  | (1,952,064 | )
Balance, September 30, 2011 |  |  | 92,952,085 |  |  | $ | 92,951 |  |  | $ | 2,957,037 |  |  | $ | - |  |  | $ | 867,500 |  |  | $ | (2,841,182 | ) |  | $ | 1,076,306 |
The accompanying notes are an integral part of these financial statements. |

36

AMERICAN POWER CORP. |
(An Exploration Stage Company) |
STATEMENTS OF CASH FLOWS |
(Audited) |
|  |  |  |  |  |  |  | Cumulative results |
|  | Year ended |  |  | Year ended |  |  | from inception (August 7, 2007) |
|  | September 30, 2011 |  |  | September 30, 2010 |  |  | to September 30, 2011 |
CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |  |  |  |  |  |
Net loss |  | $ | (1,952,064 | ) |  | $ | (777,221 | ) |  | $ | (2,766,112 | )
Adjustment to reconcile net loss to net cash |  |  |  |  |  |  |  |  |  |  |  |
used in operating activities |  |  |  |  |  |  |  |  |  |  |  |
Depreciation and amortization |  |  | 11,016 |  |  |  | 3,371 |  |  |  | 14,387 |
Stock-based compensation |  |  | 692,500 |  |  |  | 160,000 |  |  |  | 852,500 |
Accretion of debt discount |  |  | 328,287 |  |  |  | 197,374 |  |  |  | 525,661 |
Gain on extinguishment of debt |  |  | - |  |  |  | (8,000 | ) |  |  | (8,000 | )
Loss on extinguishment of debt |  |  | - |  |  |  | 237,807 |  |  |  | 237,807 |
(Increase) in prepaid expenses |  |  | (11,429 | ) |  |  | (6,324 | ) |  |  | (17,753 | )
(Increase) decrease in advances to related party |  |  | 18,416 |  |  |  | (18,416 | ) |  |  | - |
Increase in accounts payable and accrued liabilities |  |  | 222,909 |  |  |  | 13,472 |  |  |  | 249,637 |
NET CASH USED IN OPERATING ACTIVITIES |  |  | (690,365 | ) |  |  | (197,937 | ) |  |  | (911,873 | )
CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |  |  |  |  |  |  |  |  |
Website |  |  | (7,754 | ) |  |  | (31,191 | ) |  |  | (38,945 | )
Equipment |  |  | - |  |  |  | (4,957 | ) |  |  | (4,957 | )
Mineral property |  |  | - |  |  |  | (350,000 | ) |  |  | (350,000 | )
Reclamation bond |  |  | (92,876 | ) |  |  | - |  |  |  | (92,876 | )
NET CASH USED IN INVESTING ACTIVITIES |  |  | (100,630 | ) |  |  | (386,148 | ) |  |  | (486,778 | )
CASH FLOWS FROM FINANCING ACTIVITIES |  |  |  |  |  |  |  |  |  |  |  |
Proceeds from sale of common stock |  |  | 1,500,000 |  |  |  | 900,000 |  |  |  | 2,412,310 |
Loans from related party |  |  | - |  |  |  | 4,790 |  |  |  | 16,198 |
Proceeds from notes payable |  |  | - |  |  |  | 200,000 |  |  |  | 200,000 |
Payment on promissory note |  |  | (600,000 | ) |  |  | - |  |  |  | (600,000 | )
NET CASH PROVIDED BY FINANCING ACTIVITIES |  |  | 900,000 |  |  |  | 1,104,790 |  |  |  | 2,028,508 |
INCREASE IN CASH |  |  | 109,005 |  |  |  | 520,705 |  |  |  | 629,857 |
CASH, BEGINNING OF PERIOD |  |  | 520,852 |  |  |  | 147 |  |  |  | - |
CASH, END OF PERIOD |  | $ | 629,857 |  |  | $ | 520,852 |  |  | $ | 629,857 |
Supplemental cash flow information and non-cash financing activities: |  |  |  |  |  |  |  |  |
Common stock payable for property acquisition |  | $ | - |  |  | $ | 115,000 |  |  | $ | 115,000 |
Promissory notes issued for property |  | $ | - |  |  | $ | 2,405,500 |  |  | $ | 2,405,500 |
Forgiveness of debt by former director |  | $ | - |  |  | $ | 16,198 |  |  | $ | 16,198 |
Common stock issued to satisfy common stock payable |  | $ | 1,106,410 |  |  | $ | - |  |  | $ | 1,106,410 |
Conversion of debt totaling $208,603, (including interest of $8,603) for common stock |  | $ | - |  |  | $ | 446,410 |  |  | $ | 446,410 |
The accompanying notes are an integral part of these financial statements |

37

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 1 – NATURE OF OPERATIONS AND BASIS OF PRESENTATION
American Power Corp. (the “Company”) was originally organized as Teen Glow Makeup, Inc. under the laws of the State of Nevada on August 7, 2007. On April 30, 2010 the Company changed its name to American Power Corp. The Company is in exploration stage and has incurred losses since inception of $2,841,182. The Company is An Exploration Stage Enterprise, as defined in FASB ASC 915-10 “Development Stage Entities”. During the year ended September 30, 2010, the Company decided to redirect its business focus toward coal, oil and natural gas exploration and development.
The accompanying audited financial statements have been prepared in accordance with generally accepted accounting principles for financial information and with the instructions to Form 10-K.
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The financial statements present the balance sheets, statements of operations, stockholders’ equity (deficit) and cash flows of the Company. These financial statements are presented in United States dollars and have been prepared in accordance with accounting principles generally accepted in the United States.
Going Concern
The Company’s financial statements as of September 30, 2011 have been prepared using generally accepted accounting principles in the United States of America applicable to a going concern, which contemplates the realization of assets and liquidation of liabilities in the normal course of business. The Company has not yet established an ongoing source of revenues sufficient to cover its operating costs and allow it to continue as a going concern. For the years ended September 30, 2011 and 2010 the Company had a net loss of $1,952,064 and $777,221, respectively.
In order to continue as a going concern, the Company will need, among other things, additional capital resources. Management’s plan is to obtain such resources for the Company by obtaining capital from management and significant shareholders sufficient to meet its minimal operating expenses and seeking equity and/or debt financing. However management cannot provide any assurances that the Company will be successful in accomplishing any of its plans.
The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish the plans described in the preceding paragraph and eventually secure other sources of financing and attain profitable operations. These financial statements do not include any adjustments related to the recoverability and classification of assets or the amounts and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.
Stock based compensation
The Company recognizes stock-based compensation in accordance with ASC Topic 718 “Stock Compensation”, which 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.
For non-employee stock-based compensation, the Company has adopted ASC Topic 505 “Equity-Based Payments to Non-Employees”, which requires stock-based compensation related to non-employees to be accounted for based on the fair value of the related stock or options or the fair value of the services on the grant date, whichever is more readily determinable in accordance with ASC Topic 505.
Cash and cash equivalents
Cash and cash equivalents include highly liquid investments with original maturities of three months or less.
38

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES – (CONTINUED)
Financial Instruments
ASC 825, Financial Instruments requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. ASC 825 establishes a fair value hierarchy based on the level of independent, objective evidence surrounding the inputs used to measure fair value. A financial instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. ASC 825 prioritizes the inputs into three levels that may be used to measure fair value:
Level 1 applies to assets or liabilities for which there are quoted prices in active markets for identical assets or liabilities.
Level 2 applies to assets or liabilities for which there are inputs other than quoted prices that are observable for the asset or liability such as quoted prices for similar assets or liabilities in active markets; quoted prices for identical assets or liabilities in markets with insufficient volume or infrequent transactions (less active markets); or model-derived valuations in which significant inputs are observable or can be derived principally from, or corroborated by, observable market data of the fair value of the assets or liabilities.
Level 3 applies to assets or liabilities for which there are unobservable inputs to the valuation methodology that are significant to the measurement of the fair value of the assets or liabilities.
The Company’s financial instruments consist principally of cash, accounts payable and accrued liabilities, and promissory notes.
Pursuant to ASC 825, the fair value of cash is determined based on “Level 1” inputs, which consist of quoted prices in active markets for identical assets. The Company believes that the recorded values of cash, accounts payable and accrued liabilities, and other payables approximate their current fair values because of their nature and respective relatively short maturity dates or durations. Notes payable and loans payable approximate current fair value because interest is payable at market rates.
Use of Estimates and Assumptions
Preparation of the financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect certain reported amounts and disclosures. Accordingly, actual results could differ from those estimates.
Net Loss per Share
Basic loss per share includes no dilution and is computed by dividing loss available to common stockholders by the weighted average number of common shares outstanding for the period. Dilutive loss per share reflects the potential dilution of securities that could share in the losses of the Company. Because the Company does not have any potentially dilutive securities, the accompanying presentation is only of basic loss per share.
39

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES – (CONTINUED)
Fixed Assets
Fixed assets are stated at cost. Major renewals and improvements are charged to the asset accounts while replacements, maintenance and repairs, which do not improve or extend the lives of the respective assets, are expensed. At the time property and equipment are retired or otherwise disposed of, the asset and related accumulated depreciation accounts are relieved of the applicable amounts. Gains or losses from retirements or sales are credited or charged to income.
The Company’s fixed assets consist of computer equipment, which is valued at cost and depreciated using the straight-line method over a period of four years.
Website Development Costs
Costs incurred in developing and maintaining a website are charged to expense when incurred for the planning, content population, and administration or maintenance of the website. All development costs for the application, infrastructure, and graphics development are capitalized and subsequently reported at the lower of unamortized cost or net realizable value. Capitalized costs are amortized using the straight-line method over a four year estimated economic life. For the years ended September 30, 2011 and September 30, 2010, the company recorded Website amortization of $9,754 and $2,894, respectively, and net Website asset of $26,297 and $28,297, respectively.
Revenue Recognition
Coal, oil, and natural gas revenues are recorded using the sales method, whereby the Company recognizes coal, oil and natural gas revenue based on the amount of coal, oil, and gas sold to purchasers, when title passes, the amount is determinable, and collection is reasonably assured. Actual sales of coal, oil, and natural gas are based on sales, net of the associated volume charges for processing fees and for costs associated with delivery, transportation, marketing, and royalties in accordance with industry standards. Operating costs and taxes are recognized in the same period in which revenue is earned.
Income Taxes
The Company follows the liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax balances. Deferred tax assets and liabilities are measured using enacted or substantially enacted tax rates expected to apply to the taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the date of enactment or substantive enactment. As of September 30, 2011, the Company had net operating loss carryforwards; however, due to the uncertainty of realization, the Company has provided a full valuation allowance for the deferred tax assets resulting from these loss carryforwards.
Mineral Property Costs
The Company has not yet realized any revenues from its planned operations. It is primarily engaged in the acquisition and exploration of mining and coal properties. Mineral property exploration costs are charged to operations as incurred. When it has been determined that a mineral property can be economically developed as a result of establishing proven and probable reserves, the costs incurred to develop such property, are capitalized. Such costs will be depleted using the units-of-production method over the estimated life of the probable reserve.
Although the Company has taken steps to verify title to mineral and coal properties in which it has an interest, according to the usual industry standards for the stage of exploration of such properties, these procedures do not guarantee the Company’s title. Such properties may be subject to prior agreements or transfers and title may be affected by undetected defects.
Recent Accounting Pronouncements
There have been no recent accounting pronouncements or changes in accounting pronouncements that impacted the fourth quarter of fiscal 2011, or which are expected to impact future periods, which were not already adopted and disclosed in prior periods.
40

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 3 – FIXED ASSETS
The Company’s fixed assets consist of computer equipment which is valued at cost and depreciated using the straight-line method over four years as follows:

|  |  |  |  |  |  |  | Sept. 30, |  |  | Sept. 30, |
|  |  |  |  | Accumulated |  |  | 2011 |  |  | 2010 |
|  | Cost |  |  | Amortization |  |  | Net |  |  | Net |
Computer equipment |  | $ | 4,956 |  |  | $ | 1,738 |  |  | $ | 3,218 |  |  | $ | 4,480 |

Depreciation of $1,262 and $477 is included in general and administrative expenses in the statement of operations for the years ended September 30, 2011 and 2010, respectively.
NOTE 4 – LOANS
On April 6, 2010, the Company obtained a loan in the amount of $200,000, bearing interest of 10% per annum from Black Sands Holdings, Ltd. On September 10, 2010 the Company agreed to enter into a debt to equity conversion as a means of settling the outstanding loan amount of $208,603 by issuing 417,205 shares. The fair value of the shares was $446,410, of which $237,807 was recognized as a loss on debt settlement.
NOTE 5 – COAL AND OTHER MINERAL PROPERTIES
On March 31, 2010, the Company entered into a series of agreements to acquire all the mineral, oil and gas rights of a mineral property located in Judith Basin County, Montana for a total consideration of $2,670,500.
On March 31, 2010, the Company, Future Gas Holdings, Ltd. (“Future Gas”) and JBM Energy Company, LLC (“JBM”) entered into an Assignment of Coal Agreement (“Assignment”) to transfer and assign all the rights and obligations of Future Gas to the Company to purchase all coal mineral rights owned by JBM under a Coal Buy and Sell Agreement (“Agreement”) dated February 4, 2010. Pursuant to the Assignment and Agreement, the Company paid in cash $150,000 to JBM and signed a 5% promissory note with a face value of $1,750,000 (“Promissory Note 1”) to JBM. During the first 2 years, the note carries no interest. On July 9, 2010 and January 9, 2011 additional cash payments of $200,000 and $200,000, respectively, was paid towards Promissory Note 1. An additional amount of $100,000 is to be paid 90 days following the completion of the Reserve Study and Mining Plan, to be no later than April 9, 2012. Interest only payments on the $1,250,000 balance shall be made quarterly during the third and fourth years, starting July 9, 2012. Starting July 9, 2014, the principal balance of $1,250,000 shall be paid in 8 equal quarterly installments, plus accrued interest on the unpaid principal balance to date of each principal payment. The promissory note to facilitate the agreements is contracted at an interest rate substantially below market rates for similar types of coal properties. Accordingly, the Company imputed a discount of $613,812 at a market interest rate of 16% in accordance FASB ASC 835,”Interest”. Should the Company make all necessary payments as indicated, up until April 9, 2012 and completes the Reserve Study and Mining Plan as anticipated in the agreement, but defaults on the $1,250,000 balance, the coal property will be returned to JBM and the Company will receive a 40% equity interest in JBM and the $1,250,000 balance will be cancelled. Otherwise, if the Company defaults on Promissory Note 1, JBM at its option may terminate the agreement and or initiate action for any other remedy under the law. At September 30, 2011, Promissory Note 1 is presented net of unamortized debt discount of $381,808 (2010 - $528,906). Under the Coal Buy Sell Agreement, JBM will be paid a royalty of $0.25 per ton on all coal when and as mined from the coal property.
41

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 5 – COAL AND OTHER MINERAL PROPERTIES (continued)
On March 31, 2010, the Company, Future Gas Holdings, Ltd. (“Future Gas”) and Russell B. Pace, Jr. (“Pace”) entered into an Assignment and Assumption of Mineral Agreement to transfer and assign all the rights and obligations of Future Gas to the Company to purchase all mineral rights (except coal), oil and gas rights owned by Pace under a Mineral Buy and Sell Agreement dated February 4, 2010. Pursuant to the Mineral Buy and Sell Agreement, the Company issued 1,000,000 shares of its common stock valued at $50,000 ($0.05 per share), signed a 5% promissory note with a face value of $1,950,000 (“Promissory Note 2”). On October 9, 2010 and April 9, 2011 additional cash payments of $200,000 and $200,000, respectively, was paid towards Promissory Note 2. Additional amounts of $100,000 and $200,000 are to be paid 90 days and 180 days, respectively, following the completion of the Reserve Study and Mining Plan, to be no later than April 9, 2012. Interest only payments on the $1,250,000 balance shall be made quarterly during the third and fourth years, starting July 9, 2012. Starting, July 9, 2014, the principal balance of $1,250,000 shall be paid in 8 equal quarterly installments, plus accrued interest on the unpaid principal balance to date of each principal payment. The promissory note to facilitate the agreements is contracted at an interest rate substantially below market rates for similar types of mineral, oil and gas properties. Accordingly, the Company imputed a discount of $680,688 at a market interest rate of 16% in accordance FASB ASC 835, “Interest”. If the Company defaults on Promissory Note 2, Pace at his option may terminate the agreement and or initiate action for any other remedy under the law. At September 30, 2011, Promissory Note 2 is presented net of unamortized debt discount of $395,634 (2010 - $576,823). Under the Mineral Buy Sell Agreement, Pace is due a royalty equal to 20% of all royalties and other payments received by the Company as a result of any lease of the of the mineral property conveyed and 20% of all net cash proceeds and/or other consideration received by the Company from the sale or disposal of the mineral, oil and gas property.
Furthermore, the Company issued 1,000,000 shares of its common stock valued at $50,000 ($0.05 per share) to Future Gas for the assignment of such agreements.
On April 9, 2010, the Company agreed to issue 300,000 common shares of common stock valued at $15,000 ($0.05 per share), to the parties involved in the Assignment of Coal Agreement and Assignment and Assumption of Mineral Agreement as introduction and assignment compensation. The shares were issued on August 27, 2010.
Pursuant to a Consulting Agreement dated as of February 4, 2010 between Pace and Future Gas assigned to the Company on March 31, 2010, Pace agreed to provide consulting services to Future Gas concerning the coal property conveyed to Future Gas by JBM in the Coal Buy and Sell Agreement, and other minerals conveyed to Future Gas by Pace in the Mineral Buy and Sell Agreement. Future Gas agreed to pay Pace $5,000 on the first day of the month following the closing date of the Coal Buy and Sell Agreement and on the first day of each following month during for a period of one year subject to the option of Pace to extend this Consulting Agreement for two successive one year terms. Pace's rights to further compensation under this Consulting agreement will terminate upon termination of the Coal Buy and Sell Agreement by either party as authorized under said Coal Buy and Sell Agreement. Pace agreed to make himself available to perform consulting services for Future Gas for 5 days during each paid month. Future Gas had the option to require Pace to perform consulting services for an additional 5 days during each paid month for an additional $1,000 per each additional day. If Future Gas required more than 10 days per paid month, Pace had the option to decline or if accepted, Future Gas agreed to pay Pace $500 per each additional day. The Consulting Agreement is for services received by the Company after the purchase of the mineral property and is accounted for as an expense in the statements of operations.
NOTE 6 - CAPITAL STOCK
The Company’s capitalization is 500,000,000 shares of common stock with a par value of $0.001 per share. No preferred shares have been authorized or issued.
On August 13, 2007, a former director purchased 44,200,000 shares of the common stock in the Company for $8,500, recognizing a loss of $35,700. During July and August 2008, the Company sold 43,180,000 shares for $3,810, recognizing a loss of $39,370.
On January 25, 2010, a former director forgave a loan in the amount of $16,198 which was owed to the director by the Company.
On January 25, 2010, the Company announced a change in control of the Company. Johannes Petersen, a director of the Company acquired 98.63% of the issued and outstanding shares of stock of the Company from Pamela Hutchinson and Andrea Mizuhima pursuant to the terms and conditions of two Agreements for the Purchase of Common Stock, dated November 20, 2009.
On April 9, 2010, as a result of the execution of the Mineral Buy and Sell Agreement, the Company was obligated to issue 1,000,000 shares of its common stock valued at $50,000 ($0.05 per share) to Russell B. Pace, Jr. The shares were issued on August 27, 2010.
42

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 6 - CAPITAL STOCK – (continued)
On April 9, 2010, the Company agreed to issue 300,000 common shares valued at $15,000 ($0.05 per share) to the parties involved in the Assignment of Coal Agreement and Assignment and Assumption of Mineral Agreement as introduction and assignment compensation. The shares were issued on August 27, 2010.
On April 9, 2010, the Company agreed to issue 1,000,000 shares of common stock valued at $50,000 ($0.05 per share) to JBM Energy Company, LLC in lieu of a $50,000 cash payment due under a Coal Buy and Sell Agreement. The shares were issued on August 27, 2010.
Effective April 30, 2010, the President and Chairman of the Board entered into an agreement with the Company whereby 2,845,800,000 shares of the outstanding common stock of the Company were canceled and returned to the pool of the Company’s authorized and unissued shares of common stock. Since the shares under this agreement have been cancelled without the exchange of consideration to reduce number of shares outstanding, the Company considered the change in capital structure from the cancellation agreement in substance a reverse stock split. In accordance with SAB Topic 4-C, the Company recorded the cancellation retroactively as a reduction to the par value of common stock with a corresponding increase to additional paid-in capital.
Effective April 30, 2010, the Board of Directors authorized a 340 for 1 forward stock split on the issued shares of common stock. The authorized number of shares of common stock was increased from 75,000,000 to 500,000,000 shares with a par value of $0.001. All references in the accompanying financial statements to the number of common shares have been restated to reflect the forward stock split.
On June 30, 2010, the Company closed a private placement consisting of 800,000 shares of common stock at a purchase price of $0.50 per share, for gross proceeds of $400,000.
On August 1, 2010, the Company entered into an independent consultant agreement with CEO and Director Alvaro Valencia in which Mr. Valencia is entitled to receive over a period of 4 years, up to an aggregate amount of 4,000,000 of restricted shares of the Company’s common stock. The shares are to vest and be issued at the end of each three month period. As of September 30, 2011, Mr. Valencia had earned a total of 1,166,667 shares valued at $852,500, of which 166,667 shares valued at $160,000 had been recognized as compensation expense as of September 30, 2010 and 1,000,000 shares valued at $692,500 had been recognized as compensation expense as of September 30, 2011. A total of 500,000 shares were issued to Mr. Valencia on April 5, 2011 and the additional 666,667 were issued subsequent to September 30, 2011.
On September 10, 2010, the Company agreed to enter into a debt to equity conversion as a means of settling the outstanding loan and interest amount of $208,603 by issuing 417,205 shares. The fair value of the shares was $446,410, of which $237,807 was recognized as a loss on debt settlement in the statements of operations.
As of September 30, 2010, the Company recorded $160,000 for stock-based compensation payable related to 166,667 shares of common stock due to Mr. Alvaro Valencia, CEO and director of the Company, valued at the closing price of $0.96 per share of common stock as of September 30, 2010.
On October 5, 2010, the Company entered into a Private Placement Subscription for Non U.S. Subscribers with Black Sands Holdings, Inc., to subscribe to and purchase 595,238 units valued at $0.84 per unit for an aggregate purchase price of $500,000. Each unit comprises one share of common stock and one warrant of the Company. Each warrant entitles the holder to purchase one additional share of common stock of the Company at an exercise price of $1.26 per share for a period of three years.
On January 25, 2011, the Company entered into a Private Placement Subscription for Non U.S. Subscribers with Black Sands Holdings, Inc., to subscribe to and purchase 449,438 units valued at $0.89 per unit for an aggregate purchase price of $400,000. Each unit comprises one share of common stock and one warrant of the Company. Each warrant entitles the holder to purchase one additional share of common stock of the Company at an exercise price of $1.34 per share for a period of three years.
43

AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 6 - CAPITAL STOCK – (continued)
On February 23, 2011, the Company entered into a Private Placement Subscription for Non U.S. Subscribers with Black Sands Holdings, Inc., to subscribe to and purchase 510,204 units valued at $0.98 per unit for an aggregate purchase price of $500,000. Each unit comprises one share of common stock and one warrant of the Company. Each warrant entitles the holder to purchase one additional share of common stock of the Company at an exercise price of $1.47 per share for a period of three years.
On April 5, 2011, the Company issued 417,205 shares to settle the debt to equity conversion agreement entered into during the prior year, as a means of settling an outstanding loan and interest amount of $208,603. The fair value of the shares was $446,410, of which $237,807 was recognized as a loss on debt settlement in the statement of operations in the prior year.
On April 5, 2011, the Company issued a total of 500,000 shares to Mr. Alvaro Valencia, CEO and Director of the Company, as per his Independent Consulting Agreement. These shares were previously recorded as a stock payable.
On August 9, 2011, the Company entered into a Private Placement Subscription for Non U.S. Subscribers with Black Sands Holdings, Inc., to subscribe to and purchase 2,727,273 units valued at $0.22 per unit for an aggregate purchase price of $600,000. Each unit comprises one share of common stock and one warrant of the Company. Each warrant entitles the holder to purchase one additional share of common stock of the Company at an exercise price of $0.33 per share for a period of three years. The shares for this Private Placement were not issued by September 30, 2011 and, as such, the $600,000 proceeds were recorded as stock payable on the balance sheet.
The following is a summary of the common stock warrants granted, forfeited or expired and exercised.

|  | Warrants |  |  | Weighted Average Exercise Price Per Shares |
Outstanding – October 1, 2010 |  |  | 0 |  |  | $ | 0.00 |
Granted |  |  | 4,282,153 |  |  | $ | 0.70 |
Forfeited or expired |  |  | 0 |  |  | $ | 0.00 |
Exercised |  |  | 0 |  |  | $ | 0.00 |
Outstanding – September 30, 2011 |  |  | 4,282,153 |  |  | $ | 0.70 |

As of September 30, 2011, the Company has the following warrants to purchase common stock outstanding:

Number of Warrants Issued |  |  | Warrant Exercise Price Per Share |  | Warrant Expiration Date
| 595,238 |  |  | $ | 1.26 |  | October 5, 2013
| 449,438 |  |  | $ | 1.34 |  | January 25, 2014
| 510,204 |  |  | $ | 1.47 |  | February 23, 2014
| 2,727,273 |  |  | $ | 0.33 |  | August 9, 2014
| 4,282,153 |  |  |  |  |  |

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AMERICAN POWER CORP.
(An Exploration Stage Company)
NOTES TO FINANCIAL STATEMENTS
September 30, 2011 and 2010
(Audited)
NOTE 7 – INCOME TAXES
As of September 30, 2011, the Company had net operating loss carry forwards of $1,158,146 that may be available to reduce future years’ taxable income through 2029 to 2031. Future tax benefits which may arise as a result of these losses have not been recognized in these financial statements, as their realization is determined not likely to occur and accordingly, the Company has recorded a valuation allowance for the deferred tax asset relating to these tax loss carryforwards.
Components of net deferred tax assets, including a valuation allowance, are as follows at September 30, 2011 and 2010:

Deferred tax assets: |  | 2011 |  |  | 2010 |
Net operating loss carryforward |  | $ | 1,158,146 |  |  | $ | 226,869 |
Total deferred tax assets |  | $ | 405,351 |  |  | $ | 79,404 |
Less: Valuation allowance |  |  | (405,351 | ) |  |  | (79,404 | )
Net deferred tax assets |  | $ | - |  |  | $ | - |

The valuation allowance for deferred tax assets as of September, 2011 was $405,351. In assessing the recovery of the deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income in the periods in which those temporary differences become deductible. Management considers the scheduled reversals of future deferred tax assets, projected future taxable income, and tax planning strategies in making this assessment. As a result, management determined it was more likely than not the deferred tax assets would not be realized as of September 30, 2011.
Reconciliation between the statutory rate and the effective tax rate is as follows at September 30, 2011 and 2010:

|  | 2011 |  |  | 2010 |
Federal statutory tax rate |  |  | (35.0 | )% |  |  | (35.0 | )%
Stock-based compensation |  |  | 12.0 | % |  |  | 7.0 | %
Interest accretion |  |  | 6.0 | % |  |  | 9.0 | %
Loss on extinguishment |  |  | 0 | % |  |  | 10.0 | %
Valuation allowance |  |  | 17.0 | % |  |  | 9.0 | %
|  |  | - | % |  |  | - | %

NOTE 8 - SUBSEQUENT EVENTS
On December 12, 2011, the Company issued 2,727,273 shares of common stock to Black Sands Holdings, Inc. to settle a Private Placement Subscription Agreement entered on August 9, 2011. These shares were recorded as stock payable on September 30, 2011.
Additionally, on December 12, 2011, the Company issued 750,000 shares of common stock to Mr. Alvaro J. Valencia, CEO and Director of the Company, in accordance with his Independent Consultant Agreement. Of these shares, 500,000 were recorded as stock payable on September 30, 2011 and 250,000 were fully vested on October 31, 2011.
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