10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-K

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

For the fiscal year ended December 31, 2012

OR

o 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  001-16749

GeoPetro Resources Company

(Exact name of registrant as specified in its charter)

California	94-3214487
(State of incorporation)	(IRS Employer Identification Number)
150 California Street, Suite 600  San Francisco, CA	94111
(Address of principal executive offices)	(Zip Code)

(415) 398-8186

(Registrant’s telephone number, including area code)

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

Title of Each Class	Name of Each Exchange on Which Registered
Common Stock, No Par Value	NYSE MKT US

Securities registered pursuant to Section 12(g) of the Act: None

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

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the 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.

Yes x  No o

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

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

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

Large accelerated filer o	Accelerated filer o
Non-accelerated filer o	Smaller Reporting Company x

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

The aggregate market value of the registrant’s common stock held by non-affiliates was approximately $5,280,094 based on the closing sale price of $0.13 per share as reported by NYSE MKT on June 29, 2012.

The number of shares of the registrant’s common stock outstanding on April 1, 2013 was 48,681,074.

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CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

We are including the following discussion to inform our existing and potential security holders generally of some of the risks and uncertainties that can affect our company and to take advantage of the “safe harbor” protection for forward-looking statements that applicable federal securities law affords.

From time to time, our management or persons acting on our behalf may make forward-looking statements to inform existing and potential security holders about our company. All statements other than statements of historical facts included in this report regarding our financial position, business strategy, plans and objectives of management for future operations, industry conditions, and indebtedness covenant compliance are forward-looking statements. When used in this report, forward-looking statements are generally accompanied by terms or phrases such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “target,” “plan,” “intend,” “seek,” “goal,” “will,” “should,” “may” or other words and similar expressions that convey the uncertainty of future events or outcomes. Items contemplating or making assumptions about actual or potential future sales, market size, collaborations, and trends or operating results also constitute such forward-looking statements.

Forward-looking statements involve inherent risks and uncertainties, and important factors (many of which are beyond our company’s control) that could cause actual results to differ materially from those set forth in the forward-looking statements, including the following: general economic or industry conditions, nationally and/or in the communities in which our company conducts business, changes in the interest rate environment, legislation or regulatory requirements, geological, geophysical, and engineering uncertainties, conditions of the securities markets, our ability to raise capital, changes in accounting principles, policies or guidelines, financial or political instability, acts of war or terrorism, other economic, competitive, governmental, regulatory and technical factors affecting our company’s operations, products, services and prices.

We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. Accordingly, results actually achieved may differ materially from expected results in these statements. Forward-looking statements speak only as of the date they are made. You should consider carefully the statements in “Item 1A. Risk Factors” and other sections of this report, which describe factors that could cause our actual results to differ from those set forth in the forward-looking statements. Our company does not undertake, and specifically disclaims, any obligation to update any forward-looking statements to reflect events or circumstances occurring after the date of such statements.

Readers are urged not to place undue reliance on these forward-looking statements, which speak only as of the date of this report. We assume no obligation to update any forward-looking statements in order to reflect any event or circumstance that may arise after the date of this report, other than as may be required by applicable law or regulation. Readers are urged to carefully review and consider the various disclosures made by us in our reports filed with the United States Securities and Exchange Commission (“SEC”) which attempt to advise interested parties of the risks and factors that may affect our business, financial condition, results of operation and cash flows. If one or more of these risks or uncertainties materialize, or if the underlying assumptions prove incorrect, our actual results may vary materially from those expected or projected.

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GEOPETRO RESOURCES COMPANY

TABLE OF CONTENTS

		Page
PART I
Item 1.	Business	5
Item 1A.	Risk Factors	10
Item 1B.	Unresolved Staff Comments	21
Item 2.	Properties	21
Item 3.	Legal Proceedings	27
Item 4.	Mine Safety Disclosures	27
PART II
Item 5.	Market for the Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities	28
Item 6.	Selected Consolidated Financial Data	31
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	32
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	41
Item 8.	Financial Statements and Supplementary Data	41
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	41
Item 9A.	Controls and Procedures	41
Item 9B.	Other Information	42
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	43
Item 11.	Executive Compensation	51
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	59
Item 13.	Certain Relationships and Related Transactions, and Director Independence	61
Item 14.	Principal Accountant Fees and Services	62
PART IV
Item 15.	Exhibits and Financial Statement Schedules	64
Signatures		65
Glossary of Oil and Natural Gas Terms		66
Index to Consolidated Financial Statements		F-1

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PART I

Item 1.  Business

We were incorporated in the State of Wyoming in August 1994 under the name GeoPetro Company as an oil and gas exploration, development drilling and production company. In June 1996, we merged with our wholly-owned subsidiary, GeoPetro Resources Subsidiary Company, a California corporation, and the resulting merged company is incorporated in the state of California under the California General Corporation Law under the name GeoPetro Resources Company (“GeoPetro”). Our principal and registered office is located at 150 California Street, Suite 600, San Francisco, California, USA 94111.  We maintain a website located at www.geopetro.com.

On February 28, 2013, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”), with MCW Energy Group Limited, an Ontario corporation (“MCW”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“Merger Sub”). Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “Merger”) and the Company will survive the Merger and continue as a subsidiary of MCW. The Merger Agreement has been approved by Boards of Directors of each of the Company, MCW and Merger Sub.  The merger is subject to customary closing conditions, including regulatory and shareholder approval.

Inter-Corporate Relationships

We hold 100% of the shares of Redwood Energy Company (“Redwood”), a Texas corporation.  Redwood is the general partner of, and holds a 5% interest in, Redwood Energy Production, L.P. (“Redwood LP”), a Texas limited partnership. We are the sole limited partner of Redwood LP and own the remaining 95% partnership interest in Redwood LP. Redwood also holds a 100% interest in Madisonville Midstream LLC (“Madisonville Midstream”), a Texas limited liability company.

We hold a 100% interest in GeoPetro Alaska LLC (“GeoPetro Alaska”), an Alaska limited liability company; a 100% interest in GeoPetro Pacific LLC (“GeoPetro Pacific”), a Delaware limited liability company; and a 100% interest in South Texas GeoPetro, LLC (“South Texas GeoPetro”), a Texas limited liability company.

We also hold 100% of the shares of GeoPetro Canada Ltd. (“GeoPetro Canada”), an Alberta corporation; and 100% of the shares of GeoPetro International Ltd., a British Virgin Islands company.

In addition, we hold a 12% interest in Continental-GeoPetro (Bengara II) Ltd. (“C-G Bengara”), a British Virgin Islands company.

General Development of the Business

During the past two years, we conducted leasehold acquisition and exploration activities on our North American prospects. These projects currently encompass approximately 7,853 gross and net acres, consisting of mineral leases and exploration permits that give us the right to explore for, develop and produce oil and natural gas. Most of these properties are in the exploration, appraisal or development drilling phase and have not begun to produce revenue from the sale of oil and natural gas.

In December 2000, we acquired working interests in oil and natural gas leases in the Madisonville Field in Madison County, Texas, including interests in the Rodessa Formation. Also included in the acquisition was the Magness Well, an existing well that had been drilled, cased and production tested in the Rodessa Formation. In October 2001, we re-completed and tested the Magness Well. In October 2002, we drilled, completed and successfully tested an injection well to dispose of waste products resulting from the treating process for gas produced from the Rodessa Formation. The Madisonville Field gas treatment plant and associated pipelines, which were built specifically for this project, were placed into service in May 2003, and the Magness Well began production in late May 2003. The first development well in the Madisonville Field, the Fannin Well, was drilled in 2005. In 2006, we drilled the Wilson and Mitchell wells. Presently, the Fannin and Magness wells are capable of production, while the Mitchell and Wilson wells are shut-in awaiting workovers. We own a 100% working interest in the four wells. Since 2003, substantially all of our revenue has been generated from natural gas sales derived from the Madisonville Field, and the Madisonville Project was our primary source of revenue in 2012.  On December 31, 2008, GeoPetro acquired the gas treatment plant, as well as the related gas gathering pipelines and facilities. This acquisition has allowed the Company to improve operating efficiencies by consolidating the upstream and midstream portions of the Madisonville project. By owning the midstream portion of the Madisonville project, we not only expect better net price realizations and operational efficiencies (i.e. improved volume realizations), but we also control the timing and design of the expansion of the plant facilities as well as future expansions, if needed. Historically, our wells have been production constrained by the gas treatment plant at the Madisonville Field, which has a design treating capacity limit of approximately 18 MMcf/d.  See “Properties — Description of the Properties — Texas — The Madisonville Gas Treatment Plant and Gathering Facilities.”

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Growth Strategy

Our growth strategy is to maximize shareholder value through the exploration and development drilling of oil and natural gas prospects. To carry out this philosophy we employ the following business strategies:

· identify and pursue potential projects which individually have the potential to be “company makers” which we define as projects which could generate a minimum unrisked net present value of $50 million net to our interest using a 10% discount factor;

· perform geological, geophysical and engineering evaluations;

· gain control of key acreage;

· generate high quality drillable exploration and development drilling prospects;

· retain a large working interest in those projects which involve low risk development drilling, appraisal or exploration of proved, probable and possible reserves; and

· minimize early investment and exploration risk in higher risk exploratory prospects through farm-outs and sale of assets to other oil and natural gas companies and maintain meaningful interests with a “carry” through the exploration phase.

Risks Associated With Operations

Our business activities in Canada and the United States are subject to political and economic risks, including: loss of revenue, property and equipment as a result of unforeseen events like expropriation, nationalization, war, terrorist attacks and insurrection; risks of increases in import, export and transportation regulations and tariffs, taxes and governmental royalties; renegotiation of contracts with governmental entities; exchange controls, and numerous other factors. Any one or more of such political or economic conditions could change in the United States or Canada to our detriment. For a related discussion of the risks attendant with our foreign operations, see “Risk Factors.”

Regulations

Domestic exploration, production and sale of oil and gas are extensively regulated at both the federal and state levels. Our business is and will be directly or indirectly affected by numerous governmental laws and regulations applicable to the energy industry, including:

· Federal environmental laws and regulations

· State environmental laws and regulations

· Local environmental laws and regulations

· Federal energy laws and regulations

· Conservation laws and regulations

· Tax and other laws and regulations pertaining to the energy industry

Legislation, rules and regulations affecting the oil and gas industry are under constant review for amendment or expansion, frequently increasing the regulatory burden. Any changes in the existing legislation, rules or regulations could adversely affect our business. The regulatory burdens are often costly to comply with and carry substantial penalties for failure to comply.

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Our operations and activities are subject to numerous federal, state and local environmental laws and regulations. These laws and regulations:

· require the acquisition of permits;

· restrict the type, quantities and concentration of various substances that can be discharged into the environment;

· limit or prohibit drilling and other activities on wetlands and other designated, protected areas;

· regulate the generation, handling, storage, transportation, disposal and treatment of waste materials; and

· impose criminal or civil liabilities for pollution resulting from oil and natural gas operations

We expect that with increases in our exploratory and development drilling activities, the impact of environmental laws and regulations on our business and operations will also increase. We may be required in the future to make substantial outlays of money to comply with environmental laws and regulations. Additional changes in operating procedures and expenditures to comply with future environmental laws cannot be predicted.

We do not operate all of the oil and gas properties in which we own an interest. In those instances, we are not in a position to exert direct control over compliance with most of the rules and regulations discussed above. We are substantially dependent on the operators of our non-operated oil and gas properties to monitor, administer and oversee such compliance. The failure of the operator to comply with such rules and regulations could result in substantial liabilities to us.

As the operator of the Madisonville Project, among other various environmental laws and regulations, we are subject to the U.S. Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and any comparable legislation adopted by Texas which imposes strict, joint and several liability on owners and operators of properties and on persons who dispose of or arrange for the disposal of “hazardous substances” found on or under the sites of such properties.

Under CERCLA, one owner, lessee or other party, having responsibility for and an interest in a site requiring cleanup may, under certain circumstances, be required to bear a disproportionate share of liability for the cost of such cleanup if payments cannot be obtained from other responsible parties. The Resource Conservation and Recovery Act (“RCRA”) and comparable rules adopted by Texas and other states regulate the generation, management and disposal of hazardous oil and gas waste.

The Railroad Commission of Texas (“RRC”) has been delegated the responsibility and authority to regulate and prevent pollution from oil and gas operations, including the prevention of pollution of surface or subsurface water resulting from the drilling of oil and gas wells and the production of oil and gas. In addition to regulating the generation, management and disposal of hazardous oil and gas waste, the RRC has been delegated authority to regulate underground hydrocarbon storage, saltwater disposal pits and injection wells.

The drilling of oil and gas wells in Texas requires operators to obtain drilling permits, file an organization report, issue a performance bond or other form of financial security, such as a letter of credit, and obtain a permit to maintain pits to store and dispose of drilling fluids, saltwater and waste as well as other types of pits for other purposes. The issuance of such permits is conditioned upon the RRC’s determination that these pits will not result in waste or pollution of surface or subsurface water.

Other states in which we have an interest in oil and gas properties may impose similar or more stringent regulations than imposed under CERCLA or RCRA.

To date, we have re-completed an existing producing well and drilled three additional wells and an injection well in the Madisonville Project as operator. In addition, we may drill oil, gas and disposal wells in the future as the operator and will be required to obtain local government and other permits to drill such wells. There can be no assurance that such permits will be available on a timely basis or at all. Texas and other states have statutes or regulations pertaining to conservation matters which, among other matters, regulate the unitization or pooling of gas properties and the spacing, plugging and abandonment of such wells and set limits on the maximum rates of natural gas that can be produced from gas wells.

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In re-completing the existing well on the Madisonville Project, we were required to drill a well for injection or disposal of produced waste gas from the wells. Injection wells are subject to regulation under the Safe Drinking Water Act (“SDWA”) and the regulations and procedures which have been adopted by the Environmental Protection Agency (“EPA”) under that Act. Generally, enforcement procedures under the SDWA are administered by the EPA unless such authority has been delegated by the EPA to a state which has primary enforcement responsibility based on the EPA’s determination that the state has adopted drinking water regulations no less stringent than the national primary drinking water regulations and meets certain other criteria. Underground injection wells not used for the underground injection of natural gas for storage are generally unlawful and subject to penalties under the SWDA unless authorized by:

· permit issued by the EPA or a state having primary enforcement responsibility, or

· rule pursuant to an underground injection control program established by a state or the EPA.

To the extent our pipelines transport natural gas in interstate commerce, the rates, terms and conditions of that transportation service are subject to regulation by the Federal Energy Regulatory Commission (“FERC”), pursuant to Section 311 of the Natural Gas Policy Act of 1978 (“NGPA”), which regulates, among other things, the provision of transportation services by an intrastate natural gas pipeline on behalf of an interstate natural gas pipeline.  Under the Energy Policy Act of 2005, the FERC has authority to impose penalties for violations of the Natural Gas Act, up to $1 million per day for each violation and disgorgement of profits associated with any violation.

The regulatory burden on the oil and natural gas industry increases our cost of doing business.  Future developments, such as stricter requirements of environmental or health and safety laws and regulations affecting our business or more stringent interpretations of, or enforcement policies with respect to, such laws and regulations, could adversely affect us. To meet changing permitting and operational standards, we may be required, over time, to make site or operational modifications at our facilities, some of which might be significant and could involve substantial capital expenditures. There can be no assurance that material costs or liabilities will not arise from these or additional environmental matters that may be discovered or otherwise may arise from future requirements of law.  See “Risk Factors — Risks Related to Our Business”

Foreign Regulations

We own working interests in an oil and gas project located in Canada.  In the exploration, drilling and development of this property, we will be required to comply with the environmental, conservation, tax and other laws and regulations in Canada.

Technology

We participate in projects utilizing economically feasible exploration technology in our exploration and development drilling activities to reduce risks, lower costs, and more efficiently produce oil and gas. We believe that the availability of cost effective 2-D and 3-D seismic data makes its use in exploration and development drilling activities attractive from a risk management perspective in certain areas.

Briefly, through the use of a seismograph, a seismic survey sends pulses of sound from the surface down into the earth, and records the echoes reflected back to the surface. By calculating the speed at which sound travels through the various layers of rock, it is possible to estimate the depth to the reflecting surface. It then becomes possible to infer the structure of rock deep below the earth’s surface. We evaluate substantially all of our exploratory prospects using 2-D seismic data. In addition, we own a license as to approximately 12 square miles of 3-D seismic data covering our leasehold and adjacent lands in the Madisonville Project.

The use of seismic technology does not entirely remove the risk of exploration and development drilling of oil and natural gas deposits. It is important to consider the following:

· we may not recognize significant geological features due to errors in interpretation, processing limitations, the presence of certain geological environments that are out of our control or other factors;

· seismic generally becomes less reliable with increasing depth of the geological horizon; and

· the use of this technology may increase our finding cost.

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Principal Products

Our principal product is natural gas produced from properties in which we own an interest. Since our inception, we have realized only limited production of natural gas from the properties in which we own an interest. We also have working interests in various undeveloped oil and gas properties. See “Properties” for a general description of these properties.

During the last two fiscal years, 100% of our revenues have been derived from the sale of natural gas. Substantially all of our natural gas sales have been generated by three producing wells located in the Madisonville Field in East Texas. Natural gas produced by the wells is delivered via a gathering pipeline to a nearby gas treatment plant where the gas is treated to remove impurities. From the plant, the natural gas is transported approximately nine miles to one of two common carrier pipelines. This delivery point is where all natural gas sales occur. The price received for the natural gas is the Houston Ship Channel price index less certain adjustments.

Reserves

The volume of production from oil and natural gas properties generally declines as reserves are depleted, with the rate of decline depending on reservoir characteristics. Our proved reserves will decline as reserves are produced from our properties unless we are able to acquire or develop new reserves.

Acquisition of Producing Properties

We may supplement our exploration efforts with acquisitions of producing oil and gas properties. We may seek to acquire producing properties that are underperforming relative to their potential.

Patents, Trademarks, Licenses, and Franchises Held

Permits and licenses are important to our operations, since they allow the search for and the extraction of any oil, gas and minerals discovered on the areas covered.. See “Properties” for a general description of the permits and licenses under which we operate.

Seasonality of Business

Our business is not seasonal.

Working Capital Items

The majority of our current assets are in the form of cash received from the sale of natural gas from our Madisonville Project in Texas, amounts received from the sale of common and preferred stock in private placements, cash received from the issuance of debt instruments and cash received from the disposition of our interests in oil and gas properties. We use this cash to pay for the cost of our operations, service of debt facilities, and other administrative activities. For further information see “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Customers

Substantially all of our revenues are derived from sales to two customers, Luminant Energy Company, LLC and ETC Katy Pipeline, Ltd., of natural gas produced from our Madisonville Project in Texas. We contract to sell the gas with spot-market based contracts that vary with market forces. We have not committed any forward sales of our natural gas. During 2012 all of our revenue was derived from one customer.  The loss of this customer could result in the loss of our revenues, which would have a material adverse effect on our results of operations.  See “Risk Factors”.

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Competition

The oil and natural gas industry is intensely competitive and speculative in all of its phases. We encounter competition from other oil and natural gas companies in all areas of our operations. In seeking suitable oil and natural gas properties for acquisition, we compete with other companies operating in our areas of interest, including large oil and natural gas companies and other independent operators, which have greater financial resources and in many instances, have been engaged in the exploration and production business for a much longer time than we have. Many of our competitors also have substantially larger operating staffs than we do. Many of these competitors not only explore for and produce oil and natural gas but also market oil and natural gas and other products on a regional, national or worldwide basis. These competitors may be able to pay more for productive oil and natural gas properties and exploratory prospects and define, evaluate, bid for and purchase a greater number of properties and prospects than us. In addition, these competitors may have a greater ability to continue exploration activities during periods of low market prices. Our ability to acquire additional properties and to discover reserves in the future will depend on our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment.

The prices of our natural gas production are controlled by market forces. However, competition in the oil and natural gas exploration industry also exists in the form of competition to acquire leases and obtain favorable transportation prices. Our Company is relatively small and may have difficulty acquiring additional acreage and/or projects and may have difficulty arranging for the transportation of our production. We also face competition in obtaining oil and natural gas drilling rigs and in sourcing the manpower to run them and provide related services.

Employees

We have 6 employees. We use the services of independent consultants and contractors to perform various professional services, including geologic, geophysical, petroleum, reservoir & drilling engineering, land, legal, environmental and tax services. On those properties where we are not the operator, we rely on outside operators to drill, produce and market our oil and natural gas.

Available Information

We maintain a website located at http://www.geopetro.com and electronic copies of our annual, quarterly and current reports, and any amendments to those reports, as well as our code of ethics, are available free of charge under the Investor Relations link on our website.  This information is available on our website, as soon as practicable after such material is filed with, or furnished to, the SEC.

Item 1A.  Risk Factors

In addition to risks and uncertainties in the ordinary course of business that are common to all businesses, important factors that are specific to our industry and our company could materially impact our future performance and results of operations. We have provided below a list of these risk factors that should be reviewed when considering our securities. These are not all the risks we face and other factors currently considered immaterial or unknown to us may impact our future operations.

Risks Related to Our Business

Because of our historic losses from operations since inception, there is substantial doubt about our ability to continue as a going concern.

In their report dated April 16, 2013, our independent registered public accounting firm stated that our financial statements for the year ended December 31, 2012, were prepared assuming that we would continue as a going concern. We have incurred recuring losses that have resulted in an accumulated deficit attributable to common stockholders of approximately $49,700,000 as of December 31, 2012. Although we had approximately $59,000 of available cash at December 31, 2012, that amount is not adequate to meet our capital expenditure and operating requirements over the next 12 months. These factors raise substantial doubt about the ability of the Company to continue as a going concern. We are dependent upon obtaining funds from financing sources to meet our cash flow requirements. If we are unsuccessful in doing so, we would be required to substantially reduce our business plan or our business could be substantially impaired.

As of December 31, 2012, we have gross capitalized costs totaling $65.1 million as proved and unproved oil and gas properties and gas processing plant whereas we have generated revenues of only $44.5 million since January 1, 2003 and revenues of only $351 thousand during the fiscal year ended December 31, 2012.

Since inception, our activities have been primarily related to acquiring and exploring leasehold interests in oil and natural gas properties in Texas, California, Alaska, Canada, Indonesia and Australia. We have incurred substantial acquisition and exploration costs and overhead expenses in our operations, and until 2003, excluding minor interest and dividend income, our only significant cash inflows were the recovery of capital invested in projects through sale or other divestitures of interests in oil and gas prospects to industry partners. As a result, we have sustained an accumulated deficit through December 31, 2012 of $49.7 million. Our production activities commenced in May 2003. Since May 2003, over 98% of our revenue has been generated from natural gas sales derived from wells in the Madisonville Field in Texas. It is possible that in the future we will be unable to continue to generate revenues from our sales of natural gas from our Madisonville Field wells because our proved reserves decline as reserves are produced from the wells. The drilling of exploratory oil and natural gas wells is highly speculative and often unproductive. Our participation in future drilling activities to explore, develop and exploit the properties in which we have an interest, or in which we may acquire interests, may be unsuccessful, may fail to generate positive cash flow, and may not enable us to maintain profitability in the future.

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We may be unable to successfully expand the capacity of the Madisonville Gas Treatment Plant.

We own and operate, through Madisonville Midstream, gathering pipelines and a dedicated natural gas treatment plant (which we refer to as the Madisonville Gas Treatment Plant), to treat impurities in the natural gas generated by our Madisonville Project.  We plan to expand the Madisonville Gas Treatment Plant’s treatment capacity from 18 MMcf/d to 30 MMcf/d.  There can be no assurance that we will be able to accomplish the expansion and achieve a full treatment capacity of 30 MMcf/d.

Even if we are able to successfully complete the expansion of the Madisonville Gas Treatment Plant from 18 MMcf/d to 30 MMcf/d, third parties may seek access to the plant through regulatory proceedings, which could limit our use of the Plant and disrupt our production operations.

Third parties have, and may in the future, seek access to the Madisonville Gas Treatment Plant through regulatory proceedings, which could restrict our access to the Plant, disrupt our production operations and negatively impact our revenues.  An example of such a proceeding is the complaint that was filed by Crimson Exploration Inc. (“Crimson”) with the Railroad Commission of Texas in 2006 described under “Properties — Description of the Properties — Texas — The Madisonville Gas Treatment Plant and Gathering Facilities.”

Substantially all of our revenues have been generated from natural gas sales derived from wells in the Madisonville Field, and 100% of our natural gas generated from the wells in the Madisonville Field is treated at the Madisonville Gas Treatment Plant.  If our ability to treat natural gas at the Madisonville Gas Treatment Plant is limited for any reason, including but not limited to increased demands by third parties, our revenues may be adversely affected.

All of our current revenues are generated by our interest in the Madisonville Project. Delays or interruptions of the Madisonville Project natural gas drilling and production operations including, but not limited to, events beyond our control or the failure of third parties on which we rely to provide key services, could negatively impact our revenues.

All of our natural gas revenues for 2012 were derived from the Madisonville Project. In connection with that project, we have contracted with Gateway-Madisonville Pipeline, LLC (“Gateway”) which operates a sales pipeline for natural gas.

The failure of Gateway to perform its contractual obligations to us could impose delays or interruptions in our production operations and prevent us from generating revenues. In addition, events which are beyond our control, or that of Gateway, could affect our production operations. Such events include, but are not limited to:

· events referred to as force majeure, such as an act of God, act of a public enemy, war, blockade, public riot, lightning, fire, storm, flood, explosion and any other causes whether of the kind enumerated or otherwise not reasonably within the control of Gateway;

· the inability to secure raw materials or equipment;

· transportation accidents; and

· labor disputes and equipment failures.

We do not own all of the land on which our pipelines and facilities are located, and we are therefore subject to the possibility of not being able to retain necessary land use and associated increased costs.

We have the right to operate our pipelines on land owned by third parties for specified periods of time.  Our loss of these rights, through our inability to renew rights-of-way contracts, leases or otherwise, could result in the suspension of our operations, or increased costs related to continuing operations elsewhere, which would have a material adverse effect on our business, results of operations and financial condition.

If third-party pipelines and other facilities interconnected to our natural gas pipelines and processing facilities become partially or fully unavailable to transport natural gas, our revenues could be adversely affected.

We depend upon third party pipelines and other facilities to provide delivery options from the Madisonville Gas Treatment Plant to our customers.  If any of these third party pipelines become unavailable to transport the natural gas produced at the Plant, or if the gas quality specifications for these pipelines or facilities change, we would be required to find alternate means to transport our natural gas out of the Plant, which could increase our costs, reduce the revenues we might obtain from the sale of our natural gas or reduce our ability to process natural gas at the Plant.

11

100% of our revenue in 2012 was derived from sales to a single customer. The loss of this customer could have a material adverse impact on our oil and gas revenues.

100% of our natural gas sales and revenue for the year ended December 31, 2012 were derived from the Madisonville Project, and 100% of our revenue was derived from sales to one customer, Luminant Energy Company, LLC.  The loss of this customer could impact the price we receive for our gas sold due to lessened competition. The loss of, or material nonpayment by the customer could result in a loss of revenue.  Our customer may be subject to their own operating risks which could increase the risk that they could default on their obligation to us.

Unless we replace our oil and natural gas reserves, our reserves and production will decline.

The volume of production from oil and natural gas properties generally declines as reserves are depleted, with the rate of decline depending on reservoir characteristics. Our proved reserves will decline as reserves are produced from our properties unless we are able to acquire or develop new reserves. The business of exploring for, developing or acquiring reserves is capital intensive. For example, as of December 31, 2012 we have capitalized costs of $65.1 million as proved and unproved oil and gas properties and gas processing plant. To the extent cash flow from operations is reduced and external sources of capital become limited or unavailable, our ability to make the necessary capital investment to maintain or expand our asset base of oil and natural gas reserves will be impaired. Even if we are able to raise capital to develop or acquire additional properties, no assurance can be given that our future exploration and development drilling activities will result in the discovery of any reserves.

Our exploration and development drilling activities may not be commercially successful. The drilling of exploratory oil and natural gas wells is expensive, highly speculative and often unproductive.

Exploration for oil and natural gas on unproven prospects is expensive, highly speculative and involves a high degree of risk, including the risk that no commercially productive oil or natural gas reservoirs will be encountered. Reserves are dependent on our ability to successfully complete drilling activity on proven prospects.

The cost of drilling, completing and operating wells is often uncertain, and drilling operations may be curtailed, delayed or cancelled as a result of a variety of factors, including:

· unexpected drilling conditions, pressure or irregularities in formations;

· subsurface conditions or formations encountered during the drilling of wells, whether natural or mechanical, including but not limited to blowout, igneous rock, salt, saltwater flow, loss of circulation, loss of hole, abnormal pressures, or any other impenetrable substance or adverse condition, which renders further drilling of a well impossible or impractical;

· equipment failures or accidents, adverse weather conditions;

· compliance with governmental requirements; and

· shortages or delays in the availability of drilling rigs, the delivery of equipment, and availability of qualified manpower.

Our evaluations of the oil and gas prospects of our properties may be wrong.

With the exception of the Madisonville Project, the properties in which we have an interest are prospects in which the presence of oil and natural gas reserves in commercial quantities has not been established. Any decision to engage in exploratory drilling or other activities on any of these properties will be dependent in part on the evaluation of data compiled by petroleum engineers and geologists and obtained through geophysical testing and geological analysis.

12

Reservoir engineering, geophysics and geology are not exact sciences and the results of studies and tests used to make such evaluations are sometimes inconclusive or subject to varying interpretations. As such, there is no certain way to know in advance whether any of our prospects will yield oil and natural gas in commercial quantities. Further, it is possible that we will participate in the drilling of more dry holes than productive wells or that all or substantially all of the wells drilled will be dry holes. The drilling of dry holes on prospects in which we have an interest could adversely affect their values and our decision to undertake further exploration and development drilling of such prospects. It is not certain or predictable whether, and no assurance can be made that, the wells drilled on the properties in which we have an interest will be productive or, if productive, that we will recover all or any part of our investment in the properties. In summary, our participation in future drilling activities may not be successful and, if unsuccessful, such failure may negatively impact our revenues and have a material adverse effect on our results of operations and financial condition. Our natural gas revenue was $351,082 for the year ended December 31, 2012. Future revenue could decline from this level if our future drilling efforts are not successful. Furthermore, as of December 31, 2012 we have net capitalized costs totaling approximately $23 million as proved and unproved oil and gas properties and gas processing plant. Should our future drilling activities be unsuccessful, we may then be required to record an impairment charge equal to a portion of, or all, of the capitalized costs resulting in an immediate adverse impact on our results of operations and financial position.

Our business may be harmed by failures of third party operators on which we rely.

Our ability to manage and mitigate the various risks associated with certain exploration and operations in Alaska and Australia is limited since we rely on third parties to operate our projects. We are a non-operating interest owner in our Alaskan and Australian properties. With respect to our interests in Alaska and Australia, we have entered into agreements with third party operators for the conduct and supervision of drilling, completion and production operations. In the event that commercial quantities of oil and natural gas are discovered on one of our properties, the success of the oil and natural gas operations on that property depends in large measure on whether the operator of the property properly performs its obligations. The failure of such operators and their contractors to perform their services in a proper manner could result in materially adverse consequences to the owners of interests in that particular property, including us.

Our working interest in properties, and our ability to realize any profits from such properties, will be diminished to the extent that we enter into farm-out arrangements with unaffiliated third parties.

We have previously entered into, and may in the future enter into, farm-out arrangements with third parties willing to drill oil and natural gas wells on leaseholds in which we originally acquired working interests, in exchange for our assignment of part or all of our leasehold interests. As a consequence of these arrangements, our retained interests in properties which are subject to farm-out arrangements have been or may be diminished. Our opportunity to realize revenues and profits from properties which are successfully developed under farm-out arrangements will be diminished to the extent of our reduced interests.

Competition with other oil and natural gas exploration and development drilling companies for viable oil and natural gas properties may limit our success.

It is likely that in seeking future property acquisitions, we will compete with companies which have substantially greater financial and management resources. Our competition comes primarily from three sources:

(1) those competitors that are seeking oil and gas fields for expansion, further drilling, or increased production through improved engineering techniques;

(2) income-seeking entities purchasing a predictable stream of earnings based upon historic production from fields being acquired; and

(3) junior companies seeking exploration opportunities in unknown, unproven territories.

Our competitors may be able to pay more for productive oil and natural gas properties and may be able to define, evaluate, bid for and purchase a greater number of properties and prospects than we can. Our ability to acquire additional properties in the future will depend upon our ability to conduct efficient operations, evaluate and select suitable properties, implement advanced technologies and consummate transactions in a highly competitive environment.

13

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

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

Competitive pressures may force us to implement new technologies at substantial cost and our limited financial resources may limit our ability to implement such technologies at the same rate as our competitors.

The oil and gas industry is characterized by rapid and significant technological advancements and introductions of new products and services utilizing new technologies. Other oil and gas companies may have greater financial, technical and personnel resources that allow them to enjoy technological advantages and may in the future allow them to implement new technologies before we do. There can be no assurance that we will be able to respond to such competitive pressures and implement such technologies on a timely basis or at all. One or more of the technologies currently utilized by us or implemented in the future may become obsolete.

We will require additional capital to fund our future activities. Our ability to pursue our business plan may be restricted by our access to additional financing.

Until such time as the properties in which we own interests are generating sufficient cash flow to fund planned capital expenditures, we will be required to raise additional capital through the issuance of additional securities or otherwise sell or farm-out interests in our oil and natural gas properties to third parties. If and when the properties in which we own interests become productive and have adequate reserves, we may borrow funds to finance our future oil and natural gas operations and exploratory and development drilling activities. We may not be able to raise additional funds in the future from any source or, if such additional funds are made available to us, we may not be able to obtain such additional financing on terms acceptable to us. To the extent such funds are not available from any of those sources, our operations and activities will be limited to those operations and activities we can afford with the funds then available to us. Our larger competitors, by reason of their size and relative financial strength, may be more easily able to access capital markets than us.

The volatility in crude oil and natural gas prices could adversely affect our financial results and ability to raise additional capital.

Our revenues, cash flows and profitability are substantially dependent on prevailing prices for both oil and natural gas. Decreases in natural gas prices will decrease revenues and cash flows from the Madisonville Project and our other producing properties, if any, and decreases in oil and natural gas prices could deter potential investors from investing in our company and generally impede our ability to raise additional financing to fund our exploration and development drilling activities. Historically, oil and natural gas prices and markets have been volatile, and they are likely to continue to be volatile in the future. Prices for oil and natural gas are subject to wide fluctuations in response to relatively minor changes in the supply of, and demand for, oil and natural gas, market uncertainty and a variety of additional factors that are beyond our control. These factors include, but are not limited to, political conditions in the Middle East and other regions, internal and political decisions of OPEC and other oil and natural gas producing nations to decrease or increase production of crude oil, domestic and foreign supplies of oil and natural gas, consumer demand, weather conditions, domestic and foreign government regulations and taxation, transportation costs, the price and availability of alternative fuels, the impact of energy conservation efforts and overall economic conditions.

14

Risks associated with recent economic trends have adversely affected, and could further adversely affect our financial performance.

The global financial markets experienced volatility in the past few years, including diminished liquidity and credit availability. We believe these conditions have adversely impacted our financial position as of December 31, 2012 and our liquidity for the twelve months ended December 31, 2012.  Our financial condition and performance could be further negatively impacted if these conditions continue to exist for a sustained period of time, or if there is further deterioration in financial markets and major economies. We are unable to predict the likely duration and severity of the current disruption in financial markets and adverse economic conditions in the U.S. and abroad.

We are subject to a number of operational risks beyond our control against which we may not have, or be able to obtain insurance.

Our operations are subject to the many risks and hazards incident to exploring and drilling for, and producing and transporting, oil and natural gas, including among other risks:

· blowouts, fires, craterings, pollution and equipment failures that may result in damage to or destruction of wells, pipelines, producing formations, production facilities and equipment;

· damage to pipelines, facilities and properties caused by hurricanes, tornados, floods and other natural disasters;

· personal injuries or death due to accidents, human error or acts of God;

· unavailability of materials and equipment to drill and complete or re-complete wells; unfavorable weather conditions; engineering and construction delays;

· fluctuations in product markets and prices; proximity and capacity of pipeline, and trucking or termination facilities to our oil and natural gas reserves; hazards resulting from unusual or unexpected geological or environmental conditions; environmental regulations and requirements;

· accidental leakage of toxic or hazardous materials, such as petroleum liquids or drilling fluids into the environment, remediation and clean-up costs; and

· political instability and civil unrest, insurrections or disruptions in foreign countries in which some of our interests are located.

If one or more of these events occurs, we could incur substantial liabilities to third parties or governmental entities, the payment of which could have a material adverse effect on our financial condition and results of operations, or we could lose properties in which we have capitalized as proved and unproved oil and gas properties and gas processing plant as of December 31, 2012.

A loss not covered by insurance could result in substantial expenses to us.

We do not insure fully against all business risks either because such insurance is not available or because premium costs are prohibitive.  We are not insured against all environmental accidents that might occur which may include toxic tort claims. If a significant accident or event occurs that is not fully insured, if we fail to recover all anticipated insurance proceeds for significant accidents or events for which we are insured, or if we fail to rebuild facilities damaged by such accidents or events, our operations and financial condition could be adversely affected. In addition, we may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for certain of our insurance policies have increased substantially, and could escalate further. For example, following Hurricanes Katrina and Rita, insurance premiums, deductibles and co-insurance requirements increased substantially, and terms generally are less favorable than terms that could be obtained prior to such hurricanes.  In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage.  A loss not fully covered by insurance could result in expenses to us and could have a material adverse effect on our financial position and results of operations.

15

We are subject to extensive government regulations that can change from time to time, compliance with which are costly and could negatively impact our production, operations and financial results.

The oil and gas industry is subject to extensive government regulations in the countries in which we operate. Matters subject to regulation include discharge permits for drilling operations, drilling bonds, reports concerning operations, unitization and pooling of properties and taxation. Historically, our costs of complying with these regulations have not exceeded $100,000 per year. From time to time, regulatory agencies have imposed price controls and limitations on production by restricting the rate of flow of oil and natural gas wells below actual production capacity in order to conserve supplies of oil and natural gas. We are also subject to changing and extensive tax laws, the effects of which cannot be predicted. Legal requirements are frequently changed and subject to interpretation, and we are unable to predict the ultimate cost of compliance with these requirements or their effects on our operations. Future laws, or existing laws or regulations, as currently interpreted or reinterpreted or changed in the future, could result in increased operating costs, fines and liabilities, in amounts which are unknown at this time, any of which could materially adversely affect our results of operations and financial condition.

Our industry is subject to extensive environmental regulation that may limit our operations and negatively impact our production.

Extensive national, state, provincial and local environmental laws and regulations in the United States and foreign jurisdictions affect nearly all of our operations.  Environmental laws to which we are subject in the U.S. include, but are not limited to, (1) the Clean Air Act and comparable state laws that impose obligations related to air emissions, (2) the Resource Conservation and Recovery Act of 1976 (“RCRA”), and comparable state laws that impose requirements for the handling, storage, treatment or disposal of solid and hazardous waste from our facilities, (3) the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and comparable state laws that regulate the cleanup of hazardous substances that may have been released at properties currently or previously owned or operated by us or at locations to which our hazardous substances have been transported for disposal, and (4) the Clean Water Act, and comparable state laws that regulate discharges of wastewater from our facilities to state and federal waters and (5) the California Environmental Quality Act (“CEQA”), which is a statute that requires state and local agencies to identify the significant environmental impacts of their actions and to avoid and mitigate these impacts, if feasible. Failure to comply with these laws and regulations or newly adopted laws or regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial requirements, and the issuance of orders enjoining future operations or imposing additional compliance requirements on such operations. Certain environmental laws, including CERCLA and analogous state laws, impose strict, joint and several liability for costs required to clean up and restore sites where hazardous substances or hydrocarbons have been disposed or otherwise released.  Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances, hydrocarbons or other waste products into the environment.

Environmental legislation may require that we:

· acquire permits before commencing drilling;

· restrict spills, releases or emissions of various substances produced in association with our operations;

· limit or prohibit drilling activities on protected areas such as wetlands or wilderness areas;

· take reclamation measures to prevent pollution from former operations;

· take remedial measures to mitigate pollution from former operations, such as plugging abandoned wells and remedying contaminated soil and groundwater;

· take remedial measures with respect to property designated as a contaminated site.

There is inherent risk of incurring environmental costs and liabilities in connection with our operations due to our handling of natural gas and other petroleum products, air emissions and water discharges related to our operations, and historical industry operations and waste disposal practices.  The costs of any of these liabilities are presently unknown but could be significant.  We may not be able to recover all or any of these costs from insurance.

16

We are not presently aware of any environmental liabilities or able to predict the ultimate cost of liabilities not yet recognized.  We have not established a separate reserve fund for the purpose of funding any possible future environmental liability.  As a result, we may not be able to satisfy these obligations, if they occur.  Any such costs incurred will be funded out of our cash flow from operations.  If we are unable to fully fund the cost of remedying an environmental obligation, we might be required to suspend operations or enter into interim compliance measures pending satisfaction of the liability, which could have an adverse affect on our financial condition and results of operations.  We have recorded an asset requirement obligation in connection with the estimated future costs to plug certain wells at our Madisonville Project in Texas upon abandonment totaling $75,000 as of December 31, 2012.

The effects of future environmental legislation on our business are unknown but could be substantial.

Environmental legislation is evolving in a manner expected to result in stricter standards and enforcement, larger fines and liability and potentially increased capital expenditures and operating costs. Changes in, or enforcement of, environmental laws may result in a curtailment of our production activities, or a material increase in the costs of production, development drilling or exploration, any of which could have a material adverse effect on our financial condition and results of operations or prospects. In addition, many countries, as well as several states in the United States have agreed to regulate emissions of “greenhouse gases.”  Methane, a primary component of natural gas, and carbon dioxide, a byproduct of burning natural gas, are greenhouse gases.  Regulation of greenhouse gases could adversely impact some of our operations and demand for products in the future.

Potential regulations regarding climate change could alter the way we conduct our business.

Governments around the world are beginning to address climate change matters. This may result in new environmental regulations that may unfavorably impact us, our suppliers and our customers. The cost of meeting these requirements may have an adverse impact on our financial condition, results of operations and cash flows.

Should we fail to comply with all applicable FERC administered statutes, rules, regulations and orders, we could be subject to substantial penalties and fines.

Under the Energy Policy Act of 2005, FERC has authority to impose penalties for violations of the Natural Gas Act, up to $1 million per day for each violation and disgorgement of profits associated with any violation.  FERC has recently proposed and adopted regulations that may subject our facilities to reporting and posting requirements.  Additional rules and legislation pertaining to these and other matters may be considered or adopted by FERC from time to time.  Failure to comply with FERC regulations could subject us to civil penalties.

We may incur significant costs and liabilities as a result of pipeline integrity management program testing and any related pipeline repair or preventative or remedial measures.

The United States Department of Transportation has adopted regulations requiring pipeline operators to develop integrity management programs for transportation pipelines located where a leak or rupture could do the most harm in “high consequence areas.”  The regulations require operators to:

· perform ongoing assessments of pipeline integrity;

· identify and characterize applicable threats to pipeline segments that could impact a high consequence area;

· improve data collection, integration and analysis;

· repair and remediate the pipeline as necessary; and

· implement preventive and mitigating actions.

Political and/or economic conditions in Canada or the United States could change in manners that negatively affect our operations and prospects in those countries.

Our business activities in Canada and the United States are subject to political and economic risks, including: loss of revenue, property and equipment as a result of unforeseen events like expropriation, nationalization, war, terrorist attacks and insurrection; increases in import, export and transportation regulations and tariffs, taxes and governmental royalties; renegotiation of contracts with governmental entities; changes in laws and policies governing operations of foreign-based companies; exchange controls, currency fluctuations and other uncertainties arising out of foreign government sovereignty over international operations; laws and policies affecting foreign trade, taxation and investment; and the possibility of being subject to the exclusive jurisdiction of foreign courts in connection with legal disputes and the possible inability to subject foreign persons to the jurisdiction of courts in the United States.

17

Terrorist attacks could have an adverse effect on our oil and natural gas operations, especially overseas.

To date, our operations have not been disrupted by terrorist activity. It is uncertain how terrorist activity will affect us in the future, or what steps, if any, the Canadian or American governments may take in response to terrorist activities. The attack on the New York World Trade Center in 2001 and the subsequent wars in Afghanistan and Iraq and continued political unrest in the Middle East increase the likelihood that U.S. citizens and U.S. owned interests may be targeted by terrorist groups operating both in the United States and in foreign countries.

We could lose our ownership interests in our properties due to a title defect of which we are not presently aware.

As is customary in the oil and gas industry, only a perfunctory title examination, if any, is conducted at the time properties believed to be suitable for drilling operations are first acquired. Before starting drilling operations, a more thorough title examination is usually conducted and curative work is performed on known significant title defects. We typically depend upon title opinions prepared at the request of the operator of the property to be drilled. The existence of a title defect on one or more of the properties in which we have an interest could render it worthless and could result in a large expense to our business. Industry standard forms of operating agreements usually provide that the operator of an oil and natural gas property is not to be monetarily liable for loss or impairment of title. The operating agreements to which we are a party provide that, in the event of a monetary loss arising from title failure, the loss shall be borne by all parties in proportion to their interest owned.

Our acquisition activities are subject to uncertainties and may not be successful or provide a return to us on our investments.

We have grown primarily through acquisitions and intend to continue acquiring undeveloped oil and gas properties. Although we perform a review of the properties proposed to be acquired, such reviews are subject to uncertainties. It generally is not feasible to review in detail every individual property involved in an acquisition. Ordinarily, management review efforts are focused on the higher-valued properties; however, even a detailed review of all properties and records may not reveal existing or potential problems; nor will it permit us to become sufficiently familiar with the properties to assess fully their deficiencies and capabilities. Inspections are not always performed on every well, and potential problems, such as mechanical integrity of equipment and environmental conditions that may require significant remedial expenditures, are not necessarily observable even when an inspection is undertaken.

We are dependent upon our key officers and employees and our inability to retain and attract key personnel could significantly hinder our growth strategy and cause our business to fail.

While no assurances can be given that our current management resources will enable us to succeed as planned, a loss of one or more of our current directors, officers or key employees could severely and negatively impact our operations and delay or preclude us from achieving our business objectives. We could suffer the loss of key individuals for one reason or another at any time in the future. Stuart Doshi and David Creel, two members of our senior management team, have a combined experience of approximately 80 years in the oil and gas industry. There is no guarantee that we could attract or locate other individuals with similar skills or experience to carry out our business objectives. We maintain “key man” insurance with respect to our Chief Executive Officer, Stuart Doshi.

Some of our directors may become subject to conflicts of interest which could impair their abilities to act in our best interest.

David Anderson, one of our directors, is vice chairman and officer of Dundee Securities Ltd., an investment banking firm that was the lead underwriter of our public offering of common stock in Canada and concurrent previous private placement of common shares with qualified institutional buyers in the U.S. The association with other companies in the oil and gas business may give rise to conflicts of interest from time to time. For example, they could be presented with business opportunities in their capacities as our directors, which they could, in turn, offer to the other companies for whom they also serve as directors, rather than to us, whose interests might be competitive with ours. Our directors are required by law to act honestly and in good faith with a view to our best interests and to disclose any interest which they may have in any project or opportunity to us; however, their interests in the other companies may affect their judgment and cause such directors to act in a manner that is not necessarily in our best interests.

Our directors and officers hold significant positions in our shares and their interests may not always be aligned with those of our other shareholders.

As of December 31, 2012 our directors and officers beneficially own approximately 13% of our outstanding common stock. This shareholding level will allow the directors, officers and certain beneficial owners to have a significant degree of influence on matters that are required to be approved by shareholders, including the election of directors and the approval of significant transactions. The short-term interests of our directors, officers and certain beneficial owners may not always be aligned with the long-term interests of our public shareholders, and vice versa. Because our directors, officers and certain beneficial owners have a significant degree of influence on matters that are required to be approved by our shareholders, they could influence the approval of transactions.

18

Our failure to manage internal or acquisition-based growth may cause operational difficulties and negatively affect our financial performance.

We expect to experience internal and/or acquisition-based growth, which may bring many challenges. Growth in the number of employees, sales and operations will place additional pressure on already limited resources and infrastructure. No assurances can be given that we will be able to effectively manage this or future growth. Our growth may place a significant strain on our managerial, operational, financial and other resources. Our success will depend upon our ability to manage our growth effectively which will require that we continue to implement and improve our operational, administrative, financial and accounting systems and controls and continue to expand, train and manage our employee base. Our systems, procedures and controls may not be adequate to support our operations and our management may not be able to achieve the rapid execution necessary to exploit the market for our business model. If we are unable to manage internal and/or acquisition-based growth effectively, our business, results of operations and financial condition may be materially adversely affected.

Risks associated with our liquidity.

In 2013 we will need to raise capital.  Due to our liquidity issues, funds may not be available, or may be available only on unfavorable terms. Due to the decrease in our stock price, we may need to sell more shares to raise the same amount of money than we would have in the past, resulting in greater dilution to existing shareholders than would be the case if our stock price was higher and this trend could continue.  We have scheduled exploratory and development well drilling and workover activity during 2013 and future periods on our proved and unproved properties. It is anticipated that these activities together with others that we may undertake will impose financial requirements which will exceed our existing working capital. We may raise additional equity and/or debt capital, and we may farm-out certain of our projects to finance our continued participation in planned activities; however, if additional financing is not available, we may be compelled to reduce the scope of our business activities. If we are unable to fund planned expenditures, it may be necessary to:

· farm-out our interest in proposed wells;

· sell a portion of our interest in prospects and use the sale proceeds to fund our participation for a lesser interest;

· forfeit our interest in wells that we propose to drill; and

· reduce general and administrative expenses.

Further, considering our liquidity issues, we may have to resort to raising capital or selling assets on less favorable terms than may otherwise be available.

Risks Related to Our Common Stock

The shareholding position of holders of our common stock could be diluted by future issuances and conversions of other securities.

If our options and warrants are exercised for common shares, holders of our common stock will experience immediate and, depending on the magnitude of the exercises, substantial dilution. As of April 1, 2013, there are 48,681,074 shares of our common stock outstanding, 5,370,027 shares of our Series B Preferred stock outstanding, 7,026,265 shares of our common stock are issuable upon exercise of warrants and 3,445,000 shares of our common stock are issuable upon exercise of options.

Investors may be subject to further dilution if we sell additional common shares or issue additional common shares in connection with future financings. If a significant number of our common shares are sold in the public market, the market price of our common shares could be depressed. This could hamper our ability to raise capital by issuing additional equity securities.

Our results may be affected by fluctuations in currency exchange rates.

Our financial statements are reported in U.S. dollars and all of our revenue, and most of our operating costs, are currently denominated in U.S. dollars; however, we have operations outside the United States and we may expend money in Canada, where our operating costs will be denominated in local currencies. Fluctuations in exchange rates may increase our relative cost of operating in Canada, and may therefore have a negative effect on our financial results.

19

Non-U.S. holders of our common shares may be subject to U.S. federal income tax on the sale of our common shares and purchasers may have IRS withholding requirements

Since we believe that we are a United States real property holding corporation, a gain recognized by a non-U.S. holder on the sale of our common shares will be subject to U.S. federal income tax at normal graduated rates, and a purchaser may be required to withhold for the benefit of the IRS a percentage of the purchase price, unless certain trading requirements are met.

There is a limited public market for our common shares, and the ability of our shareholders to dispose of their common shares may be limited.

Our common shares have been trading on NYSE MKT (formerly the American Stock Exchange) since February 15, 2007. We cannot foresee the degree of liquidity that will be associated with our common shares. A holder of our common shares may not be able to liquidate his, her or its investment in a short time period or at the market prices that currently exist at the time the holder decides to sell. The purchase and sale of relatively small common share positions may result in disproportionately large increases or decreases in the price of our common shares. A trade involving a large number of common shares could have an exaggerated effect on the reported market price of our common shares.

Our stock price may fluctuate significantly.

The stock market in general and the market for oil and natural gas exploration companies have experienced price and volume fluctuations that are often unrelated or disproportionate to the operating results or asset values of companies. These broad market and industry factors may seriously impact the market price and trading volume of our common shares regardless of our actual operating performance. The market price of our common stock could also fluctuate significantly as a result of:

· actual or anticipated quarterly variations in our operating results and our reserve estimates;

· changes in expectations as to our future financial performance or changes in financial estimates, if any, of public market analysts;

· announcements relating to our business or the business of our competitors;

· conditions generally affecting the oil and natural gas industry, including changes in oil and natural gas prices;

· speculation in the press or investment community;

· general market and economic conditions;

· the success of our operating strategy; and

· the operating and stock price performance of other comparable companies.

The sale of large numbers of our common stock may depress the market price of our common stock.

The sale of a substantial number of shares of our common stock in the public market, or the perception that substantial sales may occur, could cause the market price of our common stock to decrease. Substantially all of the shares of our common stock are freely transferable or will be transferable in compliance with restrictions under the Securities Act of 1933, as amended.  In 2013, we will need to raise additional working capital and investors may be subject to further dilution if we sell additional common shares or issue additional common shares in connection with future financings. If a significant number of our common shares are sold in the public market, the market price of our common shares could be depressed. This could hamper our ability to raise capital by issuing additional equity securities.

20

We will continue to incur significant expenses as a result of being a public company, which may negatively impact our financial performance.

We have incurred and will continue to incur significant legal, accounting, insurance and other expenses as a result of being a public company. The Sarbanes-Oxley Act of 2002, as well as related rules implemented by the SEC, and the NYSE MKT, have required changes in corporate governance practices of public companies. Compliance with these laws, rules and regulations has increased our expenses, including our legal and accounting costs, and made some activities more time-consuming and costly. As a result, it may be more difficult for us to attract and retain qualified persons to serve on our board of directors or as officers. Furthermore, any additional increases in legal, accounting, insurance and certain other expenses that we may experience in the future could negatively impact our financial performance and have a material adverse effect on our results of operations and financial condition .

Item 1B.  Unresolved Staff Comments

None.

Item 2.  Properties

Our principal executive office, consisting of 4,201 square feet, is located at 150 California Street, Suite 600, San Francisco, CA 94111.

Description of the Properties

Our current oil and natural gas exploration, appraisal and development drilling activities are focused in three distinct project areas as follows:

· United States—Texas (East Texas), California (onshore San Joaquin basin) and Alaska (onshore Cook Inlet basin);

· Canada—Alberta (central Alberta basin);

· Australia—onshore in two permit areas located in the South Perth basin.

Texas

Madisonville Project, Madison County, East Texas

We own and operate the interest in the Madisonville Project in Madison County, Texas. We own working interests in approximately 2,733 gross and net acres of leases in the Rodessa Formation interval. We also own a license as to 12.5 square miles of 3-D seismic data over the Madisonville Field.

The Madisonville Field, located approximately 100 miles north of Houston, has produced oil and natural gas from four different horizons above the Rodessa Formation for over 50 years. The field was discovered in 1945 with the Boring No. 1 well, which was drilled to the Rodessa Formation. The well blew out at an uncontrolled rate for three days during a test; however, due to hydrogen sulphide, carbon dioxide and nitrogen in the Rodessa Formation natural gas, the gas reserves were never developed. Over 125 wells were drilled in the Madisonville Field to shallower intervals above the Rodessa Formation. In 1994, nearly 50 years after the initial discovery, United Meridian Corporation (“UMC”) drilled the Magness Well as the first follow-up well into the Rodessa Formation to the Boring No. 1 well. The Magness Well had 139 feet of net pay but the natural gas was found to contain 28% impurities.

UMC previously production tested the Magness Well in 1994 through perforations in the lower most ten feet of the indicated Rodessa Formation pay interval. The well tested at a rate of 12 MMcf/d from this limited interval on a 22/64ths inch choke with flowing wellhead pressures increasing from 3,915 to 3,919 pounds per square inch. In 2001, we re-entered and recompleted the Magness Well. A total of 139 feet of interval has been perforated in the Rodessa Formation at approximately 12,000 feet of depth for this well. The well was production tested over a 12-day period in 2001 on various choke sizes with flowing rates ranging up to approximately 20.8 MMcf/d. We own a 100% working interest (75.1333% net revenue interest) in the Magness Well located in the surrounding production unit consisting of 684 gross and 629 net acres. The Magness Well commenced production in May of 2003 and stabilized at a rate of 18 MMcf/d of raw gas.

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The first development well, the Fannin Well, was drilled and completed in 2004. We own a 100% working interest (69.8978% net revenue interest) in the Fannin Well located in the surrounding production unit consisting of 704 gross and net acres. A total of 146 feet of indicated pay was perforated in the well and a flow test of the well was completed in December 2004 from the Rodessa Formation at rates of up to 25.7 MMcf/d. We commenced production from the Fannin Well in early 2006. Also in 2006, we drilled the Mitchell and Wilson wells. We own a 100% working interest (70% net revenue interest) in the Mitchell and Wilson wells.

The Madisonville Field is a geologic feature encompassing approximately 5,800 acres at the Rodessa limestone at about 11,800 feet of depth. A 3-D seismic program shot in early 1998 confirmed the size of the structure and slightly increased its size over earlier interpretations. Our working interest covers the Rodessa Formation at approximately 12,000 feet of depth. In addition, we own a working interest in certain leases which cover depths below the Rodessa Formation.

Hydrogen sulfide, carbon dioxide and nitrogen combined comprise about 28% of the gas content. The untreated natural gas is delivered to the Madisonville Gas Treatment Plant where all the natural gas impurities are removed prior to delivery to the sales pipeline. The high concentrations of hydrogen sulfide and carbon dioxide result in higher capital and operating costs for our wells. For example, the hydrogen sulfide and carbon dioxide are corrosive to the wellbores. This means we have to utilize higher grade specification well tubing and casing which is more expensive than what we would utilize absent the impurities. In addition, we continuously treat the wellbores with chemicals designed to inhibit the corrosive effects of the impurities. We also maintain field personnel at or near the wellsites who monitor the wells on a twenty four hour basis and equip the wellsites with extensive safety equipment systems due to the toxic properties of the hydrogen sulfide and carbon dioxide.

The Madisonville Gas Treatment Plant and Gathering Facilities

In order to produce the proved gas reserves from the Rodessa Formation, we developed an onsite plan to treat and remove impurities from the Madisonville Project natural gas in order to meet pipeline-quality specifications. In June 2001, Redwood LP contracted with Hanover Compression Limited Partnership (“Hanover”) to fund, construct and operate a dedicated natural gas treatment plant with an initial designed capacity of 18 MMcf/d.  In conjunction with the plant construction, Gateway installed field gathering lines and an approximately nine mile sales pipeline, with an estimated capacity of 70 MMcf/d, to transport the Madisonville gas to a major pipeline. These facilities were completed in April 2003 and production from the Magness Well commenced in May 2003.

In July 2005, Madisonville Gas Processing LP (“MGP”) purchased the natural gas treatment plant from Hanover and purchased the gathering pipelines upstream of the gas treatment plant from Gateway. On December 31, 2008, we purchased the gas treatment plant and related gathering pipelines from MGP in exchange for the assumption of secured bank debt, payment of certain outstanding payables of MGP and shares of GeoPetro’s common stock. The effective date of the acquisition was December 31, 2008 and the current owner of the Plant is GeoPetro’s wholly-owned, indirect subsidiary, Madisonville Midstream. The secured bank debt we incurred as part of the Plant acquisition totaled $6.7 million and was in the form of a 3 year loan with the lender, Bank of Oklahoma (“BOK”). The loan agreement provided for minimum quarterly principal payments of $150,000 and supplemental principal amounts payable upon GeoPetro achieving certain cash flow thresholds.  The Company pledged its Madisonville natural gas reserves as well as the Plant assets as collateral for the loan.  GeoPetro and its wholly owned subsidiary Redwood LP were guarantors of the loan. This loan was paid in full on September 13, 2011.

The existing Plant continues to operate with a processing capacity of approximately 18 MMcf/d of inlet gas. Plans are currently under development to expand the Plant’s processing capacity to 30 MMcf/d.

Our natural gas deliveries to our gas treatment plant may be affected by third party demands for access to the plant. On August 9, 2006, the Railroad Commission of Texas issued an order requiring the Plant to ratably process, take, transport or purchase natural gas produced by Crimson into the Madisonville gas treatment plant. There is no guarantee that we will be able to maintain full access to the treatment capacity of the Madisonville Plant at all times because, for example, Crimson now has the right to have its natural gas treated at the plant, which may reduce the plant’s ability to treat all of our natural gas, unless the plant’s capacity is further expanded.

To date, Crimson has drilled and completed two wells to a depth of approximately 12,635 feet. Crimson has also drilled an injection well for disposal of waste products resulting from the treatment of their natural gas.  Crimson has not delivered any natural gas to the treatment plant since August 2009.

Other Interests in the Madisonville Project

Our working interest in the Madisonville Project is subject to a net profits interest in favor of the third party that sold us our working interests in the Madisonville Project. The net profits interest is 12.5% (proportionately reduced to our interest) of the net operating profits until payout is achieved. After payout, the net profits interest increases to 30% (proportionately reduced to our interest). “Payout”, for purposes of the net profits interest, is defined and achieved at such time as we have recouped from net operating cash flows our total net investment in the Madisonville Project plus a 33% cash on cash return.

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California

Lokern Project

We have 100% working interests in 1,280 leased acres in the Lokern Project, located in the southern San Joaquin basin, near Bakersfield, California. The primary exploration objectives are the Monterey Shale, the Miocene Stevens formation and the Carneros member of the Temblor formation. The secondary objectives include the Miocene Reef Ridge and Pliocene Etchegoin sands. The Stevens formation is Upper Miocene age.

The Lokern Project is being developed in part as a result of positive results from the Machii-Ross Ackerman show well drilled in 1979 on acreage currently controlled by us. Based on log analysis, we believe this well had approximately 240 feet of potential net oil pay and an additional 150 feet of potential pay in the Stevens zone. The Machii-Ross Ackerman well was drilled to a depth of 15,078 feet by Machii-Ross Petroleum Company and was plugged and abandoned as a dry hole. We believe, based on our log analysis, that the well may have been a bypassed producer.

Subject to drilling permits, we expect that a well will be drilled, either by us or through a farm-out arrangement with a third party, to a depth of 15,000 to 18,000 feet in 2013/2014.

Based on our review of title information from public authorities and other publicly available sources, we believe that we have a 100% working interest in the Lokern Project. As is customary in the U.S. oil and gas industry, we will not conduct a thorough title review with respect to our interest in the Lokern Project until we have made a definitive decision to drill in a particular lease area.

Alaska

The Cook Inlet Alaska Project

On February 26, 2010, we sold our entire 100% working interest in approximately 122,000 acres onshore in the Cook Inlet region of Alaska (“Alaskan Leases”). The position consisted of two separate target areas, the Point MacKenzie Prospect and the Trading Bay Prospect. The Point MacKenzie Prospect is located twelve miles northwest of Anchorage. The Trading Bay Prospect is located fifty miles west of Anchorage, across the Cook Inlet. The interests were purchased by Linc Energy (Alaska) Inc. (“Linc”).  Linc is a wholly-owned subsidiary of Linc Energy Ltd., an Australian-based company publicly traded on the Australian Stock Exchange.

In exchange for our 100% working interest in our Alaskan Leases we received or will receive the following consideration:

· a cash payment of $1.0 million;

· a $4.0 million payment from the first 75% of the 8/8ths proceeds from any oil and gas production from the underlying leases;

· subsequent to our receipt of the $4.0 million payment specified above, we will thereafter receive an over-riding royalty interest of 10% of 8/8ths in and to the leases issued by the State of Alaska and the Alaska Mental Health Trust on conventional oil and gas production and coal bed methane production; and

· Linc has agreed to pay all of the costs of maintaining the Alaskan Leases through the end of the primary lease terms.

On May 2, 2011 Linc, the operator of the Alaskan Leases in the Cook Inlet region reported that drilling and testing on the LEA #1 well located in the Point MacKenzie Block of the Cook Inlet basin had been completed. Three sandstone targets were tested separately. Despite the fact that gas shows were encountered while drilling, the sandstone targets were too tight to produce commercial quantities of gas. Although the LEA#1 has not proved to be commercial, the operator intends to use information acquired while drilling the well to continue exploration in the Cook Inlet basin.

Preliminary log analysis and seismic data indicate the Point MacKenzie and Trading Bay Blocks may contain conventional accumulations of natural gas reserves in Tertiary sandstones. Structural anticlines and/or domes occur on the lease blocks and may contain large undrilled gas reservoirs. Sandstone units also pinch-out toward the margins of the basin and may have formed stratigraphic traps on the lease blocks. In the past, oil and gas exploration has focused on oil production and anticlinal gas traps, but stratigraphic accumulations have been largely unexplored in the Cook Inlet.

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Additional potential on the Alaskan Leases may be realized from the development of coal bed methane reserves. The coals occur in seams which are commonly 20 feet thick and can be as thick as 70 feet. Accessible onshore areas have 200 to 300 feet of aggregate coal thickness shallower than 5,000 feet. Estimated gas content for these coals ranges from 80 to 250 standard cubic feet per ton. Testing for coal bed methane has been restricted to a very small number of bore holes and is almost completely unknown for most of the inlet.

Alberta

Swan Hills Project

The Swan Hills Project is located in the Central Alberta basin, Alberta, Canada. The primary exploration objective is the Swan Hills Formation at approximately 9,000 feet.

We, through our wholly-owned subsidiary, GeoPetro Canada, have reviewed 3-D seismic data over the prospect.  Subject to drilling permits, we expect that a test well will be drilled, either by us or through a farm-out arrangement with a third party, in 2013.  We have 100% of the working interest in approximately 3,840 gross and net leased acres.

Australia

On June 20, 2007, the Company agreed to sell and transfer all of its remaining property interests in Australia to an unrelated party for cash consideration and a Petroleum Sales Royalty Payment equal to 25% of the future annual earnings before interest, taxes, depreciation and amortization from the property interests. Specifically, the agreement provides that the Company will be paid consideration for the sale and transfer of its property interests as follows:

· initial cash consideration of $175,000 was received on November 19, 2007;

· a second cash payment of $175,000 upon a successful flow test of petroleum from a well located on the property interests. A successful flow test is defined for purposes of this agreement to be a test of at least 7 million standard cubic feet of natural gas for a continuous and uninterrupted 24 hour period (or an equivalent oil/condensate rate based on a conversion ratio of 6000 cubic feet of gas to a barrel of oil or condensate); and

· a Petroleum Sales Royalty Payment equal to 25% of the future annual earnings before interest, taxes, depreciation and amortization from the property interests up to a total amount of $2,200,000.

Proved Reserves Disclosures

Internal Controls Over Reserves Estimates

Our policies regarding internal controls over the recording of reserves estimates requires reserves to be in compliance with the SEC definitions and guidance and prepared in accordance with generally accepted petroleum engineering principles.

The Company engaged the independent petroleum engineering firm, MHA Petroleum Consultants, LLC (“MHA”) to prepare the Company’s reserve estimates at December 31, 2012 and 2011. MHA is a Denver based group of multiple professional engineers and geologists providing a wide range of technical services to the petroleum industry.  Within MHA, the technical persons primarily responsible for preparing the estimates set forth in the MHA reserves report incorporated herein are Mr. John Arsenault and Mr. Dennis Holler.  Mr. Arsenault has been practicing consulting petroleum engineering at MHA since 2006, and has over 25 years of practical experience in petroleum engineering, with over 17 years experience in the estimation and evaluation of reserves. Mr. Holler has been practicing consulting petroleum geology at MHA since 2001.  Mr. Holler has over 37 years of practical experience in petroleum geology, with over 27 years experience in the estimation and evaluation of reserves. Both technical principals meet or exceed the education, training, and experience requirements set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers; both are proficient in judiciously applying industry standard practices to engineering and geosciences evaluations as well as applying SEC and other industry reserves definitions and guidelines. MHA evaluated properties representing 100% of our reserves, valued at the total estimated future net cash flows before income taxes, discounted at 10% (“PV-10”), for all periods presented below. Senior members of our management review the final reserve report to ensure the accuracy and completeness of all inputs into the report. MHA’s report to management, which summarizes the scope of work performed and its conclusions, has been included in this report as Exhibit 99.1.

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Proved Undeveloped (PUD) Reserves

As of December 31, 2012, our PUDs totaled 8.7 Bcf of natural gas.

· PUD Locations - 100% of our PUDs at year-end 2012 were associated with the Madisonville Field.

· Development Costs - Estimated future development costs relating to the development of PUDs are projected to be approximately $5.4 million and $4.2 million in 2013 and 2014 respectively.

· Drilling Plans - Our PUD development is scheduled in 2013 and 2014.  Initial production from the PUD reserves is expected to begin in 2013.

Proved Oil and Gas Reserves

The 2012 and 2011 reserve estimates were prepared by MHA and are part of their reserve reports on our oil and natural gas properties. MHA’s estimates were based on a review of geologic, economic, ownership and engineering data that we provided. In estimating the reserve quantities that are economically recoverable, MHA used simple arithmetic average of the natural gas price in effect on the first day of each month in 2012 and 2011. All of our proved reserves are attributable to our Madisonville Project in Madison County, Texas.

Our estimated total net proved reserves of oil and natural gas as of December 31, 2012 and 2011, and the present values of estimated future net revenues attributable to those reserves as of those dates, are presented in the following tables.

	DECEMBER 31,
	2012		2011
	(MMcf)		(MMcf)
Proved developed producing		—		2,453
Proved developed non-producing		9,126		7,327
Proved undeveloped		8,663		9,108
Total		17,789		18,888

In accordance with SEC regulations, estimates of our proved reserves and future net revenues are made using sales prices which are held constant throughout the life of the properties, except to the extent a contract specifically provides for escalation. Estimated quantities of proved reserves and future net revenues are affected by oil and natural gas prices, which have fluctuated significantly in recent years.

See “Glossary of Oil and Natural Gas Terms”

Standardized Measure of Discounted Future Net Cash Flows

For purposes of the following disclosures, estimates were made of quantities of proved reserves and the periods during which they are expected to be produced.  Future cash flows for the 2012 & 2011 estimates were computed by applying the simple arithmetic average of the natural gas price in effect on the first day of each month in the respective years to estimated annual future net production from proved gas reserves. The price assumptions used for natural gas are indicated below. Future development drilling and production costs were computed by applying year-end costs to be incurred in producing and further developing the proved reserves. Future income tax expenses were computed by applying, generally, year-end statutory tax rates (adjusted for permanent differences, tax credits and allowances) to the estimated net future pre-tax cash flows. The discount was computed by application of a 10% discount factor. The calculations assume the continuation of existing economic, operating and contractual conditions. However, such arbitrary assumptions have not proven to be the case in the past. Other assumptions of equal validity could give rise to substantially different results:

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	YEAR ENDED DECEMBER 31,
	2012			2011
	(in thousands)
Future cash inflows	$	44,045		$	72,305
Future production costs		(10,555	)		(16,512	)
Future development costs		(10,916	)		(10,916	)
Future income taxes		—			—
Future net cash flows		22,574			44,877
10% annual discount		(6,426	)		(12,258	)
Standardized measure of discounted future net cash flows	$	16,148		$	32,619

The standardized measure values shown in the aforementioned table are not intended to represent the current market value of the estimated proved oil and gas reserves owned by us.

Pricing Assumptions

SEC regulations require that the gas price used for the December 31, 2012 and 2011 MHA reserve reports is the simple arithmetic average of the natural gas price in effect on the first day of each month in 2012 and 2011 respectively. These prices are projected without inflation for the life of the wells included in the reserve reports. The pricing assumptions are listed below and represent the un-weighted average price for natural gas delivered based upon the Houston Ship Channel price, as adjusted, before any reductions for transportation and processing fees:

AVERAGE PRICE		AVERAGE PRICE
2012 REPORT		2011 REPORT
Gas ($/MMBtu)		Gas ($/MMBtu)
$	2.46	$	3.76

Acreage and Productive Wells

The following table sets forth our ownership interest in undeveloped acreage, developed acreage and productive wells in the areas indicated where we own a working interest as of December 31, 2012. Gross represents the total number of acres or wells in which we own a working interest. Net represents our proportionate working interest resulting from our ownership in gross acres or wells. Productive wells are wells in which we have a working interest and that are capable of producing natural gas or oil. Wells that are completed in more than one producing horizon are counted as one well.

	Undeveloped acreage				Developed acreage				Producing Wells				Non-Producing Wells
Acreage Holdings	Gross Acres		Net Acres		Gross Acres		Net Acres		Gross		Net		Gross		Net
Canada		3,840		3,840		—		—		—		—		—		—
Texas		706		706		2,027		2,027		3		3		1		1
California		1,280		1,280		—		—		—		—		—		—
Total		5,826		5,826		2,027		2,027		3		3		1		1

The following table sets forth as of December 31, 2012, the expiration periods of the gross and net undeveloped acreage:

	Undeveloped Acreage
	United States				Canada
	Gross		Net		Gross		Net
Twelve months ended
December 31, 2013		663		663		3,840		3,840
December 31, 2014		1,323		1,323		—		—
December 31, 2015 and thereafter		—		—		—		—
		1,986		1,986		3,840		3,840

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Volumes, Prices and Production Costs

Substantially all of our production is derived from our Madisonville Project in Madison County, Texas. The following table sets forth information with respect to our production volumes, average prices received and average production costs for the periods indicated:

	YEAR ENDED DECEMBER 31,
	2012		2011
Production:
Natural gas (MMcf) (1)		161		292
Natural gas (MMcf/d) (1)		0.44		0.80
Average Sales Prices
Natural gas ($per Mcf) (2)	$	2.18	$	3.35
Lease Operating Expense
($per Mcf) (3)	$	1.65	$	0.98

(1) Production volumes for 2012 and 2011 represent actual plant throughput.

(2) The sales price reflected for the years ended December 31, 2012 and 2011 represents the sales price realized before deducting treatment, gathering and transportation costs, and is based on plant throughput.

(3) Lease operating expense per Mcf is based on lease operating expense and sales volumes net to our interests in the Madisonville gas wells.

Business Risks and Other Special Considerations

Refer to “Risk Factors” in this report for a discussion of business risks and other special considerations.

Item 3.  Legal Proceedings

Not applicable.

Item 4.  Mine Safety Disclosures

Not applicable.

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PART II

Item 5. Market for the Registrants Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities

Common Stock

Market Information.  Our common stock trades on NYSE MKT under the symbol “GPR”.

The range of high and low closing prices for our Common Stock for each quarterly period from January 1, 2011 through December 31, 2012 as reported by NYSE MKT:

	NYSE MKT
	High		Low
2012
Fourth Quarter	$	0.11	$	0.06
Third Quarter	$	0.16	$	0.07
Second Quarter	$	0.21	$	0.11
First Quarter	$	0.27	$	0.19
2011
Fourth Quarter	$	0.32	$	0.22
Third Quarter	$	0.40	$	0.31
Second Quarter	$	0.72	$	0.35
First Quarter	$	0.93	$	0.39

On April 11, 2013, the closing sale price for the Common Stock as reported by the NYSE MKT was $0.08 per share.

Holders. On April 11, 2013, the number of holders of record of our common stock was 328.

Dividends. We have not paid or declared any cash dividends on our common stock in the past and do not intend to pay or declare any cash dividends in the foreseeable future. We currently intend to retain future earnings for the future operation and development of our business including exploration, development and acquisition activities. Any future dividends would be subordinate to the full cumulative dividends on all shares of our Series B Preferred Stock.

The holders of Series B preferred stock are entitled to receive ratably such cash dividends, as were declared from time to time by the board of directors out of funds legally available therefore and, when declared, dividends were paid at the rate of $0.06 per share per annum, paid on a calendar quarter basis.  During 2012, we accrued $325,380 in dividends associated with the Series B preferred stock, of which $0 had been paid as of December 31, 2012.

Use of Proceeds

On our registration statement on Form S-1 (Reg. No. 333-135485) we registered up to 16,499,991 shares of our common stock, no par value per share, including 5,943,105 shares of common stock issuable upon exercise of warrants and options, for resale by selling shareholders. The registration statement was declared effective by the SEC in February 2007. The offering commenced in February 2007 and has not terminated. On our registration statement on Form S-1 (Reg. No. 333-146557) we registered up to 2,002,599 shares of outstanding common stock and the resale of up to 780,857 shares of common stock issuable upon exercise of warrants, for resale by selling shareholders. The registration statement was declared effective by the Securities and Exchange Commission in October 2007. The offering commenced in October 2007 and has not terminated. We will not receive any proceeds from the sale of our common stock by the selling shareholders under the registration statements; however, if all warrants and options to acquire our common stock being registered thereunder are exercised, we will realize cash proceeds of approximately $8,851,550, which we expect to use for general working capital purposes and the drilling of wells in our Texas, California, and Canada prospects.

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If less than the $8,851,550 proceeds are realized from the exercise of such warrants and options, we anticipate the proceeds would be spent in the following order of priority:

1.   Madisonville Project, Madison County, Texas — Approximately $6,095,000 may be expended in the Madisonville Field area as follows:  $650,000 for the Mitchell well workover; $1,445,000 toward the fracture stimulation and hook up costs of the Wilson Well; and $4,000,000 for expansion of the gas treatment plant.

2. California — Approximately $200,000 to be utilized for land and permitting costs.

3. Canada — Approximately $150,000 to be utilized for permitting costs.

We do not know if, or how many, of the warrants or options will be exercised. This is our best estimate of our use of proceeds generated from the possible exercise of warrants or options based on the current state of our business operations, our current plans and current economic and industry conditions. Any changes in the projected use of proceeds will be made at the sole discretion of our board of directors.

Unregistered Sales of Securities

In March 2012, Stuart J. Doshi, President and CEO, advanced to the Company a loan in the amount of $100,000.  In connection with the note, the Company issued 20,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In March 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In May 2012, Stuart J. Doshi, President and CEO, advanced to the Company two loans totaling $75,000.  In connection with these notes, the Company issued 15,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In June 2012, Stuart J. Doshi, President and CEO, advanced to the Company four loans totaling $225,000.  In connection with these notes, the Company issued 45,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In July 2012, Stuart J. Doshi, President and CEO, advanced to the Company two loans totaling $75,000.  In connection with these notes, the Company issued 15,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In August 2012, the Company issued 45,000 warrants to purchase our common stock. Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of four years.

In August 2012, the Company issued 225,000 shares of common stock to our independent directors. The shares were valued at $0.14 per share and the aggregate value of the shares issued was $31,500.  We agreed to grant "piggyback" registration rights to the directors with respect to the shares of common stock.

In August 2012, the Company granted 675,000 stock options at an exercise price of $0.16 per share.  These options will vest ratably over five years pursuant to the terms of the 2004 Stock Option and Appreciation Rights Plan. 

In October 2012, the Company issued 72,000 warrants to purchase our common stock. Each warrant entitles the holder to acquire one common share at a price ranging from $0.10 to $0.23 per share for a period of five years.

In November 2012, Stuart J. Doshi, President and CEO, advanced to the Company two loans totaling $60,000.  In connection with these notes, the Company issued 12,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In November 2012, the Company issued 30,000 warrants to purchase our common stock. Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

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In November 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $10,000, and represented the sale of 100,000 common shares and 50,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In December 2012, Stuart J. Doshi, President and CEO, advanced to the Company a loan for $30,000.  In connection with this note, the Company issued 6,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In December 2012, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $100,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In January 2013, Stuart J. Doshi, President and CEO, advanced to the Company a loan for $5,000.  In connection with this note, the Company issued 1,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In January 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $132,500, and represented the sale of 1,325,000 common shares and 662,500 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In January 2013, we agreed to rescind a unit subscription agreement. Units were originally priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitled the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units originally sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  The Company is reacquiring the common shares and warrants in exchange for a non-interest bearing unsecured note for $250,000 which matures in July 2014.

In February 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $122,500, and represented the sale of 1,225,000 common shares and 612,500 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In March 2013, Stuart J. Doshi, President and CEO, advanced to the Company three loans totaling $85,000.  In connection with this note, the Company issued 17,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In March 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $50,000, and represented the sale of 500,000 common shares and 250,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

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GeoPetro issued the aforementioned common shares and warrants in reliance on the exemption from registration provided for under Section 4(2) of the Securities Act of 1933, as amended (“ Securities Act ”), and Rule 506 of Regulation D thereunder. GeoPetro relied on the exemption from registration provided for under Section 4(2) of the Securities Act based in part on the representations made by the purchasers, including the representations with respect to each purchaser’s status as an accredited investor, as such term is defined in Rule 501(a) of the Securities Act, and each purchaser’s investment intent with respect to the securities purchased. In addition, the Securities, which were taken for investment purposes and not for resale, were subject to restrictions on transfer.  We did not engage in any public advertising or general solicitation in connection with this transaction, and we provided the investors with disclosure of all aspects of our business, including providing the investor with our reports filed with the SEC and other financial, business and corporate information.  Based on our investigation, we believed that the accredited investors obtained all information regarding the Company that they requested, received answers to all questions posed and otherwise understood the risks of accepting our Securities for investment purposes.

Item 6.  Selected Consolidated 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 and analysis should be read in conjunction with the “Selected Consolidated Financial Data” and the accompanying consolidated financial statements and related notes included elsewhere in this Annual Report on Form 10-K. The following discussion contains forward-looking statements that reflect our future plans, estimates, beliefs and expected performance. The forward-looking statements are dependent upon events, risks and uncertainties that may be outside our control. See “Cautionary Statement Concerning Forward-Looking Statements”.

Business Overview

We are an oil and gas company in the business of exploring and developing oil and natural gas reserves on a worldwide basis. Since inception, we have conducted leasehold acquisition, exploration and drilling activities on our North American, Australian and Indonesian prospects. These projects currently encompass approximately 7,853 gross and net acres, consisting of mineral leases, production sharing contracts and exploration permits that give us the right to explore for, develop and produce oil and natural gas. Most of these properties are in the exploration, appraisal or development drilling phase and have not begun to produce revenue from the sale of oil and natural gas. Excluding minor interest and dividend income, our only significant cash inflows until 2003 were the recovery of capital invested in projects through sale or other divestiture of interests in oil and gas prospects to industry partners.

Our objective is to increase shareholder value by profitably growing our reserves, production, revenue, and cash flow by focusing primarily on our projects in Texas, California, Canada and certain new venture opportunities.

Since 2003, substantially all of our revenue has been generated from natural gas sales derived from the Madisonville Field in East Texas under spot gas purchase contracts at market prices. Natural gas sales from the Madisonville Field are expected to account for substantially all of our revenues for 2013. We expect the majority of our capital expenditures in 2013 will be for the Madisonville Project. Considering our liquidity issues, we may have to raise capital or sell assets on less favorable terms than may otherwise be available in order to accomplish our goals.

	For The Years Ended December 31,
	2012			2011
Consolidated Statement of Operations:
Revenues	$	351,082		$	976,571
Plant operating expense		1,036,549			2,280,453
Lease operating expense		191,615			205,421
General and administrative		1,963,053			2,202,171
Depreciation and depletion expense		195,110			449,537
Impairment expense		620,656			750,133
Loss from operations		(3,655,901	)		(4,911,144	)
Gain on sale of equipment		—			4,069,640
Net loss		(3,935,302	)		(1,472,434	)
Net loss attributable to common shareholders	$	(4,260,682	)	$	(1,907,073	)

Revenue and Operating Trends in 2012

As discussed in the “Properties — Texas — Madisonville Project” section of this annual report, in order to produce the gas reserves from the Rodessa Formation, we developed an onsite plan to treat and remove impurities from the Madisonville Project natural gas in order to meet pipeline-quality specifications. In 2003, a third party completed the construction and installation of a natural gas treatment plant with a designed capacity of 18 MMcf/d and associated pipeline and gathering facilities.

On December 31, 2008, we purchased the gas treatment plant and related gathering pipeline from MGP in exchange for assumption of secured debt, payment of certain outstanding payables of MGP and shares of GeoPetro’s common stock.  The effective date of the acquisition was December 31, 2008 and the new owner of the Plant is GeoPetro’s wholly-owned, indirect subsidiary, Madisonville Midstream. The plant operates with a design capacity of up to approximately 18 MMcf/d of inlet gas. Plans are currently under development for the plant capacity to be increased to 30 MMcf/d.

While there can be no assurance, our goal is to complete the expansion to the plant and increase the production rates from our wells which may result in higher net production and increased revenue in the latter half of 2013 and 2014 as compared to 2012 and prior periods. To accomplish the plant expansion we will need to raise capital in 2013. Due to our liquidity concerns, funds may not be available, or may not be available on favorable terms. If we are unable to raise the necessary capital, we may have to delay our plans for expansion or reduce the scope of our operations.

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Industry Overview for the year ended December 31, 2012

Natural gas prices have historically been volatile.  Price volatility during 2012 and 2011 relates to economic concerns and a resultant decline in demand for natural gas, an increase in production from shale gas, and a relatively mild winter in 2011/2012. These factors led to natural gas prices falling to 10-year lows in 2012. The Houston Ship Channel price, the index price prevailing in the locale of our Madisonville Project in Madison County, Texas, as quoted in Gas Daily as of December 31, 2012 was $3.35 per Mcf versus $2.74 per Mcf as of December 31, 2011. Fluctuations in the price for natural gas are closely associated with customer demand relative to the volumes produced and the level of inventory in underground storage.

Company Overview in 2012

Our net loss after taxes for the year ended December 31, 2012 was $4,260,682. From our inception, through mid-2003, we only received nominal revenues from our oil and natural gas activities, while incurring substantial acquisition and exploration costs and overhead expenses which have resulted in an accumulated deficit through December 31, 2012 of $49,729,613. Commencing in May 2003, we placed our Madisonville Project into production. Substantially all of our revenues for the year ended December 31, 2012 were derived from our Madisonville Project, from three producing wells, the Magness Well, the Fannin Well, and the Mitchell Well.

Comparison of Results of Operations for the year ended December 31, 2012 and 2011

Gross natural gas revenues for the twelve months ended December 31, 2012 were $351,082. During this 2012 period, the sales of natural gas from our wells amounted to 161,377 Mcf and our average natural gas price realized was $2.18 per Mcf.  Gross natural gas revenues for the twelve months ended December 31, 2011 were $976,571.  During this 2011 period, the sales of natural gas from our wells amounted to 291,797 Mcf and our average natural gas price realized was $3.35 per Mcf. Revenues decreased for the twelve months ended December 30, 2012 as compared to the prior year period mainly due to lower production volumes and lower natural gas prices. The 44.7% lower production volumes for the twelve months ended December 31, 2012 as compared to the same period of 2011 was due primarily to the temporary shut-in of the Madisonville Field in 2012 as a result of low natural gas prices.  

Plant operating expenses for the twelve months ended December 31, 2012 were $1,036,549 as compared to $2,280,453 for the twelve months ended December 31, 2011.  The decrease in plant operating expenses of $1,243,904 or 54.6% was primarily attributable to the suspension of plant operations as a result of the temporary shut-in of the Madisonville Field. Since the Company planned for an extended shut down, it was able to significantly reduce expenses. When operations resume at the plant, expenses will increase from current levels.

Lease operating expenses for the twelve months ended December 31, 2012 were $191,615. Our average lifting cost for this 2012 period was $1.19 per Mcf. Lease operating expenses for the twelve months ended December 31, 2011 were $205,421. Our average lifting cost for this 2011 period was $0.70 per Mcf. Despite overall lease operating expenses being lower in 2012, the average lifting cost per Mcf was higher during the period, due to fixed costs associated with field personnel, insurance costs, and ad valorem property taxes applicable to the wells, on a lower base of production volume.

General and administrative expenses (“G&A”) for the twelve months ended December 31, 2012 were $1,963,053 as compared to $2,202,171 for the twelve months ended December 31, 2011. The decrease in G&A of $239,118 or 10.9% was primarily attributable to reduced expenses for investor relations, professional fees and salaries due to a reduction in the number of employees.

Depreciation, depletion and amortization expense ("DD&A") for the twelve months ended December 31, 2012 was $195,110 as compared to $449,537 for the twelve months ended December 31, 2011.  These amounts primarily represent depletion of the oil and gas properties.  The 56.6% decrease was primarily due to the temporary shut in of the Madisonville Field.

Impairment expense for the twelve months ended December 31, 2012 was $620,656 as compared to $750,133 for the twelve months ended December 31, 2011. The 2012 impairment was primarily a result of terminated negotiations with the Indonesian government for an extension of the Bengara II Production Sharing Contract.  The 2011 impairment write-down was due to the decision to terminate CG Xploration and wind down operations as no immediate opportunity to acquire an attractive new project in Indonesia existed.

During the twelve months ended December 31, 2011, a gain on the sale of equipment of $4,069,640 was realized relating to the sale of certain idle and non-income producing equipment at the Madisonville Plant. There was no comparable sale of equipment during the twelve months ended December 31, 2012.

Interest expense for the twelve months ended December 31, 2012 was $295,620 as compared to $634,576 for the twelve months ended December 31, 2011.  The decrease in interest expense was primarily attributable to the retirement of the Bank of Oklahoma debt in September 2011.

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Net loss before taxes for the twelve months ended December 31, 2012 was $3,925,638 as compared to $1,471,634 for the twelve months ended December 31, 2011. The increase in net loss during the twelve months ended December 31, 2012 was primarily due to the fact that we recorded a gain on the sale of certain idle and non-income producing equipment in 2011.

Recent Developments

In March 2012, Stuart J. Doshi, President and CEO, advanced to the Company a loan in the amount of $100,000.  The note bears interest at 10% per annum and is payable on demand.  In connection with the note, the Company issued 20,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In March 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In April 2012, the Company's wholly-owned subsidiary, Redwood Energy Production, L.P., elected to temporarily shut-in its natural gas production at the Madisonville Field, Madison County, Texas in light of currently depressed natural gas prices caused by the oversupply of natural gas and the abnormally warm winter weather which has reduced the demand for natural gas.  We plan to resume our natural gas production from the Madisonville Field when natural gas prices recover from the recently depressed levels, thus providing a better economic return.  We will monitor market conditions and bring our natural gas production back on stream as market conditions warrant.

In April 2012, Nick DeMare indicated that he would not stand for reelection at that year's Annual Meeting.  Mr. DeMare did not reference any disagreement with the Company on any matter.  Mr. DeMare indicated that he needed to resign in order to devote all of his attention to managing his own company and his other business interests.

In April 2012, in accordance with the provisions of the Company's Bylaws, the Board of Directors unanimously adopted a resolution to reduce the size of the Board of Directors from 6 to 5 directors, effective upon the expiration of the current directors' term of office.

In May 2012, the Company extended the maturities of five promissory notes totaling $1,150,000 to January 2014 and two promissory notes totaling $365,000 to May 2014.  In connection with these extensions, the Company extended 151,500 warrants to purchase our common stock associated with the notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share.

In May 2012, Stuart J. Doshi, President and CEO, advanced to the Company two loans totaling $75,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 15,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In June 2012, Stuart J. Doshi, President and CEO, advanced to the Company four loans totaling $225,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 45,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In June 2012, the Company’s wholly owned subsidiary, GeoPetro Canada Ltd., acquired the remaining two-thirds (2/3) working interest in the Swan Hills Project, Central Alberta, Canada in exchange for an overriding royalty interest.  Following the acquisition, the Company now owns 100% of the working interest in the Project.

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On June 28, 2012, the Company received notice from NYSE MKT LLC (the “Exchange”) indicating that the Company is not in compliance with one of the Exchange’s continued listing standards. Specifically, the Exchange has notified the Company that it is not in compliance with Section 1003(a)(iv) of the Exchange’s Company Guide in that the Exchange believes that the Company has sustained losses which are so substantial in relation to its overall operations or its existing financial resources, or its financial condition has become so impaired that it appears questionable, in the opinion of the Exchange, as to whether the Company will be able to continue operations and/or meet its obligations as they mature. In order to maintain the listing of the Company’s common stock on the Exchange, the Company was required to submit a plan to the Exchange by July 30, 2012, addressing how the Company intended to regain compliance with Section 1003(a)(iv) by September 28, 2012 (the “Plan Period”). On July 30, 2012, the Company filed a plan with the Exchange as required. On August 27, 2012, the Exchange notified the Company that it had accepted the Company’s plan of compliance and granted the Company an extension, until September 28, 2012, to regain compliance with the continued listing standards. On October 9, 2012, the Exchange notified the Company that the Exchange had determined that, in accordance with Section 1009 of the Company Guide, the Company had made a reasonable demonstration of its ability to regain compliance with Section 1003(a)(iv) of the Company Guide by the end of the revised plan period, which is now determined by the Exchange to be December 31, 2012. As a result, the Exchange is continuing the Company's listing pursuant to this extension. The Company will be subject to periodic reviews by the Exchange during the extension period covered by the plan. Failure to make progress consistent with the plan or to regain compliance with continued listing standards by the end of the extension period could result in the Company being delisted from the Exchange.

In July 2012, Stuart J. Doshi, President and CEO, advanced to the Company two loans totaling $75,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 15,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In August 2012, the Company issued 45,000 warrants to purchase our common stock in exchange for certain consulting services, valued at $2,986. Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of four years.

In August 2012, the Company issued 225,000 shares of common stock to our independent directors. The shares were valued at $0.14 per share and the aggregate value of the shares issued was $31,500.  We agreed to grant "piggyback" registration rights to the directors with respect to the shares of common stock.

In August 2012, the Company granted 675,000 stock options at an exercise price of $0.16 per share.  These options will vest ratably over five years pursuant to the terms of the 2004 Stock Option and Appreciation Rights Plan. 

The Company has been notified that the operator of the Bengara II Production Sharing Contract (“PSC”) has terminated negotiations with the Indonesian government for an extension of the PSC’s terms. The PSC shall now be relinquished and allowed to expire in accordance with its terms. As a result, the Company has recorded an impairment charge of $587,040 to its oil and gas properties.

In October 2012, the Company issued 72,000 warrants to purchase our common stock in exchange for certain consulting services, valued at $5,887. Each warrant entitles the holder to acquire one common share at a price ranging from $0.10 to $0.23 per share for a period of five years.

In November 2012, Hein & Associates LLP notified us that they declined to stand for re-election as the Company’s independent registered public accounting firm.

In November 2012, Stuart J. Doshi, President and CEO, advanced to the Company two loans totaling $60,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 12,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In November 2012, the Company issued 30,000 warrants to purchase our common stock in exchange for certain consulting services, valued at $1,014. Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

On November 21, 2012, the Company received a notice from the Exchange stating that the Company is not in compliance with Section 1003(f)(v) of the Exchange's Company Guide. Specifically, the Exchange Staff has determined that the Company's securities have been selling for a low price per share for a substantial period of time and, pursuant to Section 1003(f)(v) of the Company guide, the Company's continued listing is predicated on it effecting a reverse stock split of its Common Stock no later than May 21, 2013.

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In November 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $10,000, and represented the sale of 100,000 common shares and 50,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In December 2012, Stuart J. Doshi, President and CEO, advanced to the Company a loan for $30,000.  The note bears interest at 10% per annum and is payable on demand.  In connection with this note, the Company issued 6,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In December 2012, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $100,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In January 2013, the Company engaged Burr Pilger Mayer, Inc. as its independent registered public accounting firm to audit the Company’s financial statements for the fiscal year ended December 31, 2012.

In January 2013, Stuart J. Doshi, President and CEO, advanced to the Company a loan for $5,000.  The note bears interest at 10% per annum and is payable on demand.  In connection with this note, the Company issued 1,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In January 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $132,500, and represented the sale of 1,325,000 common shares and 662,500 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In January 2013, we agreed to rescind a unit subscription agreement. Units were originally priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitled the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units originally sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  The Company is reacquiring the common shares and warrants in exchange for a non-interest bearing unsecured note for $250,000 which matures in July 2014.

In February 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $122,500, and represented the sale of 1,225,000 common shares and 612,500 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

On February 28, 2013, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”), with MCW Energy Group Limited, an Ontario corporation (“MCW”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“Merger Sub”). Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “Merger”) and the Company will survive the Merger and continue as a subsidiary of MCW. The Merger Agreement has been approved by Boards of Directors of each of the Company, MCW and Merger Sub.  The merger is subject to customary closing conditions, including regulatory and shareholder approval.

In March 2013, Stuart J. Doshi, President and CEO, advanced to the Company three loans totaling $85,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with this note, the Company issued 17,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

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In March 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $50,000, and represented the sale of 500,000 common shares and 250,000 warrants.  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

On April 4, 2013, the Company entered into an amendment (the “ Amendment ”) to the Agreement and Plan of Merger (the “ Merger Agreement ”), with MCW Energy Group Limited, an Ontario corporation (“ Parent ”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“ Merger Sub ”) dated February 28, 2013. Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “ Merger ”) and the Company will survive the Merger and continue as a subsidiary of Parent.

On April 10, 2013, the Company received notice from the Exchange indicating that after a review of the Plan, and the request by the Company to extend the Plan Period until July 31, 2013, the Exchange determined that the Company has not made sufficient progress consistent with the Plan in order to regain compliance with Section 1003(a)(iv) of the Company Guide by July 31, 2013 and that its securities are, therefore, subject to being delisted from the Exchange.  In the April 10, 2013 notice, the Exchange also informed the Company that, in accordance with Sections 1203 and 1009(d) of the Company Guide, the Company has a right to appeal the Exchange’s determination by requesting an oral hearing or a hearing based on a written submission before the Exchange’s Listing Qualifications Panel (the “Panel”).  The Company intends to appeal the Exchange’s determination by requesting an oral hearing before the Panel, which request will stay the delisting determination until at least such time as the Panel renders a determination following the hearing.The Company anticipates that the hearing will take place in approximately 6 to 8 weeks.  The Company is undertaking steps to address the deficiencies raised by the Exchange.  However, there can be no assurance that the Company will be successful in its appeal and that the Company’s request for continued listing will be granted. 

Liquidity and Capital Resources

We had a working capital deficit of $4,200,568 at December 31, 2012 versus $2,059,100 at December 31, 2011. Our working capital deficit increased during the year ended December 31, 2012 primarily due to losses incurred in connection with natural gas operations.

Our cash balance at December 31, 2012 of $59,432 compared to a cash balance of $916,741 at December 31, 2011. The change in our cash balance is summarized as follows:

Cash balance at December 31, 2011	$	916,741
Sources of cash:
Cash provided by investing activities		523,786
Cash provided by financing activities		925,000
Total sources of cash including cash on hand		2,365,527
Uses of cash:
Cash used by operating activities		(2,000,278	)
Cash used in investing activities		(230,817	)
Cash used in financing activities		(75,000	)
Total uses of cash		(2,306,095	)
Cash balance at December 31, 2012	$	59,432

Net cash used in operating activities of $2,000,278  and $4,403,330 for the years ended December 31, 2012 and 2011 respectively are attributable to our net loss adjusted for non-cash charges as presented in the consolidated statements of cash flows and changes in working capital as discussed above.

We have historically financed our business activities through December 31, 2012 principally through issuances of preferred stock, issuances of common shares, promissory notes, and the exercise of common share purchase warrants in private placements. These financings are summarized as follows:

	For the Years Ended December 31,
	2012			2011
Proceeds from sale of common shares and warrant exercises, net	$	360,000		$	1,479,208
Proceeds from promissory notes		—			1,000,000
Repayments of promissory notes		(75,000	)		(5,947,847	)
Proceeds from related party notes		565,000			125,000
Repayment of related party note		—			(125,000	)
Payment of loan fee		—			(27,000	)
Net cash provided by (used in) financing activities	$	850,000		$	(3,495,639	)

In March 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  In November and December 2012, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $110,000, and represented the sale of 1,100,000 common shares and 550,000 warrants.

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During 2012, Stuart J. Doshi, President and CEO, advanced to us twelve loans in the amount of $565,000. The notes accrue interest at 10% annually and are payable on demand.

In 2012 we paid $75,000 in repayment of promissory notes.

In February 2011, Stuart J. Doshi, President and CEO, advanced to us a loan in the amount of $125,000. The note accrued interest at 8% annually and was payable on demand.

In March 2011, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.45 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.75 for a period of three years. The total aggregate purchase price for the units sold was $922,648, and represented the sale of 2,050,328 common shares and 1,025,164 warrants.  In June 2011, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.55 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $1.00 for a period of three years. The total aggregate purchase price for the units sold was $556,560, and represented the sale of 1,011,928 common shares and 505,965 warrants.

In June and July 2011, pursuant to the Fifth Amendment of the Amended and Restated Term Loan Agreement with BOK, the Company took additional advances totaling $1,000,000.

In 2011 we paid $6,099,847 in repayments of promissory notes, the repayment of a related party note and loan fees.

The net proceeds of our equity and note financings coupled with net cash provided by investing activities of $292,969 and $7,867,847 in 2012 and 2011, resulting primarily from the sale of certain mineral rights in 2012 and the sale of certain idle and non-income producing equipment in 2011, were primarily used to fund operating activities and invested in oil and natural gas properties and our gas processing plant totaling $244,705, and $1,382,153 for the years ended December 31, 2012 and 2011, respectively.

Our current cash and cash equivalents and anticipated cash flow from operations may not be sufficient to meet our working capital, capital expenditures and growth strategy requirements for the foreseeable future. See “Outlook for 2013/2014 Capital” for a description of our expected capital expenditures for 2013/2014. If we are unable to generate revenues necessary to finance our operations over the long-term, we may have to seek additional capital through the sale of our equity or borrowing. As noted in “Recent Developments,” we periodically borrow funds pursuant to promissory notes to finance our activities.

As discussed in the “Outlook for 2013/2014 Capital”, we are forecasting capital expenditures of $6.4 million during 2013. We will need to obtain adequate sources of cash to fund our anticipated capital expenditures through the end of 2013, to fund ongoing operations and to follow through with plans for continued investments in oil and gas properties. Our success, in part, depends on our ability to generate additional financing and farm-out certain of our projects.  Additionally, as a result of our liquidity concerns, we may have difficulty raising sufficient funds to meet our projected funding requirements.  See Item 1A.- “Risk Factors — Risks Related to Our Business”.

Since our inception, we have participated as a working interest owner in the acquisition of undeveloped leases, seismic options, lease options and foreign concessions and have participated in seismic surveys and the drilling of test wells on our undeveloped properties. Further leasehold acquisitions, drilling and seismic operations are planned for 2013 and future periods. In addition, exploratory and development drilling is scheduled during 2013 and future periods on our undeveloped properties. It is anticipated that these exploration activities together with others that may be entered into will impose financial requirements which will exceed our existing working capital. We may raise additional equity and/or debt capital, and we may farm-out certain of our projects to finance our continued participation in planned activities. However, if additional financing is not available, we may be compelled to reduce the scope of our business activities. If we are unable to fund planned expenditures, it may be necessary to:

· farm-out our interest in proposed wells;

· sell a portion of our interest in prospects and use the sale proceeds to fund our participation for a lesser interest;

· reduce general and administrative expenses; and/or

· forfeit our interest in wells that are proposed to be drilled.

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Outlook for 2013/2014 Capital

Depending on capital availability, we are forecasting capital spending of up to approximately $6,445,000 during the year 2013, allocated as follows:

1. Madisonville Project, Madison County, Texas — Approximately $6,095,000 may be expended in the Madisonville Field area as follows: $650,000 for the Mitchell well workover; $1,445,000 toward the fracture stimulation and hook up costs of the Wilson Well; and $4,000,000 for expansion of the gas treatment plant.

2. California— Approximately $200,000 to be utilized for land and permitting costs.

3. Canada — Approximately $150,000 to be utilized for permitting costs.

We may, in our discretion, decide to allocate resources towards other projects in addition to or in lieu of, those listed above should other opportunities arise and as circumstances warrant. We currently do not have sufficient working capital to fund the capital expenditures listed above. We may, in our discretion, fund the foregoing planned expenditures from operating cash flows, asset sales, potential debt and equity issuances and/or a combination of all four. The Madisonville Project forecasted capital expenditures will play an important part in our ability to achieve our 2013 cash flow projections. See “Liquidity and Capital Resources.”

We expect commodity prices to be volatile, reflecting the current supply and demand fundamentals for North American natural gas and world crude oil. Political and economic events around the world, which are difficult to predict, will continue to influence both oil and gas prices.

Significant price changes for oil and gas often lead to changes in the levels of drilling activity which in turn lead to changes in costs to explore, develop and acquire oil and gas reserves. Significant change in costs could affect the returns on our capital expenditures.

Income Taxes

As of December 31, 2012, GeoPetro had net operating loss (NOL) carryforwards of approximately $39,500,000 for federal income tax purposes which begin to expire in 2017.  If the Company were to experience a change in ownership under Section 382, the Company may be limited in its ability to fully utilize its net operating losses.

However, in accordance with ASC 718 (formerly SFAS 123(R)), a deferred tax asset has not been recognized for the portion of the net operating loss carryforwards that is attributable to excess tax deductions associated with the exercise of stock options which do not reduce income taxes payable. Accordingly, approximately $3,536,000 of GeoPetro’s federal NOL has not been benefited for financial statement purposes as it relates to excess tax deductions that have not reduced income taxes payable. The benefit of these excess tax deductions will not be recognized for financial statement purposes until the related deductions reduce income taxes payable.

The Company also has approximately $12,430,000 of California net operating losses and approximately $670,000 of Alaska net operating losses which begin to expire in 2012 and 2026, respectively. In accordance with ASC 718, a portion of the state NOLs has similarly not been benefited for financial statement purposes as it relates to excess tax deductions which have not resulted in the reduction of income taxes payable. The benefit of such excess tax deductions will not be recognized for financial statement purposes until the related deductions reduce state income taxes payable.

In addition, the Company has approximately $318,264 of carryforward credits in Texas, a portion of which may be utilized each year against Texas Margin Tax liability through 2027.

A significant change in our ownership may limit our ability to use these NOL carryforwards. ASC 740, Accounting for Income Taxes (formerly Statement of Financial Accounting Standards No. 109), requires that the tax benefit of such net operating loss be recorded as an asset. At December 31, 2012, we had net deferred tax assets of approximately $17,615,000 related to the NOL and other temporary differences. We have recorded a full valuation allowance of $17,615,000 at December 31, 2012 due to uncertainties surrounding the realizability of the deferred tax asset.

Off Balance Sheet Arrangements

From time to time, we may enter into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of December 31, 2012, our off-balance sheet arrangements and transactions include operating lease agreements and gas transportation commitments. We do not believe that these arrangements are reasonably likely to materially affect our liquidity or availability of, or requirements for, capital resources.

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Financial Instruments

We currently have no natural gas price financial instruments or hedges in place. Similarly, we have no financial derivatives. Our natural gas marketing contracts use “spot” market prices. Given the uncertainty of the timing and volumes of our natural gas production this year, we do not currently plan to enter into any long term fixed-price natural gas contracts, swap or hedge positions, other gas financial instruments or financial derivatives in 2013.

Impact of Inflation & Changing Prices

As the following table illustrates, average sales prices of natural gas have changed in the past two years. This has led to changes in revenues and earnings from operations:

	For the Years Ended December 31,
	2012			2011
Average Sales Prices per Mcf	$	2.18		$	3.35
Net Production Volume Mcf		161,377			291,797
Revenues	$	351,082		$	976,571
Loss from Operations (1)	$	(3,891,872	)	$	(4,911,944	)

(1) Loss from operations includes $620,656 and $750,133 in impairment expense in 2012 and 2011, respectively.

We are highly dependent upon natural gas pricing. A material decrease in current and projected natural gas prices could impair our ability to raise additional capital on acceptable terms. Likewise, a material decrease in current and projected natural gas prices could also impact our revenues and cash flows. This could impact our ability to fund future activities.

Changing prices have had a significant impact on the costs of drilling and completing wells, particularly in the Madisonville Field area where we are currently the most active. The estimated cost of drilling and completing a Rodessa formation well at approximately 12,300 feet of depth has increased from $3.0 million in 2001 to $4.2 million in 2012 due to higher costs associated with tubular goods, well equipment, and day rates for drilling contracts, among other factors. These higher costs have impacted and will continue to impact our income from operations in the form of higher depletion expense.

Critical Accounting Estimates

Our consolidated financial statements have been prepared by management in accordance with U.S. GAAP.

The preparation of consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates.

Management believes the most critical accounting policies that may have an impact on our financial results relate to the accounting for oil and gas properties. Amortization, abandonment costs and full cost ceiling limitation write-downs are all based on numerous estimates, many of which are beyond management’s control. Reserves valuation is central to much of the accounting for an oil and gas company as described below. Significant accounting policies are contained in Note 3 to the consolidated financial statements. A summary of unaudited supplementary oil and gas reserve information is contained in Note 12 to the consolidated financial statements.

The following discusses the accounting estimates that are critical in determining the reported financial results:

Oil and Gas Properties — We follow the full cost method of accounting for oil and gas producing activities as prescribed by U.S. GAAP and, accordingly, capitalize all costs incurred in the acquisition, exploration, and development drilling of proved oil and gas properties, including the costs of abandoned properties, dry holes, geophysical costs, and lease rentals. All general corporate costs are expensed as incurred. In general, sales or other dispositions of oil and gas properties are accounted for as adjustments to capitalized costs, with no gain or loss recorded. Amortization of proved oil and gas properties is computed on the units of production method based on all proved reserves on a country by country basis. Unproved oil and gas properties are assessed for impairment either individually or on an aggregate basis. The net capitalized costs of proved oil and gas properties (full cost ceiling limitation) are not to exceed their related estimated future net revenues discounted at 10%, and the lower of cost or estimated fair value of unproved properties, net of tax considerations.

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Reserves — We engage independent petroleum engineering consultants to evaluate our reserves. Reserves, future production profiles, and net revenues are estimated by independent professional reservoir engineering firms. While we engage qualified reservoir engineering firms, their estimates are inherently uncertain, involve numerous assumptions that may not be realized, and predict asset values that may not be indicative of the true market value of the assets evaluated. As a result of the inherent uncertainties and changing technical and economic assumptions, reserve estimates are subject to revisions that can materially impact our results.

Stock Based Compensation — The Company has a stock-based compensation plan that allows employees to purchase common shares of the Company. Option exercise prices approximate the market price for the common shares on the date the options were issued. Options granted under the plan are generally fully exercisable within five years and expire five to ten years after the grant date. We measure and record stock-based awards to directors, employees and consultants based on the grant-date fair value, determined using the Black-Scholes option pricing model with assumptions for: risk free interest rates, expected dividend yield, expected life of the option, and the expected volatility.  We record the compensation expense ratably over the requisite service period defined in the award.  The Company recorded $422,999 and $407,311 of stock-based employee compensation for the twelve months ended December 31, 2012 and 2011, respectively.

Risks and Uncertainties

There are a number of risks that face participants in the U.S. and international oil and natural gas industry, including a number of risks that face us in particular. Accordingly, there are risks involved in an ownership of our securities. See “Risk Factors” for a description of the principal risks faced by us.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

We are exposed to market risks arising from fluctuating prices of crude oil, natural gas and interest rates as discussed below.

Commodity Risk.  Our major commodity price risk exposure is to the prices received for our natural gas production. Realized commodity prices received for our production are the spot prices applicable to natural gas in the East Texas region. Prices received for natural gas are volatile and unpredictable and are beyond our control.

Currency Translation Risk.  Because our revenues and expenses are primarily in U.S. dollars, we have little exposure to currency translation risk, and, therefore, we have no plans in the foreseeable future to implement hedges or financial instruments to manage international currency changes.

Hedging. We did not enter into any hedging transactions during the years ended December 31, 2011 or 2012.

Item 8. Financial Statements and Supplementary Data

The reports of our independent registered public accounting firm and our consolidated financial statements and supplemental information required to be filed under Item 8 of Form 10-K are presented beginning on Page F-1 of this Form 10-K.

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

None.

Item 9A. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our President, Chief Executive Officer and Chairman and our Vice-President of Finance, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of December 31, 2012.  Based on this evaluation, we have concluded that, as of December 31, 2012, our disclosure controls and procedures were effective, in that they ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is (1) recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and (2) accumulated and communicated to our management, including our President and Chief Executive Officer and Vice President of Finance, as appropriate to allow timely decisions regarding required disclosure.

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Internal control over financial reporting

Pursuant to Section 404 of the Sarbanes-Oxley Act of 2002, we have included a report of management’s assessment of the design and effectiveness of our internal controls as part of this annual report on Form 10-K for the fiscal year ended December 31, 2012.  This annual report does not include an attestation report of the company’s registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Company’s registered public accounting firm pursuant to the rules of the SEC that permit the company to provide only management’s report in this annual report. Management’s report shall not be deemed to be filed for purposes of Section 18 of the Exchange Act or otherwise subject to the liabilities of that section.

No changes to our internal control over financial reporting occurred during the last fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act).

Item 9B. Other Information

None.

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PART III

Item 10. Directors, Executive Officers and Corporate Governance

Directors

Information is provided on the following pages about the directors, including their principal occupations for the past five years, certain other directorships, age and length of service as a director of GeoPetro.  Membership on Board committees, attendance at Board and committee meetings and ownership of GeoPetro stock are provided in separate sections following the biographical information on the directors.

Name	Age	Position with GeoPetro (1)
Stuart J. Doshi(2)	67	Director, Chairman, President and Chief Executive Officer
David V. Creel(2)	73	Director and Vice President of Exploration
Thomas D. Cunningham(3)(4)	64	Director
David G. Anderson(3)(4)	60	Director
Christopher T. Czuppon(3)(4)	36	Director

Notes:

(1)	Each director is elected or appointed to hold office until the next annual meeting of shareholders or until their successor is duly elected or appointed, unless their office is earlier vacated. Our bylaws currently authorize a minimum of four and a maximum of seven directors to serve on the Board of Directors and, by resolution of the Board of Directors, the current number of directors has been set at five.
(2)	Executive Officer.
(3)	Member of the Audit Committee.
(4)	Independent, in accordance with the rules of the NYSE MKT.

Stuart J. Doshi. Mr. Doshi, 67, has been actively engaged in the oil and gas business for the past 43 years. Mr. Doshi began his oil and gas career with Natomas Company in 1970. He held various positions of increasing responsibility in planning, corporate development and financial management with Natomas. Mr. Doshi's activities covered international oil and gas exploration and production, domestic oil and gas exploration and production, geothermal energy production, coal production and petroleum trading and marketing companies.  After leaving Natomas in 1985, Mr. Doshi served as a Senior Vice President of Energy Sources Group until 1988. Mr. Doshi then served as Vice President of Pan Pacific Petroleum, Inc. from 1988 to 1991. Immediately prior to forming GeoPetro, Mr. Doshi was the Managing Director of Sierra Overseas Corporation. Mr. Doshi founded GeoPetro in 1994 and has served as a director and our President and Chief Executive Officer since our inception and as Chairman of the Board since March 1998. Mr. Doshi is a graduate of the University of San Francisco with a Bachelor's Degree in Finance and the University of California, Santa Barbara with a Master's Degree in Economics.

Mr. Doshi is our longest-serving director, and he brings to the Board a broad array of institutional knowledge and a historical perspective.  He has served as our Chairman since 1998.  He possesses the critical historical and institutional knowledge of the Company's projects and the complex multi-jurisdictional contractual arrangements governing them.  We believe any discussions concerning the strategic direction of our Company should be conducted with this knowledge, insight and experience.  The Board of Directors believes that having Mr. Doshi serve as the Chairman of the Board of Directors is a benefit to the overall success and growth of the Company. Since he manages the day-to-day operations, he has a unique perspective on the Company's technical and financial strengths and is best positioned to chair board meetings where key business issues and corporate strategies are discussed on a routine basis.  As indicated above, Mr. Doshi has been involved in the oil and gas industry virtually all his professional life and has developed a wide network of personal and business relationships within the oil and gas industry.  His strong financial background combined with his many years of domestic and international operational experience throughout changing conditions in the market and industry provide him with the ability to successfully lead the Company.

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David V. Creel. Mr. Creel, 73, has 48 years oil and gas experience as a petroleum exploration geologist. Mr. Creel held various geological and supervisory positions in Libya during his eleven-year career with AMOSEAS (the operator for CALTEX Petroleum). Mr. Creel was also the Exploration Manager of the Rocky Mountain Region and Canada for Ladd Petroleum Company; Exploration Manager of the Rocky Mountain Region for Kilroy Company of Texas; and President of Aztec Resources Corporation. Since 1995, Mr. Creel worked as an independent geologic consultant and in June 1998 he joined GeoPetro in his current role as Vice President of Exploration. Mr. Creel has served as a director of GeoPetro since October 2001. Mr. Creel is a graduate of the University of Notre Dame with a Bachelor's degree in Geology and the University of Tulsa with a Master's degree in Geology.

Mr. Creel has been an officer and Vice President of Exploration of GeoPetro since 1998 and has served as a member of our Board for more than 10 years. Based on his experience at Ladd Petroleum Company and AMOSEAS, which is described above, Mr. Creel is able to deliver important geological and technical insights to our management and other directors on our various oil and gas projects, which are both developmental and exploratory in nature.  His prior experience in exploring diverse geologic basins in both the US and internationally for oil and gas enables him to lend expertise with respect to our geographically diverse portfolio of oil and gas assets.

Thomas D. Cunningham. Mr. Cunningham, 64, has 36 years of experience in general management, with expertise in mergers and acquisitions, foreign exchange, sales, financial analysis and personnel management. Most recently, he has served as Senior Vice President of OfficePower L.L.C., a privately owned company in the distributed generation business. Prior to joining OfficePower Inc. , Mr. Cunningham served as Executive Vice President and Chief Financial Officer of Microban International, Ltd., a seller and licensor of branded additives from 2000 to 2003. From 1997 to 2000, Mr. Cunningham was a member of the Board and Executive Vice President of EMCOR Group, Inc. Prior to EMCOR, Mr. Cunningham was with Swiss Army Brands Inc. from 1994 to 1997, where he served on the Board of Directors and as Executive Vice President and Chief Financial Officer. Prior to that position, Mr. Cunningham spent 21 years with J.P. Morgan & Co., in various positions of increasing responsibility and last served as Managing Director in the Corporate Banking Group. Mr. Cunningham has served as a director of GeoPetro since April 2000. Mr. Cunningham is a graduate of Harvard College with a Bachelor's degree in Economics and Columbia University with a Master's degree in Business Administration.

Mr. Cunningham has been a member of our Board for 13 years, and has provided independent leadership to our Board as our Audit Committee Chairman. In addition to having extensive historical knowledge of GeoPetro and its business, Mr. Cunningham brings to the Board a wide range of experience with respect to senior management and corporate finance which supports the Board's management oversight role as well as its commitment to oversee and direct corporate strategy.  In recognition of Mr. Cunningham's skills in overseeing GeoPetro's financial reporting as well as his overall leadership abilities, his fellow directors elected him as Chairman of the Audit Committee.

David G. Anderson. Mr. Anderson, 60, became Vice Chairman of Dundee Securities Ltd. in November 2009. Prior to that time, he was a Senior Vice President and director of Dundee Securities Corporation where he has managed the firm's investment banking and capital markets activities since 1998. Mr. Anderson began his career with the National Energy Board of Canada in 1976 and later was employed by Amoco Production Company from 1978 to 1986 in its Calgary, Chicago and Houston offices. In 1987, Mr. Anderson returned to Canada with Midland Doherty and later joined BBN James Capel where he was the Managing Director from 1988 to 1995. From 1995 to 1998, Mr. Anderson was a partner and Managing Director with another investment dealer, Loewen, Ondaatje, McCutcheon Limited. Mr. Anderson has served as a director of GeoPetro since March 2006. Mr. Anderson is a graduate from the University of Manitoba with a Master's degree in Business Administration and Bachelor's degree in Arts.

Mr. Anderson has been a member of our Board for 7 years, and currently serves on our Audit Committee.  Mr. Anderson provides the Board with a combination of historical industry perspective and an extensive understanding of the industry's current challenges and opportunities, both as an investment banker and experienced business person in our industry. Mr. Anderson brings extensive senior management and capital markets experience including acquisitions, divestitures, spin-offs, and cross-border transactions.  His expertise is valuable in directing corporate strategy.

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Christopher T. Czuppon. Mr. Czuppon, 36, is the Managing Director of CC Natural Resource Partners, LLC and has held that position from 2009 to present. He has thirtenn years of experience in the energy corporate finance industry focusing his efforts in exploration and production, oilfield services, midstream, electric power and renewable and alternative fuels. Specifically, he has worked in the energy industry on the investment banking, business development and direct private investment aspects of the business. Prior to founding CC Natural Resource Partners, Mr. Czuppon was employed by Energy Capital Solutions, an energy focused investment bank, from February 2004 until March 2009.  Mr. Czuppon served as lead banker and an integral deal team member on financing and advisory mandates as well as new business development for micro-cap and small-cap energy companies. Mr. Czuppon's transaction experience for public and private companies includes 15 M&A transactions totaling $1.0 billion in value, 41 private placement transactions totaling $1.2 billion in total capital raised and 24 senior and mezzanine debt transactions totaling $1.2 billion in total debt capital raised.  Mr. Czuppon was an Analyst with the Hunt Oil Company's business development and energy private equity group focusing on midstream oil and gas, oilfield services, and power transactions from 2003 to 2004. Prior to his role with the Hunt Oil Company, Mr. Czuppon worked for the Hunt Power Company as a financial analyst in a similar capacity.  The Board has determined that he is an "audit committee financial expert" as defined by SEC rules.  Mr. Czuppon earned a B.A. in economics from the University of Texas at Austin with concentrations in money and banking and public finance.

Mr. Czuppon has been a member of our Board for 3 years, and currently serves on our Audit Committee.  Mr. Czuppon's acumen in corporate finance brings additional vigor and sharpness to our Board of Directors.  Mr. Czuppon has a strong background in providing financial transactional services on a wide range of corporate matters including mergers and acquisitions, private placements, debt and equity financings.  His expertise is valuable to us in the execution of our corporate strategy.

Executive Officers

The following table provides information regarding our executive officers, their ages, the year in which each first became an officer of the Company and descriptions of their backgrounds.

Name

Stuart J. Doshi (67)

President, CEO and Chairman (a)

David V. Creel (73)

Vice President of Exploration and Director (a)

Dale W. Dvoracek (48)

Vice President of Finance (b)

(a) Information regarding the executive officers is provided under “Directors.”

(b) Dale W. Dvoracek was appointed as the Company's Principal Accounting Officer in October 2011 and currently serves as the Company’s Vice President of Finance.

Legal Proceedings

Currently, no director or executive officer is a party to any legal proceeding adverse to the interests of the Company.  Additionally, no director or executive officer has an interest in any proceeding adverse to the Company.

Section 16(a) Beneficial Ownership Reporting Compliance

Section 16(a) of the Securities Exchange Act of 1934 (the "Exchange Act") requires our officers, directors and persons who beneficially own more than ten percent of our common stock to file reports of securities ownership and changes in such ownership with the Securities and Exchange Commission ("SEC").  Officers, directors and greater than ten percent beneficial owners also are required by rules promulgated by the SEC to furnish us with copies of all Section 16(a) forms they file.  Based on a review of such reports we believe that during our fiscal year ended December 31, 2012, all Section 16(a) filing requirements applicable to our officers, directors and greater than ten percent beneficial owners were timely complied with.

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Code of Business Conduct and Ethics

Our board of directors has adopted a code of business conduct and ethics that applies to all of our employees, executive officers and directors. Our code of business conduct and ethics is posted on our website, www.geopetro.com, under the Investor Relations section.  In addition, a copy of the code of business conduct and ethics will be provided without charge upon request to the Corporate Secretary, GeoPetro Resources Company, 150 California Street, Suite 600, San Francisco, CA 94111.  We intend to disclose any future amendments to certain provisions of our code of business conduct and ethics, or waivers to such provisions, applicable to our directors and executive officers, at the same location on our website identified above.  The inclusion of our website address in this proxy statement does not include or incorporate by reference the information on our website into this proxy statement.

Corporate Governance

Board of Directors

David Anderson, Thomas Cunningham and Christopher Czuppon, current directors, are independent as defined by the rules of the NYSE MKT. Stuart Doshi and David Creel, current directors, are not independent as defined by the rules of the NYSE MKT. Our Board of Directors is currently comprised of a majority of independent directors. 

Company Leadership Structure

Stuart Doshi serves as both the principal executive officer and board chairman.  We believe this board leadership structure is appropriate given the specific characteristics and circumstances of the Company.  Specifically, we believe it is appropriate due to the relatively small size of the Company (i.e. less than $100 million in assets) and the fact that Mr. Doshi possesses the critical historical and institutional knowledge of the Company's projects and the complex multi-jurisdictional contractual arrangements governing them.  We believe any discussions concerning the strategic direction of our Company should be conducted with this knowledge, insight and experience. In his capacity as Chairman, Mr. Doshi has the following responsibilities:

· Calls meetings of the Board,

· Chairs meetings of the Board and the Annual Shareholders' Meeting,

· Establishes Board meeting schedules and agendas,

· Ensures that information provided to the Board is timely, complete, and accurate,

· Communicates with all directors on key issues and concerns outside of Board meetings, and

· Represents the Company to and interacts with shareholders and employees.

The Board of Directors believes that having Mr. Doshi serve as both the Chief Executive Officer and the Chairman of the Board of Directors is a benefit to the overall success and growth of the Company. Since he manages the day-to-day operations, he has a unique perspective on the Company's technical and financial strengths and is best positioned to chair board meetings where key business issues and corporate strategies are discussed on a routine basis.

The strong working relationships among Mr. Doshi and the other Directors foster open communications among the members of the Board.  The Board believes that such communication is vital to understanding issues, promoting oversight, and encouraging the frank discussion of matters essential to leading a complex and dynamic company.

We will continue to examine our corporate governance policies and leadership structures on an ongoing basis to ensure that they continue to meet the Company's needs.

The Company does not have a lead independent director.

The board of directors and its audit committee play a critical role in risk oversight by establishing the right environment or tone at the top by senior executives and others throughout the enterprise. It is the board's responsibility to represent the interests of shareholders.  The board also plays a vital role in overseeing management's approach to enterprise risk management, including the determination of the Company's appetite for risk.

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Committees of the Board of Directors

We have an Audit Committee of the Board of Directors which complies with the rules of the NYSE MKT and the SEC.  Our Audit Committee charter is available on our website, www.geopetro.com, under the investor relations section. The inclusion of our website address in this proxy statement does not include or incorporate by reference the information on our website into this proxy statement.

Audit Committee

Our Audit Committee currently consists of three directors, Thomas Cunningham, Christopher Czuppon and David Anderson. Messrs. Cunningham, Czuppon and Anderson are independent as defined by the rules of the NYSE MKT and the SEC. Each member of the Audit Committee meets the financial literacy and experience requirements of the SEC and NYSE MKT rules. Mr. Cunningham serves as the chairperson of the Audit Committee and Christopher Czuppon is an "audit committee financial expert" under applicable SEC rules.  Our Audit Committee operates pursuant to a written charter that satisfies applicable SEC and NYSE MKT rules.  Our Audit Committee charter is available on our website at http://www.geopetro.com.

Our Audit Committee charter requires that the Audit Committee oversee our corporate accounting and financial reporting processes. The primary duties of our Audit Committee are to, among other things:

· evaluate our independent auditors' qualifications, independence and performance;

· determine the engagement and compensation of our independent auditors;

· approve the retention of our independent auditors to perform any audit and permissible non-audit services;

· monitor the rotation of partners of the independent auditors on our engagement team as required;

· review our consolidated financial statements;

· review our critical accounting policies;

· meet with our management periodically to consider the adequacy of our internal controls and procedures for financial reporting;

· establish procedures for the receipt, retention and treatment of complaints regarding accounting, internal accounting controls or auditing matters and the confidential, anonymous submissions by employees of concerns regarding questionable accounting or auditing matters;

· review on an ongoing basis and approve related party transactions;

· prepare the reports required by the rules of the SEC to be included in our annual proxy statement;

· discuss with our management and our independent auditors the results of our annual audit and the review of our quarterly consolidated financial statements.

Audit Committee Report (1)

Our Audit Committee currently consists of three directors, Thomas Cunningham, Christopher Czuppon and David Anderson. Messrs. Cunningham, Czuppon and Anderson are independent as defined by the rules of the NYSE MKT and the SEC. Each member of the Audit Committee meets the financial literacy and experience requirements of the SEC and NYSE MKT rules. Mr. Cunningham serves as the chairperson of the Audit Committee and Christopher Czuppon is an "audit committee financial expert" under applicable SEC rules. We have adopted an Audit Committee charter that satisfies applicable SEC and NYSE MKT rules.  The Committee met five times during fiscal year 2012 to fulfill its responsibilities.

The role of the Audit Committee is to oversee the Company's financial reporting process on behalf of the Board of Directors.  Management is responsible for the Company's accounting, consolidated financial statements and financial reporting processes. The Company's independent auditor is responsible for performing an independent audit of the Company's consolidated financial statements and expressing an opinion as to the conformity of such consolidated financial statements with generally accepted auditing standards.

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In this context, the Committee has reviewed and discussed the audited financial statements of the Company as of and for the year ended December 31, 2012 with management and Burr Pilger Mayer Inc. ("Burr Pilger Mayer"), the Company's independent auditor. The Committee discussed with Burr Pilger Mayer matters required to be discussed by Statement on Auditing Standards No. 61, as amended (AICPA, Professional Standards, Vol. 1.AU Section 380) as adopted by the Public Company Accounting Oversight Board in Rule 3200T.  In addition, the Committee has received the written disclosures and the letter from Burr Pilger Mayer required by the applicable requirements of the Public Company Accounting Oversight Board regarding Burr Pilger Mayer’s communications with the Audit Committee concerning independence.  The Audit Committee discussed their independence with them and satisfied itself of the independence of the independent registered public accountants. The Committee considered the effects that the provision of non-audit services may have on the auditor's independence.

Based on the reviews and discussions referred to in this report, and subject to the limitations on the role and responsibilities of the Committee referred to in its charter, the Committee recommended to the Board of Directors that the audited consolidated financial statements be included in the Company's Annual Report on Form 10-K for the year ended December 31, 2012 filed with the SEC.

THE AUDIT COMMITTEE

Thomas Cunningham (Chair)

David Anderson

Christopher Czuppon

(1) SEC filings sometimes incorporate information by reference.  This means that the Company is referring you to information that has previously been filed with the SEC, and that this information should be considered as part of the filing you are reading.  Unless GeoPetro specifically states otherwise, this report shall not be deemed to be incorporated by reference and shall not constitute soliciting material or otherwise be considered filed under the Securities Act or the Securities Exchange Act.

Compensation Committee

We do not have a Compensation Committee and, as such, we do not have a Compensation Committee charter. The Board of Directors believes that it is in the best interest of the Company to permit all independent directors to fully participate in the compensation decisions for our executive officers, as well as our directors. In accordance with the rules of the NYSE MKT, the compensation of our Chief Executive Officer and all other executive officers is determined, or recommended to the Board of Directors for determination, by a majority of independent directors.

The independent directors' duties include:

· establishing overall employee compensation policies and recommending to our Board of Directors major compensation programs;

· reviewing and approving the compensation of our corporate officers and directors, including salary, bonus awards and stock option grants;

· administering our various employee benefit, pension and equity incentive programs;

· reviewing executive officer and directors indemnification and insurance matters;

· managing and reviewing employee loans; and

· preparing a report on executive compensation for inclusion in our annual report and, as applicable, our proxy or information statement.

Our current independent directors who participate in the consideration of executive officer and director compensation are David Anderson, Thomas Cunningham and Christopher Czuppon.  In establishing compensation for our executive officers and directors, we do not rely on independent compensation consultants to analyze or prepare formal surveys for us.  Our independent directors review executive compensation on an annual basis.  In establishing compensation to our executives, we strive to provide compensation that will:  (1) motivate and retain executives and reward performance; (2) encourage our long-term success; (3) encourage the long-term enhancement of shareholder value; and (4) encourage the application of prudent decision-making processes in an industry marked by volatility and high risk.

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Nominating Committee

We do not have a Nominating Committee and, as such, we do not have a Nominating Committee charter. The Board of Directors believes that it is in the best interest of the Company to permit all independent directors to fully participate in the director nomination process. In accordance with the rules of the NYSE MKT, director nominees are selected, or recommended to the Board of Directors for selection, by a majority of independent directors. The independent directors do not have a policy that considers diversity when identifying nominees for director. In addition, the independent directors' duties include:

· establishing standards for service on our Board of Directors and nominating guidelines and principles;

· identifying individuals qualified to become members of our Board of Directors and recommending director candidates for election to our Board of Directors;

· considering and making recommendations to our Board of Directors regarding its size and composition, committee composition and structure and procedures affecting directors;

· establishing policies regarding the consideration of any director candidates recommended by our shareholders, and the procedures to be followed by shareholders in submitting such recommendations;

· evaluating and reviewing the performance of existing directors; and

· monitoring our corporate governance principles and practices and making recommendations to our Board of Directors regarding governance matters, including our articles of incorporation, bylaws and charters of our committees.

Our current independent directors who participate in the consideration of director nominees are David Anderson, Thomas Cunningham and Christopher Czuppon.  At an appropriate time prior to each annual meeting of shareholders at which directors are to be elected or reelected, and whenever there is otherwise a vacancy on the Board, the independent directors who participate in the consideration of director nominees will assess the qualifications and effectiveness of the current board members and, to the extent there is a need, shall actively seek additional individuals well-qualified and available to serve to become board members.  Members of management, the independent directors or any other member of the board may identify a need to add a new member to the board with specific criteria at any other time.  Shareholders of the Company may identify a potential director candidate in accordance with the procedures set forth below.  The independent directors may choose to hire an independent search firm to identify potential director candidates in those situations where particular qualifications are required or where existing contacts are not sufficient to identify an appropriate candidate.

We have adopted procedures by which shareholders may recommend director candidates for membership to our board.  Each shareholder recommending a person as a director candidate must provide the Company at its principal executives offices with the following information in order for the independent directors to determine whether the recommended director candidate is independent from the shareholder or each member of the shareholder group that has recommended the director candidate:

(i) If the recommending shareholder or any member of the recommending shareholder group is a natural person, whether the recommended director candidate is the recommending shareholder, a member of the recommending shareholder group, or a member of the immediate family of the recommending shareholder or any member of the recommending shareholder group;

(ii) If the recommending shareholder or any member of the recommending shareholder group is an entity, whether the recommended director candidate or any immediate family member of the recommended director candidate has been an employee of the recommending shareholder or any member of the recommending shareholder group during the then-current calendar year or during the immediately preceding calendar year;

(iii) Whether the recommended director candidate or any immediate family member of the recommended director candidate has, during the year of the nomination or the preceding three fiscal years of the Company, accepted directly or indirectly any consulting, advisory, or other compensatory fee from the recommending shareholder or any member of the group of recommending shareholders or any affiliate of any such holder or member, provided that compensatory fees would not include the receipt of fixed amounts of compensation under a retirement plan (including deferred compensation) for prior service with such holder or any such member (provided that such compensation is not contingent in any way on continued service);

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(iv) Whether the recommended director candidate is an executive officer or director (or person fulfilling similar functions) of the recommending shareholder or any member of the recommending shareholder group, or of an affiliate of the recommending shareholder or any such member of the recommending shareholder group; and

(v) Whether the recommended director candidate controls the recommending shareholder or any member of the recommending shareholder group (or in the case of a holder or member that is a fund, an interested person of such holder or any such member as defined in Section 2(a)(19) of the Investment Company Act).

Each shareholder recommending a person as a director candidate or the person recommended by a shareholder as a director candidate must provide the Company with such information as may be reasonably required to determine whether the recommended director candidate is qualified to serve on the Audit Committee of the board, so that the independent directors may assess whether, if the candidate were elected to the board, the board as then composed would have a sufficient number of directors qualified to serve on the Audit Committee in accordance with the rules of the NYSE MKT and the Securities and Exchange Commission.

Each shareholder recommending a person as a director candidate or the person recommended by a shareholder as a director candidate must provide the Company with such information as may be reasonably required to determine whether the director candidate meets the standards of independence established by NYSE MKT and the SEC so that the independent directors may assess whether, if the candidate were elected to the board, the board as then composed would have a sufficient number of independent directors.

The Company may request from the recommending shareholder such other information as may reasonably be required to determine whether each person recommended by a shareholder as a director candidate meets the minimum director qualifications established by the Company's board, to enable the Company to make appropriate disclosures to shareholders entitled to vote in the next election of directors.

The shareholder must submit a detailed resume for the candidate and an explanation of the reasons why the shareholder believes this candidate is qualified for service on the board.  The shareholder must include the consent of the candidate and describe any arrangements or undertakings between the shareholder and the candidate regarding the nomination.  The shareholder must also submit proof of his, her or its Company stockholdings.

The person recommended by a shareholder as a director candidate shall make himself or herself reasonably available to be interviewed by the independent directors and members of management, as determined appropriate by the independent directors.  The Company will not accept a shareholder recommendation for a director candidate if the recommended candidate's candidacy or, if elected, board membership, would violate controlling state law, federal law or the rules of any exchange or market on which the Company's securities are listed or traded.

The independent directors evaluate nominees recommended by shareholders on the same basis as nominees recommended by any other source.  Nominations to the board may be submitted by shareholders of the Company for consideration by the Board of Directors by sending such nominations to: Stuart J. Doshi, Chairman, President and Chief Executive Officer, GeoPetro Resources Company, 150 California Street, Suite 600, San Francisco, CA 94111.

Currently, there are no specific minimum qualifications that the independent directors believe must be met by a nominee for director, whether such director is recommended by a shareholder or identified by the independent directors.  In making their assessment of nominees, the independent directors seek candidates who meet the current challenges and needs of the board.  In making their assessment, the independent directors may request that nominees complete and return a questionnaire prepared by the Company.  The independent directors will consider issues of independence, knowledge, judgment, diversity, skills, education, character, standing in the community, and industry and financial background and experience.  If the independent directors preliminarily determine that the potential candidate is qualified to fill a vacancy or to satisfy a particular need after a preliminary inquiry, the independent directors will make an investigation and interview the potential candidate, as necessary, to make an informed final determination.  During this process, the independent directors may solicit input from other members of the Board, the Company's Chief Executive Officer and members of the Company's senior management, as the independent directors deem appropriate, during the interview and evaluation process, regardless of who recommended the candidate.

Meetings of the Board and the Committees of the Board

During 2012, the Board of Directors held seven regular meetings.  In 2012, the Audit Committee held five regular meetings.  All of the directors attended 100 percent of the meetings of the Board and of the committee on which they served during that period, except David Anderson who attended all of the Board meetings and eighty percent of the Audit Committee meetings due to scheduling conflicts.  Mr. Anderson was briefed by Mr. Doshi on these occasions.   Directors are expected to attend our annual meeting of shareholders.  All of our directors attended our annual meeting of shareholders in 2012.

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Communications with the Board of Directors

If a shareholder would like to write to the Board, he or she may send written correspondence to the following address:  GeoPetro Resources Company, Attn:  Board of Directors, 150 California Street, Suite 600, San Francisco, CA 94111.  Shareholders should provide proof of share ownership with their correspondence.  It is suggested that shareholders also include contact information.  All communications will be received and processed by our President, and then directed to the appropriate member(s) of the Board.  In general, correspondence relating to accounting or auditing matters will be referred to the Chairperson of the Audit Committee.  All other correspondence will be referred to the independent directors.  To the extent correspondence is addressed to a specific director or requires a specific director's attention, it will be directed to that director.

Oversight of Risk Management

The Company is exposed to a number of risks and undertakes enterprise risk management reviews to identify and evaluate these risks and to develop plans to manage them effectively. The Company's executive officers are directly responsible for the Company's enterprise risk management function and report to the Board of Directors. Although not inclusive, a list of items considered generally includes:

· accurate and complete financial reporting,

· rules and regulations of the NYSE MKT,

· environmental and safety issues,

· safeguarding of Company assets,

· adequacy of insurance protection,

· compliance with all credit facility covenants, and

· employee relations issues.

The Board of Directors plays a key role in the oversight of the Company's enterprise risk management function. Using their collective skills and experience, they consider information provided by management and provide feedback and make recommendations, if needed, to try to help minimize risk to the Company's current and future value.

Item 11. Executive Compensation

Compensation Discussion and Analysis

We do not presently have a Compensation Committee. The Board of Directors believes that it is in the best interest of the Company to permit all independent directors to fully participate in the compensation decisions for our executive officers. In accordance with the rules of the NYSE MKT, the compensation of our executive officers is determined, or recommended to the Board of Directors for determination, by a majority of independent directors. The independent directors consider the input of Stuart Doshi, our President and Chief Executive Officer, in making their recommendations for our other executive officers. The independent directors do not engage compensation consultants in formulating compensation decisions.

Our independent directors are responsible for reviewing executive compensation on an annual basis. Compensation for our executive officers consists of three components:

· base salaries;

· stock option grants; and

· cash bonuses.

In establishing the compensation paid to our executives, we emphasize providing compensation that will: (1) motivate and retain executives and reward performance; (2) encourage our long term success; (3) encourage the long term enhancement of shareholder value; and (4) encourage the application of prudent decision making processes in an industry marked by volatility and high risk.

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Historically, we have evaluated compensation paid to our executive officers based upon the following factors:

· the growth in our oil and gas reserves and production;

· cash flow;

· the extent to which our executive officers have been successful in finding and creating opportunities for us to participate in attractive oil and gas projects;

· the ability of our executives to formulate and maintain sound budgets for drilling ventures and other business activities;

· our overall financial condition;

· the extent to which proposed business plans are met; and

· by comparing the compensation packages of our executive officers with the compensation packages of executive officers of other companies in the oil and gas industry, which are similar to us in their size and operations, among other factors.

We do not assign relative weights or rankings to these factors. Instead, we make subjective determinations based upon a consideration of all of these factors. While specific performance levels or "benchmarks" are not used to establish compensation, we do take into account our overall progress over time.

In establishing compensation for our executive officers, we do not rely on independent consultants to analyze or prepare formal surveys for us; however, we make informal comparisons of our executives' compensation with the compensation paid to executives of other publicly and privately held companies similar to ours. Companies included in our informal comparisons included companies in our deemed industry peer group including Kodiak Oil and Gas Corporation (KOG), GeoMet, Inc. (GMET), Double Eagle Petroleum Co. (DBLE), and Gasco Energy, Inc. (GSX).  These companies are publicly-traded exploration and production companies. In addition, we take into account the fact that we do not provide significant perquisites and we provide no retirement plan or pension benefits to our executive officers.

Compensation Risks

Our independent directors, with the assistance of Mr. Doshi, review the elements of executive compensation to determine whether any portion of executive compensation encouraged excessive risk taking. Management of the Company conducted a similar risk assessment with respect to other employees. Management and the independent directors believe that risks arising from our compensation policies and practices for our executive officers and other employees are not reasonably likely to have a material adverse effect on the Company. In addition, we believe that the mix and design of the elements of compensation do not encourage management to assume excessive risks.

Elements of Compensation

Mr. Doshi is currently party to an employment agreement whereby he is to receive a base salary which is subject to an annual inflation adjustment based on the 1995 Consumer Price Index. In the past, we have amended Mr. Doshi's employment agreement to provide for increases in base salary. When determining base salaries, we perform a subjective analysis of each executive officer's contributions and overall performance, consider the current compensation paid to executives of similar companies, and the officer's current salary.

During 2012 and 2011, salaries accounted for approximately 75% and 90% respectively of total compensation for the Chief Executive Officer.

In reviewing the overall compensation of Mr. Doshi, our President and Chief Executive Officer, we took into account the fact that Mr. Doshi declined receiving an increase in his base salary since 2003.  In the past several years, we were faced with intense competition in the oil and gas industry, including competition for oil and gas leases, and scarcity of available drilling rigs and goods and services related to the drilling, testing and completion of wells, and more recently, scarcity of capital and weakening natural gas prices. While industry competition has softened somewhat with the recent economic downturn, in the prior years, competition was intense, particularly from competitors that have similar or greater financial and human resources than we do.  We believe the insight, experience and leadership of Mr. Doshi has been instrumental in keeping us positioned to access sufficient capital and remain competitive. Additionally, Mr. Doshi, in his capacity as President and Chief Executive Officer, has been responsible for achieving a number of historical benchmarks for us, including, but not limited to:

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· Negotiating with Hanover Compression Limited Partnership and Gateway Processing Company the installation and construction of a new gas treatment plant and related pipelines which became operational in 2003 in the Madisonville Project, which was necessary in order to treat natural gas production from our wells in the Madisonville Field in Texas.

· Arranging the sale of the gas treatment plant by Hanover to Madisonville Gas Processing, LP and the related commitment by MGP to expand the treating capacity of the plant from 18 million cubic feet of natural gas per day to 68 million cubic feet of natural gas per day.

· Negotiating on favorable terms to the Company the purchase of the Madisonville gas treatment plant and related gathering pipelines in exchange for the assumption of secured bank debt, payment of certain outstanding payables and shares of GeoPetro's common stock. 

· The drilling of additional wells at the Madisonville Project in an industry environment affected by intense competition and shortages of available drilling rigs and associated goods and services.

· On March 30, 2006, we completed an initial public offering in Canada, which consisted of 3,730,021 shares of common stock at an issue price of $3.50 per share and 519,500 shares of common stock issued on a "flow-through" basis under the Income Tax Act (Canada) at an issue price of $3.85 per share for aggregate gross proceeds of $15,055,149.

· On September 29, 2006 we sold 70% of our interest in C-G Bengara to CNPCHK (Indonesia) Limited in exchange for a substantial financial commitment from CNPC to conduct exploration, appraisal and development activities on the Bengara II PSC production sharing contract in Indonesia.

· The sale of an interest in October 2005 in another Indonesian production sharing contract for cash consideration of $2,400,000.

· The settlement in June 2006 of all of our pending litigation related the Miller and Mejlaender lawsuits.

· Approval of S-1 Registration Statement and the subsequent Company listing on the American Stock Exchange under the symbol "GPR" providing shareholders with a significant increase in liquidity and increase in trading volume.

· Extending leases for the deep rights in Madisonville, Texas and the Lokern Project in the San Joaquin basin of California.

· Completing a $7.7 million common stock offering at $3.85 per unit and satisfying subsequent registration requirements in May, 2008.

· Completing, under difficult market conditions, financings totaling $1.8 million by issuing promissory notes and $5.5 million, net of offering costs, through the issuance of Series B Convertible Preferred Stock to accredited investors in 2009.

· Selling our working interest in the Alaska Leases in the Cook Inlet Region of Alaska to Linc Energy (Alaska) Inc. for upfront cash and significant overriding royalty interests.

· In 2010, raising an additional $2.3 million in equity capital and $0.675 million in debt on favorable terms.

· Securing loan extensions and negotiating a lower interest rate with Bank of Oklahoma, National Association, and securing loan extensions with certain non-bank lenders.

· Settling Devon Energy overriding royalty claims on favorable terms.

· Completing a unit sale through a private placement for a total of $922,648 on favorable terms in March 2011.

· Completing a unit sale through a private placement transaction for a total of $556,560 on favorable terms in June 2011.

· The sale of certain idle and non-income producing plant equipment at the Madisonville Plant to Peregrine Midstream Partners LLC for a final sales price of $9,250,000.  As a result of this transaction, GeoPetro recognized a significant gain on the sale of the equipment of $4,069,640 in 2011.

· Negotiating the terms of the proposed merger with MCW Energy Group Limited.

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When awarding stock options, we attempt to provide executives with an incentive compensation vehicle that could result in future additional compensation to them, but only if the value of our common stock increases for all shareholders. We perform a subjective analysis of each executive officer's contributions, and we consider the number of options granted on prior occasions and the length of time between option grants. All stock options are granted with exercise prices equal to or above the fair market value of the common stock on the date of grant.

In 2004, we implemented a new 2004 Stock Option and Appreciation Rights Plan (the "Stock Option Plan") providing for awards of incentive stock options, non-qualified stock options and stock appreciation rights. The Stock Option Plan replaced the 2001 Stock Incentive Plan as to new award grants effective in 2004 or thereafter to our directors, officers, employees and consultants. The terms of the Stock Option Plan govern future grants to our named executive officers. The terms provide, among other things, that the exercise price of option grants shall be no less than 110% of the fair market value of the common stock on the date of grant and that such grant shall vest at a rate no less than twenty percent (20%) over five years from the date of grant. We do not have specific established criteria for determining the timing of option grants.

In August 2012, the independent directors determined that additional stock options should be granted to our named executives to provide a long-term incentive to remain employed with us and to work toward the long-term best interests of all of our shareholders.  The option grants in 2012 were made pursuant to our 2004 Stock Plan.  The options were granted with a five-year vesting schedule providing that 20% of the options would vest on each one year anniversary of the date of grant of August 31, 2012.   We determined that the five-year vesting schedule was appropriate to provide a long-term incentive and align the interests of our management with the interests of all our shareholders.

During 2012 and 2011, stock option equity incentives accounted for approximately 14% and 0% of total compensation of the Chief Executive Officer, approximately 17% and 0% of total compensation of the Vice President of Exploration, and approximately 7% and 13% of total compensation of the Vice President of Finance.  The Board determined that our named executive officers had a sufficient equity stake in GeoPetro, consisting of shares of common stock and/or existing options and warrants, to align their interests with GeoPetro's and our shareholders.

Bonuses for each of our named executive officers are discretionary.   In determining bonus amounts, our independent directors took into consideration that our named executive officers have significant equity interests in GeoPetro through direct ownership of shares or prior option grants, which already provide them with performance incentives.  During 2012 and 2011, no bonuses were granted to any of the named officers.  In future periods, in considering whether to award bonuses, we will consider such factors as enumerated above in determining overall compensation, with a particular emphasis on our profitability and financial condition.

We provide certain personal benefits to our Chief Executive Officer in the form of life and disability insurance. During both 2012 and 2011, personal benefits accounted for approximately 11% and 10% of total compensation for the Chief Executive Officer.

We do not have any established formal criteria to determine how decisions regarding one compensation element might affect decisions regarding other compensation elements or fit into our overall compensation objectives.

Mr. Doshi's employment agreement provides for substantial and immediate cash payments in the event of a change in control or termination. The amounts of, and the conditions precedent for, such payments are discussed in detail in this proxy statement under "Potential Payments Upon Termination or Change in Control."

It is our conclusion that the amount and types of compensation currently being paid to our executive officers are sufficient to retain and motivate them, reward their performance and encourage their efforts to increase the value of our common stock for all shareholders. We did not pay bonuses for the last several years because of the Company's performance. 

Compensation of Executive Officers

The following table sets forth all compensation awarded to, earned by or paid to our Chief Executive Officer, our Vice President of Finance and our other most highly compensated executive officers whose total compensation exceeded $100,000 for services rendered during our 2012 and 2011 fiscal years. These officers are referred to as the named executive officers. No other executive officer received total compensation of more than $100,000 in the fiscal year ended December 31, 2012 and 2011.

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Summary Compensation Table

Name and Principal Position (1)	Year	Salary ($)			Bonus ($)		All Other Compensation ($)			Option Awards ($)		Total ($)
Stuart J. Doshi	2012		200,000	(2)		—		30,024	(3)		36,727		266,751
Chairman, President and	2011		426,956	(2)		—		47,159	(3)		—		474,115
Chief Executive Officer
David V. Creel	2012		50,187	(4)		—		—			10,493		60,680
Vice President of Exploration	2011		101,646	(4)		—		—			—		101,646
Paul Maniscalco	2012		—			—		—			—		—
Former Interim Chief Financial Officer (6)	2011		24,260	(5)		—		—			—		24,260
Dale W. Dvoracek	2012		110,000	(7)		—		—			7,870		117,870
Vice President of Finance (6)	2011		46,000	(5)		—		—			6,852		52,852

(1)	None of the named executive officers received any compensation for their services as a director during 2012 or 2011.
(2)	$0 and $126,956 of Mr. Doshi's salary for 2012 and 2011, respectively, consists of an annual inflation adjustment based on the 1995 Consumer Price Index, per the terms of his employment agreement. The comparable inflation adjustment accrued and unpaid for 2012 is $140,208. In addition, Mr. Doshi has deferred a portion of his base salary in 2012.
(3)	Represents life and disability insurance premiums paid on Mr. Doshi's behalf, and automobile allowance.
(4)	Mr. Creel did not receive his full base salary during 2012 and 2011 due to temporary medical and personal leaves of absences. In 2011, Mr. Creel's schedule was reduced from full-time to part-time. Mr. Creel has deferred a portion of his base salary in 2012.
(5)	Represents a partial year of service.
(6)	Paul D. Maniscalco resigned his position as the Company's interim Chief Financial Officer in October 2011. Dale W. Dvoracek was appointed as the Company's Principal Accounting Officer in October 2011 and currently serves as the Company’s Vice President of Finance.
(7)	Mr. Dvoracek has deferred a portion of his base salary in 2012.

Employment Agreements and Potential Post-Employment Payments

We entered into a contract of employment with Stuart J. Doshi, Chairman, President and Chief Executive Officer, dated July 28, 1997 (effective July 1, 1997) and amended on January 11, 2001, July 1, 2003, April 20, 2004, May 9, 2005, July 28, 2005, January 30, 2006 and December 29 and 31, 2008. The contract as amended currently provides for a five-year term which commenced May 1, 2005 which term is automatically extended for successive two-year renewal terms unless: (a) the Board of Directors elects not to renew the contract and we provide notice to Mr. Doshi of such non-renewal at least six months prior to the expiry of his employment term or any renewal term, (b) Mr. Doshi provides notice at any time prior to the expiry of his employment term or any renewal term that he elects not to renew the contract, or (c) Mr. Doshi attains age 75, in which case the term ends upon the completion of the calendar year in which he becomes 75 years old unless we and Mr. Doshi mutually agree to one-year extensions. The contract of employment provides for an annual base salary of $300,000, subject to annual inflation adjustments based on the 1995 United States Department of Labor, Bureau of Labor Statistics Consumer Price Index of Urban Wage Earners and Clerical Workers. The contract also provided for options to purchase up to 750,000 shares of our common stock at an exercise price of $0.50 per share which options, as amended, expired on April 30, 2008.  Mr. Doshi exercised the options on April 25, 2008.  In the event that we file a registration statement under the 1933 Act, other than our initial registration statement, we have agreed to permit Mr. Doshi to include in the proposed registration the shares of our common stock that he would hold on exercise of his stock options and other securities issued to him, at no expense to him, subject to his payment of his own taxes, legal fees and underwriter's discounts, commissions and spreads.

Mr. Creel is the Vice President of Exploration for the Company.  He is currently employed on a month-to-month employment basis and earning compensation at a daily rate of $525.23.

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Paul Maniscalco was our Interim Chief Financial Officer from April 15, 2010 until October 14, 2011. Mr. Maniscalco assisted GeoPetro in preparing and reviewing the Company's financial statements and information to be included in the Company's required SEC filings. Our consulting agreement with him provided for payment of $110 per hour as well as reimbursement for out-of-pocket expenses.

Dale Dvoracek is the Vice President of Finance for the Company.  The material terms of Mr. Dvoracek's employment agreement include an annual compensation of $144,000, and a stock option grant of 25,000 common shares granted under the Company's Stock Option Plan with an exercise price of $0.50 per share vesting ratably over five years.

Outstanding Equity Awards at Year-End 2012

The following table details information with respect to all options and warrants to purchase our common stock held by our named executive officers and outstanding on December 31, 2012.

Name	Number of Securities Underlying Unexercised Options Exercisable/Unexercisable				Option Exercise Price			Option Expiration Date
Stuart J. Doshi		1,000,000/	—			$	2.10	5/13/2013
President and Chief Executive Officer		220,000/	55,000	(1)		$	0.50	6/26/2013
		—/	350,000	(1)		$	0.16	8/31/2017
David V. Creel		150,000/	—			$	2.10	5/13/2013
Vice President of Exploration		60,000/	15,000	(2)		$	0.50	6/26/2013
		—/	100,000	(2)		$	0.16	8/31/2017
Paul Maniscalco		—/	—			$
Former Interim Chief Financial Officer
Dale W. Dvoracek		5,000/	20,000	(3)		$	0.50	8/15/2016
Vice President of Finance		—/	75,000	(3)		$	0.16	8/31/2017

(1) Mr. Doshi has 405,000 common stock options which are not yet vested. The unvested common stock options will vest 20% of the original grant amount each year. Mr. Doshi must still be employed by us on the respective vesting date in order to vest his options, subject to certain exceptions. See "Potential Payments Upon Termination or Change in Control."

(2) Mr. Creel has 115,000 common stock options which are not yet vested. The unvested common stock options will vest 20% of the original grant amount each year. Mr. Creel must still be employed by us on the respective vesting date in order to vest his options. However, if Mr. Creel is terminated without cause, all unvested options shall immediately vest. See "Potential Payments Upon Termination or Change in Control."

(3) Mr. Dvoracek has 95,000 common stock options which are not yet vested. The unvested common stock options will vest 20% of the original grant amount each year. Mr. Dvoracek must still be employed by us on the respective vesting date in order to vest his options. However, if Mr. Dvoracek is terminated without cause, all unvested options shall immediately vest. See "Potential Payments Upon Termination or Change in Control."

Options Exercised and Stock Vesting in 2012

Our named executive officers did not exercise any stock options during our fiscal year 2012. None of our named executive officers holds any shares of restricted stock or any other stock awards subject to vesting requirements.

Indebtedness of Directors and Officers

None of our directors or officers, nor any of their associates or affiliates, are or have been indebted to us, nor have any of the foregoing been the subject of a guarantee, support agreement, letter of credit or similar arrangement or understanding provided by us.

Potential Payments Upon Termination or Change in Control

Mr. Doshi has an employment agreement with us which provides for payments upon the termination of employment under certain circumstances and/or upon a change in control.

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Mr. Doshi's employment contract provides that in the event of a change of control, if we do not renew Mr. Doshi's agreement, if Mr. Doshi is terminated without cause, or if Mr. Doshi terminates his employment due to our uncured, material breach of his employment contract, he is entitled to receive:

(a) in exchange for all of his vested stock options and vested restricted shares, such number of shares of common stock having a market value equal to the difference between (x) the aggregate total market value of all vested restricted shares and shares of common stock he would receive upon exercise of all vested stock options less (y) the aggregate total exercise price for all of his vested stock options; provided, however, that if the common stock to be delivered to Mr. Doshi upon such change of control or termination have not been registered so as to permit immediate public resale, Mr. Doshi shall instead receive a cash payment equal to the market value on the date of termination of all vested stock options and restricted shares without any discount for liquidity or minority position against cancellation of such options and restricted shares,

(b) a cash payment equal to the greater of (i) his salary for the remainder of his term and the aggregate amount of his bonuses in respect of the last four fiscal years and (ii) four times his compensation in the current year and the aggregate amount of his bonuses for the last four fiscal years, and

(c) an additional cash payment representing his employment benefits equal to 20% of the amount of salary he is entitled to receive under (b)(i) or (b)(ii) above, as applicable.

In addition, in the event of a change of control or termination without cause, all unvested options issued by us to Mr. Doshi will vest.

For purposes of Mr. Doshi's employment contract, "cause" for termination is either: a final felony conviction of Mr. Doshi; Mr. Doshi's willful refusal, without proper legal cause, to perform his duties or responsibilities; or Mr. Doshi continuing to willfully engage in conduct, which he knows or should have reason to know may be materially injurious to the Company, after receipt of written notice from the Company.

In the event of a change of control, if we do not renew Mr. Doshi's agreement, Mr. Doshi is terminated without cause, or Mr. Doshi terminates his employment due to our uncured, material breach of his employment contract, and assuming the triggering event took place on the last business day of the Company's last completed fiscal year, December 31, 2012, the potential post-employment benefits payable to Mr. Doshi are estimated as follows (estimates are based on the $0.07 closing market price of our common stock as quoted on the NYSE MKT on December 31, 2012):

a. With regards to outstanding commons stock options, since the December 31, 2012 market price was less than the option exercise price, no shares of the company's commons stock would be required to be issued as noted in the following table:

Number of options		Exercise price		Market price		# of shares
	1,000,000	$	2.10	$	0.07		—
	275,000	$	0.50	$	0.07		—
	350,000	$	0.16	$	0.07		—

If the common stock to be delivered to him upon the triggering event have not been registered with the Securities and Exchange Commission so as to permit immediate resale, he shall instead receive an immediate cash payment equal to the market value of all vested stock options as noted in the following table:

Number of options		Exercise price		Market price		Market value of options
	1,000,000	$	2.10	$	0.07	$	—
	275,000	$	0.50	$	0.07	$	—
	350,000	$	0.16	$	0.07	$	—

b. A cash payment equal to four times his 2012 salary of $440,208 and the aggregate amount of his bonuses of $0 for the last four fiscal years, for a total of $1,760,832, which is payable immediately.

c. And an additional cash payment representing employment benefits equal to 20% of the amount calculated in paragraph (b) or $352,166, which is payable immediately.

We provide the foregoing post-employment payments in the event of termination and/or a change in control in order to attract and retain an appropriate caliber of talent for the position. We believe that our severance and change in control provisions are consistent with the provisions and benefit levels of other companies disclosing such provisions as reported in public SEC filings.

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The termination provisions of Mr. Doshi's employment contract were designed, in part, to impede and discourage a hostile takeover attempt and to protect the continuity of management. The termination provisions, including appropriate payment and benefit levels and the various circumstances that trigger payments or provision of benefits, were determined through negotiations between Mr. Doshi, our directors and representatives of Dundee Securities Corporation, the lead underwriter in connection with a sale of common shares we completed on March 30, 2006.

Mr. Dvoracek’s employment contract provides that in the event of a change of control, if he is not retained, he is entitled to receive a severance payment equal to nine months salary.

Compensation of Directors

Director Compensation Table

The table below summarizes the compensation received by our non-employee directors for the year ended December 31, 2012.

		Fees Earned or
		Paid in Cash				Option Awards		Total
Name	Period	($)				($)		($)
Christopher Czuppon	2012	$	10,500	(1)	(	$	—	$	10,500
Thomas Cunningham	2012	$	10,500	(1)		$	—	$	10,500
David Anderson	2012	$	10,500	(1)		$	—	$	10,500
Nick DeMare	2012	$	—			$	—	$	—

(1) Each director received a stock grant of 75,000 shares, valued at $0.14 per share.

Summary of Director Compensation

We have not provided cash compensation to our directors for their services as members of the Board or for attendance at Board or audit committee meetings. However, our directors are reimbursed for reasonable travel and other expenses incurred in connection with attending meetings of the Board and its committees as well as the annual meeting of shareholders.  Under our Stock Option Plan, directors are eligible to receive stock option grants at the discretion of the Board of Directors.

Compensation Committee Interlocks and Insider Participation

We do not presently have a Compensation Committee. The Board of Directors believes that it is in the best interest of the Company to permit all independent directors to fully participate in the compensation decisions for our executive officers. In accordance with the rules of the NYSE MKT, the compensation of our executive officers is determined, or recommended to the Board of Directors for determination, by a majority of independent directors. The independent directors consider the input of Stuart Doshi, our President and Chief Executive Officer, in making their recommendations for our other executive officers. The independent directors do not engage compensation consultants in formulating compensation decisions.

The table below sets forth those executive officers and directors who, during the last completed fiscal year, participated in deliberations of the registrant’s board of directors concerning executive officer compensation.

Name	Position with GeoPetro
Stuart J. Doshi	Director, Chairman, President and Chief Executive Officer
Thomas D. Cunningham	Director
David G. Anderson	Director
Christopher T. Czuppon	Director

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Compensation Committee Report

The independent directors of the Board of Directors have reviewed and discussed the Compensation Discussion and Analysis appearing under "Executive Compensation and Related Information" included herein with management and, based on such review and discussions, the independent directors have recommended to the board of directors that the Compensation Discussion and Analysis be included in the Company's annual report on Form 10-K for the year ended December 31, 2012.

Respectfully submitted,

David G. Anderson

Thomas D. Cunningham

Christopher T. Czuppon

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

 Equity Compensation Plan Information

The following table summarizes all equity compensation plans including those approved by shareholders and those not approved by shareholders, as of December 31, 2012.

Plan Category (1)	(a) Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants or Rights		(b) Weighted-average Exercise Price of Outstanding Options, Warrants and Rights		(c) Number of Securities Remaining Availablefor Future IssuanceUnder EquityCompensation Plans(excluding securities reflected in column(a))
Equity compensation plans approved by shareholders		3,445,000	$	1.21		1,555,000
Equity compensation plans not approved by shareholders		—	$	—		—
		3,445,000	$	1.21		1,555,000

(1) In 2004, we implemented a new 2004 Stock Option and Appreciation Rights Plan (the "Stock Option Plan") providing for awards of incentive stock options, non-qualified stock options and stock appreciation rights. The Stock Option Plan replaced the Stock Incentive Plan as to new award grants effective in 2004 or thereafter to our directors, officers, employees and consultants. Amounts in the table do not include common stock warrants outstanding as of December 31, 2012, whereby investors may purchase up to an aggregate of 5,983,265 shares of our Common Stock, with a weighted average exercise price of $0.78. For additional details regarding warrants issued by the Company, see Note 9 Common Stock Warrants of the footnotes to the financial statements contained herein in our Annual Report on Form 10-K for the year ended December 31, 2012.

Security Ownership of Certain Beneficial Owners and Management

The following table sets forth information regarding beneficial ownership of our voting stock as of April 1, 2013 by: (i) each person who is known by us to beneficially own more than 5% of any class of our voting stock; (ii) each of our named executive officers listed in the Summary Compensation Table, directors and director nominees; and (iii) all of our executive officers and directors as a group.

For purposes of the following table, a person is deemed to be the beneficial owner of securities that can be acquired by that person within 60 days from April 1, 2013 upon the exercise of warrants or options or the conversion of preferred stock. Each beneficial owner's percentage is determined by assuming that options, warrants and convertible preferred stock that are held by that person regardless of price, but not those held by any other person, which are exercisable or convertible within 60 days from April 1, 2013 have been exercised or converted.

The information in the following table is based upon information supplied by officers, directors and principal shareholders. Except as otherwise noted below, and subject to applicable community property laws, the persons named have sole voting and investment power with respect to all shares of common stock shown as beneficially owned by them. Unless otherwise indicated, the address of the following shareholders is c/o GeoPetro Resources Company, 150 California Street, Suite 600, San Francisco, CA 94111.

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	Common Stock					Amount and Nature of Beneficial Ownership Series B Preferred Stock					Total
			% of					% of			Voting
Name of Beneficial Owner	Shares		Class (1)			Shares		Class			Power
Stuart J. Doshi, President, Chief Executive Officer and Chairman (2)		4,514,598		9.1	%		—		*			8.2	%
David V. Creel, Vice President of Exploration and Director (3)		477,272		1.0	%		—		*			*
Paul Maniscalco, Former Interim Chief Financial Officer		—		*			—		*			*
Dale W. Dvoracek, Vice President of Finance (4)		5,000		*			—		*			*
David G. Anderson, Director (5)		497,700		1.0	%		—		*			*
Thomas D. Cunningham, Director (6)		487,420		1.0	%		—		*			*
Christopher T. Czuppon, Director (7)		105,000		*			—		*			*
All executive officers, key persons and directors as a group (7 persons)		6,086,990		12.1	%		—		*			10.9	%
Certain Beneficial Owners
James A. Heller (8) 1160 Park Avenue New York, NY 10128		339,000		*			866,669		16.1	%		2.2	%
Susan K. Heller (9) 1160 Park Avenue New York, NY 10128		387,500		*			1,400,002		26.1	%		3.3	%
Encompass Fund (10) 1700 California Street, Suite 335 San Francisco, CA 94109		3,622,019		7.3	%		—		*			6.6	%
AK Capital LLC (11) 220 Montgomery St # 810 San Francisco, CA 94104		*		*			325,000		6.1	%		*

* Less than 1.0%

(1)     For the purposes of calculating the percent of class beneficially owned by a holder, shares of common stock which may be issued to that holder within 60 days of April 1, 2013 are deemed to be outstanding.

(2)     Includes direct ownership of 3,294,598 common shares and stock options to purchase 1,220,000 common shares that are exercisable within 60 days April 1, 2013.

(3)     Includes direct ownership of 267,272 common shares and stock options to purchase 210,000 common shares that are exercisable within 60 days of April 1, 2013.

(4)     Includes direct ownership of 0 common shares and stock options to purchase 5,000 common shares that are exercisable within 60 days of April 1, 2013. 

(5)     Includes direct ownership of 442,700 common shares and stock options to purchase 55,000 common shares that are exercisable within 60 days of April 1, 2013.

(6)     Includes direct ownership of 332,420 common shares and stock options to purchase 155,000 common shares that are exercisable within 60 days of April 1, 2013.

(7)     Includes direct ownership of 75,000 common shares and stock options to purchase 30,000 common shares that are exercisable within 60 days of April 1, 2013.

(8)     Includes direct and indirect ownership of 225,000 common shares and warrants to purchase 114,000 common shares that are exercisable within 60 days of April 1, 2013, and 866,669 Series B preferred shares that are convertible into common shares within 60 days of April 1, 2013.

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(9) Includes direct and indirect ownership of 225,000 common shares and warrants to purchase 162,500 common shares that are exercisable within 60 days of April 1, 2013, and 1,400,002 Series B preferred shares that are convertible into common shares within 60 days of April 1, 2013.

(10) Includes direct ownership of 2,378,046 common shares and warrants to purchase 1,243,973 common shares that are exercisable within 60 days of April 1, 2013.

(11) Includes direct ownership of 325,000 Series B preferred shares that are convertible into common shares within 60 days of April 1, 2013.

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

Certain Relationships and Related Party Transactions

On January 23, 2007, our Board of Directors adopted a written Amended and Restated Audit Committee charter which provides that the Audit Committee shall review all related-party transactions and potential conflict of interest situations involving amounts in excess of $120,000 on an ongoing basis. Related party transactions include transactions between GeoPetro and:

· Any of our directors or executive officers;

· Any nominee for election as a director;

· Any security holder who is known to us to own of record or beneficially more than five percent of any class of our voting securities; and

· Any member of the immediate family of any of the foregoing persons.

The Audit Committee shall determine whether the terms of proposed related party transactions are at least as favorable to us as could be obtained through arm's length negotiations with unaffiliated third parties. In making such determinations, the Audit Committee shall consider, where practicable, some or all of the following factors:

· Competitive bids;

· Industry or market comparables;

· Informal comparisons to similar transactions of other publicly and privately held companies similar to ours; and

· Similar transactions entered into by the Company through arm's length negotiations with unaffiliated third parties.

GeoPetro did not enter into any related party transactions during 2011 or 2012 except the following:

Eric Doshi, Stuart Doshi's son, was employed as our Director of Planning and Investor Relations, and Corporate Secretary. We paid Eric Doshi $85,240 and $145,000 during 2012 and 2011 respectively, for his services. In October 2003, Eric Doshi was granted 100,000 options, now fully vested, exercisable to purchase common stock at $2.10 per share until October 1, 2013.  In addition, Eric Doshi was granted 50,000 options exercisable to purchase common stock at $4.28 per share exercisable until June 26, 2013.  The 50,000 options were granted on June 27, 2008 and vest ratably over five years.  These options were repriced to $0.50 effective July 19, 2010, which was at or above the trading price of our common stock on that date.  Eric Doshi's salary and stock option compensation, based on industry comparables, was at least as favorable to us as could have been obtained through arm's length negotiations with unaffiliated third parties.

In February 2011, Stuart J. Doshi, President and CEO, made a loan to the Company in the amount of $125,000 in original principal amount.  The note accrued interest at 8% annually and was payable on demand.  This loan was approved by the audit committee and was repaid in September 2011.

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During 2012, Stuart J. Doshi, President and CEO, advanced to the Company twelve loans totaling $565,000. The notes bear interest at 10% per annum and are payable on demand. In connection with the notes, the Company issued 113,000 warrants to purchase our common stock. Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. These loans were approved by the audit committee.

Director Independence

David Anderson, Thomas Cunningham and Christopher Czuppon, current directors, are independent as defined by the rules of the NYSE MKT. Stuart Doshi and David Creel, current directors, are not independent as defined by the rules of the NYSE MKT. Our Board of Directors is currently comprised of a majority of independent directors. 

Item 14. Principal Accountant Fees and Services

Fees Paid to Burr Pilger Mayer, Inc.

Burr Pilger Mayer, Inc. has been engaged as the Company's independent registered public accounting firm beginning in January 2013 and has been selected by the Audit Committee to conduct the audit of our consolidated financial statements as of and for the year ended December 31, 2012.  The following table lists the aggregate fees and costs billed by Burr Pilger & Mayer Inc. to the Company for the years ended December 31, 2012 and 2011:

	2012		2011
Audit fees (1)	$	64,205	$	—
Audit related fees (2)		—		—
Tax fees (3)		—		—
All other fees		—		—
	$	64,205	$	—

(1) Audit fees consist of fees and expenses for professional services rendered in connection with the audit of our consolidated financial statements as of December 31, 2012 and December 31, 2011, quarterly reviews of our interim consolidated financial statements, and review of our registration statements.

(2) Audit related fees consist of fees and expenses related to professional services that are reasonably related to the performance of the auditor review of our consolidated financial statements and consist primarily of consultations concerning financial accounting and reporting standards.  We have not incurred any such fees during 2012 or 2011.

(3) Tax fees consist of fees and expenses related to the preparation of federal and state tax returns, tax advice and planning and related compliance matters.  We have not incurred any such fees during 2012 or 2011.

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Fees Paid to Hein & Associates LLP

Hein & Associates LLP was the Company's independent registered public accounting firm from 2002 until November 2012.  The following table lists the aggregate fees and costs billed by Hein & Associates LLP to the Company for the years ended December 31, 2012 and 2011:

	2012		2011
Audit fees (1)	$	51,579	$	114,635
Audit related fees (2)		—		—
Tax fees (3)		—		—
All other fees		—		—
	$	51,579	$	114,635

(1) Audit fees consist of fees and expenses for professional services rendered in connection with the audit of our consolidated financial statements as of December 31, 2012 and December 31, 2011, quarterly reviews of our interim consolidated financial statements, and review of our registration statements.

(2) Audit related fees consist of fees and expenses related to professional services that are reasonably related to the performance of the auditor review of our consolidated financial statements and consist primarily of consultations concerning financial accounting and reporting standards.  We have not incurred any such fees during 2012 or 2011.

(3) Tax fees consist of fees and expenses related to the preparation of federal and state tax returns, tax advice and planning and related compliance matters.  We have not incurred any such fees during 2012 or 2011.

Policy on Audit Committee Pre-Approval

The Audit Committee is responsible for pre-approving the engagement of our independent auditors for audit or permissible non-audit services.  Audit Committee pre-approval of specific audit and non-audit services is not required if the engagement for the services is entered into pursuant to general pre-approval policies and procedures established by the Committee regarding GeoPetro's engagement of the independent auditor, provided the policies and procedures are detailed as to the particular service, the Committee is informed of each service provided and such policies and procedures do not include delegation of the Committee's responsibilities under the Exchange Act to the Company's management.  The Committee may delegate to one or more designated members of the Committee the authority to grant pre-approvals, provided such approvals are presented to the Committee at a subsequent meeting.  Committee pre-approval of non-audit services (other than review and attest services) is not required if such services fall within available exceptions established by the U.S. Securities & Exchange Commission.  All of the services covered by the fees disclosed above were pre-approved by the Chairman of the Audit Committee.  These services and fees were then presented to the Committee.

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PART IV

Item 15. Exhibits and Financial Statement Schedules

The following documents are filed as part of this report

1.	Management’s Report on Internal Control Over Financial Reporting	F-2
	Report of Independent Registered Public Accounting Firm	F-3
	Report of Independent Registered Public Accounting Firm	F-4
	Consolidated Balance Sheets as of December 31, 2012 and 2011	F-5
	Consolidated Statements of Operations for the years ended December 31, 2012 and 2011	F-6
	Consolidated Statements of Shareholders’ Equity for the years ended December 31, 2012 and 2011	F-7
	Consolidated Statements of Cash Flows for the years ended December 31, 2012 and 2011	F-8
	Notes to Consolidated Financial Statements	F-9
2.	All other schedules are omitted because they are not applicable, not required or the required information is included in the consolidated financial statements or related notes.
3.	A list of exhibits filed or furnished with this report on Form 10-K (or-incorporated by reference to exhibits previously filed or furnished by GeoPetro) is provided in the Exhibit Index immediately following the financial statements in this report.

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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, on April 16, 2013.

GEOPETRO RESOURCES COMPANY
By:	/s/ Stuart J. Doshi
	Stuart J. Doshi
	Chairman of the Board of Directors, President and  Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on April 16, 2013.

Signature	Title	Date
/s/ Stuart J. Doshi	Chairman of the Board, President	April 16, 2013
Stuart J. Doshi	and Chief Executive Officer
/s/ David V. Creel	Vice-President of Exploration and	April 16, 2013
David V. Creel	Director
/s/ Dale W. Dvoracek	Vice-President of Finance	April 16, 2013
Dale W. Dvoracek
/s/ Christopher T. Czuppon	Director	April 16, 2013
Christopher T. Czuppon
/s/ Thomas D. Cunningham	Director	April 16, 2013
Thomas D. Cunningham
/s/ David G. Anderson	Director	April 16, 2013
David G. Anderson

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GLOSSARY OF OIL AND NATURAL GAS TERMS

In this report, unless the context otherwise requires, the following terms shall have the indicated meanings. A reference to an agreement means the agreement as it may be amended, supplemented or restated from time to time.

“1933 Act” means the United States Securities Act of 1933, as amended.

“Acquisition of Properties” - Costs incurred to purchase, lease or otherwise acquire a property.

“Analogous Reservoir” - Analogous reservoirs, as used in resources assessments, have similar rock and fluid properties, reservoir conditions (depth, temperature, and pressure) and drive mechanisms, but are typically at a more advanced stage of development than the reservoir of interest and thus may provide concepts to assist in the interpretation of more limited data and estimation of recovery.

“Bengara Block” means the contract area in the Indonesian province of East Kalimantan designated as the Bengara (II) PSC Block.

“Bengara II PSC” means the PSC dated December 4, 1997 between C-G Bengara and Pertamina.

“Bitumen” — Bitumen, sometimes referred to as natural bitumen, is petroleum in a solid or semi-solid state in natural deposits with a viscosity greater than 10,000 centipoise measured at original temperature in the deposit and atmospheric pressure, on a gas free basis. In its natural state it usually contains sulfur, metals, and other non-hydrocarbons.

“BP Migas” means Badan Pelaksana Minyak Dan Gas Muni, a new executive board established by the government of Indonesia in 2002 for oil and gas upstream operations and an implementing body created to assume the role of Pertamina’s regulatory functions and responsibilities in managing oil and gas contractors.

“CBM” means coal bed methane, which is methane found in coal seams. It is produced by non-traditional means, and therefore, while it is sold and used the same as traditional natural gas, its production is different. CBM is generated either from a biological process as a result of microbial action or from a thermal process as a result of increasing heat with depth of the coal. Often a coal seam is saturated with water, with methane held in the coal by water pressure.

“C-G Bengara” means Continental-GeoPetro (Bengara II) Ltd., a British Virgin Islands corporation owned 12% by GeoPetro.

“CG Xploration” means CG Xploration Inc., a Delaware corporation owned 50% by GeoPetro.

“CNPC” means CNPCHK (Indonesia) Limited. CNPC is a wholly owned subsidiary of CNPC (Hong Kong) Limited, a publicly held company based in Hong Kong where its shares trade on the Hong Kong Stock Exchange under the listing number 0135.HK.

“Company” means GeoPetro Resources Company, a California corporation, and its wholly-owned subsidiaries.

“Condensate” — Condensate is a mixture of hydrocarbons that exists in the gaseous phase at original reservoir temperature and pressure, but that, when produced, is in the liquid phase at surface pressure and temperature.

“Continental” means Continental Energy Corporation.

“Developed Oil and Gas Reserves” — Developed oil and gas reserves are reserves of any category that can be expected to be recovered: a) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and b) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

“Development Costs” — Costs incurred to obtain access to proved reserves and to provide facilities for extracting, treating, gathering and storing the oil and gas.

“Development Project” — A development project is the means by which petroleum resources are brought to the status of economically producible.

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“Development Well” — A well drilled within the proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive.

“Earning Obligation” means $18.7 million paid by CNPC into a special joint venture account at a Hong Kong international bank, which funds are under joint signature control of CNPC, Continental and GeoPetro, and has been expended to pay for 2007 exploration drilling in the Bengara II PSC area.

“Economically Producible” — The term economically producible, as it relates to a resource, means a resource which generates revenue that exceeds, or is reasonably expected to exceed, the costs of the operation.

“EIA” means the United States Energy Information Administration.

“Estimated Ultimate Recovery” — (EUR) Estimated ultimate recovery is the sum of reserves remaining as of a given date and cumulative production as of that date.

“Exploration Costs” — Costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects of containing oil and gas reserves, including costs of drilling exploratory wells and exploratory-type stratigraphic test wells. Exploration costs may be incurred both before acquiring the related property (sometimes referred to in part as prospecting costs) and after acquiring the property.

“Exploratory Well” — An exploratory well is a well drilled to find a new field or to find a new reservoir in a field previously found to be productive of oil or gas in another reservoir.

“Extension Well” — An extension well is a well drilled to extend the limits of a known reservoir.

“Fannin Well” means the Angela Farris Fannin No. 1 well located in the Madisonville Field.

“Farm-out” means an agreement whereby a third party agrees to pay for the drilling of a well on one or more of GeoPetro’s properties in order to earn an interest therein with GeoPetro retaining a residual interest in such properties.

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

“Gateway” means Gateway-Madisonville Pipeline, LLC, a company that has constructed pipeline facilities at the Madisonville Field.

“GeoPetro” means GeoPetro Resources Company, a California corporation, and its wholly-owned subsidiaries.

“GeoPetro Alaska” means GeoPetro Alaska LLC, an Alaska limited liability company, which is a wholly-owned subsidiary of GeoPetro.

“GeoPetro Canada” means GeoPetro Canada Ltd., an Alberta corporation, which is a wholly-owned subsidiary of GeoPetro.

“GeoPetro Pacific” means GeoPetro Pacific LLC, a Delaware limited liability company, which is a wholly-owned subsidiary of GeoPetro.

“Hanover” means Hanover Compression Limited Partnership, a limited partnership that constructed and previously operated treatment facilities at the Madisonville Field.

“LPG” means liquefied petroleum gas.

“Madisonville Field” means the Madisonville (Rodessa) field in Madison County, Texas.

“Madisonville Midstream” means Madisonville Midstream LLC, a Texas limited liability company, which is a wholly-owned subsidiary of Redwood Energy Company, and which is 100% owned, directly or indirectly, by GeoPetro.

“Madisonville Project” means the oil and natural gas exploration, development and production project at the Madisonville Field.

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“Magness Well” means the UMC Ruby Magness No. 1 well located in the Madisonville Field.

“Makapan Gas Field” means the Makapan gas field in East Kalimantan, Indonesia.

“MGP” means Madisonville Gas Processing, LP, a limited partnership that purchased and operated the treatment facilities at the Madisonville Field, prior to the acquisition of the facilities by GeoPetro.

“Mitchell Well” means the Mitchell No. 1 well located in the Madisonville Field.

“Oil and Gas Producing Activities” — Oil and gas producing activities include: a) The search for crude oil, including condensate and natural gas liquids, or natural gas (“oil and gas”) in their natural states and original locations; b) The acquisition of property rights or properties for the purpose of further exploration or for the purpose of removing the oil or gas from such properties; c) The construction, drilling, and production activities necessary to retrieve oil and gas from their natural reservoirs, including the acquisition, construction, installation, and maintenance of field gathering and storage systems, such as: i) Lifting the oil and gas to the surface; and ii) Gathering, treating, and field processing (as in the case of processing gas to extract liquid hydrocarbons); and d) Extraction of saleable hydrocarbons, in the solid, liquid, or gaseous state, from oil sands, shale, coalbeds, or other nonrenewable natural resources which are intended to be upgraded into synthetic oil or gas, and activities undertaken with a view to such extraction.  Oil and gas producing activities do NOT include: a) Transporting, refining, or marketing oil and gas; b) Processing of produced oil, gas or natural resources that can be upgraded into synthetic oil or gas by a registrant that does not have the legal right to produce or a revenue interest in such production; c) Activities relating to the production of natural resources other than oil, gas, or natural resources from which synthetic oil and gas can be extracted; or d) Production of geothermal steam.

“Pertamina” means Perusahaan Pertambangan Minyak Dan Gas Bumi Negara, the previous Indonesian state-owned oil and natural gas company established in 1971 which had exclusive authority to explore, drill for, and produce oil and natural gas minerals in Indonesia. In accordance with the new Indonesian Oil and Gas Law, its corporate form has been changed to become a state-owned limited liability company established under Indonesian Company Law, and all rights and obligations of Pertamina under existing PSCs shall pass to BP Migas.

“Possible Reserves” — Possible reserves are those additional reserves that are less certain to be recovered than probable reserves.

“Probable Reserves” — Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.

“Production Costs” — Costs incurred to operate and maintain wells and related equipment and facilities, including depreciation and applicable operating costs of support equipment and facilities and other costs of operating and maintaining those wells and related equipment and facilities.

“Proved Area”— The part of a property to which proved reserves have been specifically attributed.

“Proved Developed Nonproducing Reserves” means reserves expected to be recovered from zones behind casing in existing wells.

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

“Proved Oil and Gas Reserves”— Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible - from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations - prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

“Proved Properties” — Properties with proved reserves.

68

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

“PSC” means a production sharing contract, being a contract with Pertamina whereby Pertamina contracts with a petroleum company to explore for, develop and extract petroleum substances from a particular license area, on Pertamina’s behalf, at the risk and expense of the petroleum company, in exchange for a share of the production.

“Redwood” means Redwood Energy Company, a Texas corporation, which is a wholly-owned subsidiary of GeoPetro and which is the general partner of, and holds a 5% interest in, Redwood LP.

“Redwood LP” means Redwood Energy Production, L.P., a Texas limited partnership, the sole limited partner of which is GeoPetro and which is 100% owned, directly or indirectly, by GeoPetro.

“Reliable Technology” — Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation.

“Reserves”— Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

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

“Resources” — Resources are quantities of oil and gas estimated to exist in naturally occurring accumulations. A portion of the resources may be estimated to be recoverable, and another portion may be considered to be unrecoverable. Resources include both discovered and undiscovered accumulations.

“Rodessa Formation” means the geological formation at the Madisonville Field existing at a depth of approximately 12,000 feet.

“Seismic” means data collected that uses reflected seismic waves to produce images of the Earth’s subsurface. The method requires a controlled seismic source of energy, such as dynamite or a specialized air gun. By noting the time it takes for a reflection to arrive at a receiver, it is possible to estimate the depth of the feature that generated the reflection.

“Service Well” — A well drilled or completed for the purpose of supporting production in an existing field.

“South Texas GeoPetro” means South Texas GeoPetro, LLC., a Texas limited liability company, which is a wholly-owned subsidiary of GeoPetro.

“Stratigraphic Test Well” — A stratigraphic test well is a drilling effort, geologically directed, to obtain information pertaining to a specific geologic condition. Such wells customarily are drilled without the intent of being completed for hydrocarbon production.

“Tertiary Sandstones” means sandstones which were deposited during a geologic time period ranging from 2 to 63 million years ago.

“Undeveloped Oil and Gas Reserves” — Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

“Unproved Properties” — Properties with no proved reserves.

69

“U.S. GAAP” means the accounting principles generally accepted in the United States.

“Wilson Well” means the Wilson No. 1 well located in the Madisonville Field.

“Working interest” means the percentage of undivided interest held by a party in the oil and/or natural gas or mineral lease granted by the mineral owner, which interest gives the holder the right to “work” the property (lease) to explore for, develop, produce and market the leased substances.

ABBREVIATIONS AND CONVERSIONS

In this report, the following abbreviations have the meanings set forth below:

API	American Petroleum Institute
bbl and bbls	barrel and barrels, each barrel representing 34.972 Imperial gallons or 42 U.S. gallons
bbls/d	barrels per day
Bcf	billion cubic feet
boe	barrels of oil equivalent converting 6 mcf of natural gas to one barrel of oil equivalent and one barrel of natural gas liquids to one barrel of oil equivalent. Measures of boes may be misleading, particularly if used in isolation. This conversion ratio is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead, but is a commonly used industry benchmark.
boe/d	barrels of oil equivalent per day
degree API	an indication of the specific gravity of crude oil measured on the API gravity scale. Liquid petroleum with a specified gravity of 28 degree API or higher is generally referred to as light crude oil.
LPG	liquefied petroleum gas
mbbls	one thousand barrels
mboe	one thousand barrels of oil equivalent
Mcf	one thousand cubic feet
Mcf/d	one thousand cubic feet per day
mmbbls	one million barrels
MMBtu	one million British Thermal Units
MMcf	one million cubic feet
MMcf/d	one million cubic feet per day
NGLs	natural gas liquids
psig	pounds per square inch gauge
Tcf	trillion cubic feet

70

GEOPETRO RESOURCES COMPANY

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

	Page
CONSOLIDATED FINANCIAL STATEMENTS FOR THE FISCAL YEARS ENDED DECEMBER 31, 2012 AND 2011
Management’s Report on Internal Control Over Financial Reporting	F-2
Report of Independent Registered Public Accounting Firm	F-3
Report of Independent Registered Public Accounting Firm	F-4
Consolidated Balance Sheets as of December 31, 2012 and 2011	F-5
Consolidated Statements of Operations for the years ended December 31, 2012 and 2011	F-6
Consolidated Statements of Shareholders’ Equity for the years ended December 31, 2012 and 2011	F-7
Consolidated Statements of Cash Flows for the years ended December 31, 2012 and 2011	F-8
Notes to Consolidated Financial Statements	F-9
Exhibit Index

F-1

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934). Our internal control over financial reporting is designed to provide reasonable assurance to management and our board of directors regarding the preparation and fair presentation of published financial statements. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Management assessed the effectiveness of our internal control over financial reporting as of December 31, 2012.  In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in  Internal Control - Integrated Framework.  Based on our assessment, we believe that as of December 31, 2012, our internal control over financial reporting was effective based on those criteria. This annual report does not include an attestation report of the Company’s registered public accounting firm regarding internal control over financial reporting.  Management’s report was not subject to attestation by the Company’s registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit the Company to provide only management’s report in this annual report.

By:	/s/ Stuart J. Doshi	By:	/s/ Dale W. Dvoracek
	Stuart J. Doshi		Dale W. Dvoracek
	President, Chief Executive Officer and Chairman		Vice-President of Finance

F-2

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

GeoPetro Resources Company

We have audited the accompanying consolidated balance sheet of GeoPetro Resources Company and its subsidiaries (the “Company”) as of December 31, 2012, and the related consolidated statements of operations, shareholders’ equity, and cash flows for the year then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor have we been engaged to perform, an audit of the Company’s internal control over financial reporting. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit 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 audit provides a reasonable basis for our opinion.

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

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern.  As discussed in Note 2 to the consolidated financial statements, the Company has incurred recurring net losses that have resulted in an accumulated deficit of $49.7 million as of December 31, 2012.  Also, the Company has limited cash and working capital to fund its future operations.  These factors raise substantial doubt about the ability of the Company to continue as a going concern.  Management’s plans regarding those matters are also described in Note 2.  The consolidated financial statements do not include any adjustments that might result from the outcome of these uncertainties.

/s/ Burr Pilger Mayer, Inc.

San Francisco, California

April 16, 2013

F-3

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

GeoPetro Resources Company

We have audited the consolidated balance sheet of GeoPetro Resources Company and subsidiaries (collectively, the “Company”) as of December 31, 2011, and the related consolidated statements of operations, changes in shareholders’ equity and cash flows for the year then ended.  These financial statements are the responsibility of the Company’s management.  Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.  The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting.  Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting.  Accordingly, we express no such opinion.  An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.  We believe that our audit provides a reasonable basis for our opinion.

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

/s/ Hein & Associates LLP

Dallas, Texas

March 30, 2012

F-4

GEOPETRO RESOURCES COMPANY

CONSOLIDATED BALANCE SHEETS

	December 31,
	2012			2011
ASSETS
Current Assets
Cash and cash equivalents	$	59,432		$	916,741
Trade accounts receivable—oil and gas sales		—			165,160
Accounts receivable—other		5,460			5,560
Prepaid expenses		65,266			88,931
Total current assets		130,158			1,176,392
Oil and gas properties, at cost (full cost method)
Unproved properties		6,524,819			6,931,499
Proved properties		53,090,943			52,977,232
Gas processing plant		5,533,910			5,533,910
Less—accumulated depletion, depreciation and impairment		(41,625,269	)		(40,823,082	)
Net oil and gas properties		23,524,403			24,619,559
Furniture, fixtures and equipment, at cost, net of depreciation		28,709			42,288
Other assets		36,733			44,600
Total Assets	$	23,720,003		$	25,882,839
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities
Trade payables	$	1,346,510		$	969,617
Current portion of long term notes payable		944,950			1,197,385
Notes payable – related party		565,000			—
Interest payable		137,921			16,570
Dividends payable		873,791			548,411
Other taxes payable		134,704			164,796
Royalty owners payable		327,850			338,713
Total current liabilities		4,330,726			3,235,492
Long Term Notes Payable		1,644,427			1,423,707
Asset Retirement Obligations		75,000			75,000
Other Long Term Liabilities		66,548			75,750
Total Liabilities		6,116,701			4,809,949
Commitments and Contingencies (Notes 2 and 10)		—			—
Shareholders’ Equity
Series B preferred stock, no par value; 7,523,000 shares authorized; 5,423,000 shares issued and outstanding. Aggregate liquidation preference of $4,067,250.		3,873,602			3,873,602
Common stock, no par value; 100,000,000 shares authorized; 46,578,101 and 44,253,101 shares issued and outstanding at December 31, 2012 and December 31, 2011, respectively.		59,117,079			58,725,579
Additional paid-in-capital		4,342,234			3,942,640
Accumulated deficit		(49,729,613	)		(45,468,931	)
Total shareholders’ equity		17,603,302			21,072,890
Total Liabilities and Shareholders’ Equity	$	23,720,003		$	25,882,839

See accompanying notes to these consolidated financial statements.

F-5

GEOPETRO RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS

	For the Years Ended December 31,
	2012			2011
Revenues
Natural gas sales	$	351,082		$	976,571
Costs and Expenses
Plant operating		1,036,549			2,280,453
Lease operating		191,615			205,421
General and administrative		1,963,053			2,202,071
Depreciation and depletion		195,110			449,537
Impairment of oil and gas properties		620,656			750,133
Total costs and expenses		4,006,983			5,887,715
Loss from operations		(3,655,901	)		(4,911,144	)
Other Income (Expense)
Other income		25,705			3,771
Interest income		178			675
Interest expense		(295,620	)		(634,576	)
Gain on sale of equipment		—			4,069,640
Total other income (expense)		(269,737	)		3,439,510
Loss Before Taxes		(3,925,638	)		(1,471,634	)
Income tax expense		(9,664	)		(800	)
Net Loss		(3,935,302	)		(1,472,434	)
Preferred stock dividend		(325,380	)		(434,639	)
Net Loss Available to Common Shareholders	$	(4,260,682	)	$	(1,907,073	)
Net Loss Per Common Shares Basic and Diluted	$	(0.09	)	$	(0.05	)
Weighted average number of common shares outstanding basic and diluted		45,129,877			41,754,777

See accompanying notes to these consolidated financial statements.

F-6

GEOPETRO RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

FOR THE YEARS ENDED DECEMBER 31, 2012 AND 2011

	Preferred Stock Series B						Common Stock				Additional Paid-in		Accumulated			Total Shareholders’
	Shares			Amount			Shares		Amount		Capital		Deficit			Equity
Balances, January 1, 2011		7,523,000		$	5,448,602			39,090,845	$	55,671,371	$	3,522,167	$	(43,561,858	)	$	21,080,282
Issuance of common stock for cash, net		—			—			3,062,256		1,479,208		—		—			1,479,208
Conversion of preferred stock to common stock		(2,100,000	)		(1,575,000	)		2,100,000		1,575,000		—		—			—
Share-based compensation		—			—			—		—		407,311		—			407,311
Fair value of warrants issued in connection with notes payable		—			—			—		—		13,162		—			13,162
Net loss		—			—			—		—		—		(1,472,434	)		(1,472,434	)
Dividends on Series B preferred stock		—			—			—		—		—		(434,639	)		(434,639	)
Balances, December 31, 2011		5,423,000			3,873,602			44,253,101		58,725,579		3,942,640		(45,468,931	)		21,072,890
Issuance of common stock for cash, net		—			—			2,100,000		360,000		—		—			360,000
Share-based compensation		—			—			225,000		31,500		391,499		—			422,999
Fair value of warrants issued in connection with notes payable		—			—			—		—		8,095		—			8,095
Net Loss		—			—			—		—		—		(3,935,302	)		(3,935,302	)
Dividends on Series B preferred stock		—			—			—		—		—		(325,380	)		(325,380	)
Balances, December 31, 2012		5,423,000		$	3,873,602			46,578,101	$	59,117,079	$	4,342,234	$	(49,729,613	)	$	17,603,302

See accompanying notes to these consolidated financial statements.

F-7

GEOPETRO RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2012			2011
Cash Flows From Operating Activities
Net loss	$	(3,935,302	)	$	(1,472,434	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and depletion		195,110			449,537
Share-based compensation expense		422,999			407,311
Non-cash interest expense		51,380			140,251
Accretion of discount on asset retirement obligations		—			3,490
Impairment of oil and gas properties		620,656			750,133
Gain on sale of equipment		—			(4,069,640	)
Changes in operating assets and liabilities:
Accounts receivable		165,160			(39,567	)
Other assets		31,632			1,266
Current liabilities		457,289			(574,492	)
Other		(9,202	)		815
Net cash used in operating activities		(2,000,278	)		(4,403,330	)
Cash Flows from Investing Activities
Additions to oil and gas properties		(230,817	)		(1,382,153	)
Dispositions of oil and gas properties		523,786			—
Proceeds from sale of equipment		—			9,250,000
Net cash provided by investing activities		292,969			7,867,847
Cash Flows from Financing Activities
Proceeds from issuance of common shares		360,000			1,479,208
Proceeds from promissory notes		—			1,000,000
Repayments of promissory notes		(75,000	)		(5,947,847	)
Proceeds from related party notes		565,000			125,000
Repayments of related party notes		—			(125,000	)
Payments of loan fee		—			(27,000	)
Net cash provided by (used in) financing activities		850,000			(3,495,639	)
Net Decrease in Cash and Cash Equivalents:		(857,309	)		(31,122	)
Cash and Cash Equivalents
Beginning of period		916,741			947,863
End of period	$	59,432		$	916,741
Supplemental Disclosure of Cash Flow Information
Cash paid for interest	$	122,889		$	664,761
Cash paid for income taxes	$	1,600		$	800
Non-Cash Transactions
Issuance of warrants in connection with promissory notes and private placements	$	77,932		$	403,749
Accrual of dividends on preferred stock	$	325,380		$	434,639

See accompanying notes to these consolidated financial statements.

F-8

GEOPETRO RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Information subsequent to December 31, 2012 is unaudited)

1.         ORGANIZATION AND BASIS OF PRESENTATION

GeoPetro Resources Company (“we,” “us,” “our,” “GeoPetro” or the “Company”) was originally incorporated as GeoPetro Company under the laws of the State of Wyoming in 1994 to participate in the oil and gas acquisition, exploration, development and production business in the United States and internationally. GeoPetro Company was subsequently merged into GeoPetro Resources Subsidiary Company, a California corporation, on June 28, 1996. GeoPetro’s name was then changed to GeoPetro Resources Company. GeoPetro’s corporate offices are in San Francisco, California. The accompanying consolidated financial statements include the accounts of GeoPetro and its wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.

2.         LIQUIDITY

As of December 31, 2012, GeoPetro had a working capital deficit of $4,200,568 and an accumulated deficit of $49,729,613.  Further, GeoPetro generated net losses attributable to common sharesholders of $4,260,682 and $1,907,073 during the years ended December 31, 2012 and 2011 respectively.  GeoPetro’s ability to meet its contractual obligations and remit payment under its arrangements with its vendors depends on its ability to generate additional financing.  GeoPetro’s management continues to renegotiate the terms of its existing borrowing arrangements and raise additional capital through debt and equity issuances. These conditions raise substantial doubt about the Company's ability to continue as a going concern. These consolidated financial statements do not include any adjustment that might be necessary if the Company is unable to continue as a going concern.

Since its inception, GeoPetro has participated as a working interest owner in the acquisition of undeveloped leases, seismic options, lease options and foreign concessions and has participated in seismic surveys and the drilling of test wells on its undeveloped properties.  More recently, we acquired a natural gas treatment plant in East Texas.  Exploratory and development drilling is scheduled during 2013 and future periods on GeoPetro’s undeveloped properties and expansion is planned on the natural gas treatment plant.  The planned expansion at the natural gas treatment plant and the exploration activities together with others that may be entered into exceed the existing working capital of GeoPetro.  Management will need to raise additional equity and/or debt capital, to finance its continued activities.  Management believes that GeoPetro will be successful in obtaining adequate sources of cash to fund its anticipated capital expenditures and operating expense through the end of 2013, but there can be no assurance that management will be successful in raising sufficient additional equity and/or debt capital.  If additional financing is not available, GeoPetro will be compelled to reduce the scope of its business activities including, but not limited to, the following:

· Selling working interests and assets in its Madisonville operations to other parties;

· Farming-out its interest in proposed wells;

· Forfeiting its interest in wells that are proposed to be drilled and/or;

· Reducing general and administrative expenses;

As a result of the Company’s liquidity issues, it may be required to sell certain assets or raise capital with terms that may not be as favorable as might otherwise be available.

In April 2012, the Company's wholly-owned subsidiary, Redwood Energy Production, L.P., elected to temporarily shut-in its natural gas production at the Madisonville Field, Madison County, Texas in light of depressed natural gas prices.  The Company will monitor market conditions and bring its natural gas production back on stream as market conditions warrant. For the year ended December 31, 2012, 100% of the Company's revenue was derived from the natural gas production in the Madisonville Field.

As of December 31, 2012, Stuart J. Doshi, President and CEO, has advanced to the Company twelve loans totaling $565,000.  The notes bear interest at 10% per annum and are payable on demand (Note 5). 

On February 28, 2013, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”), with MCW Energy Group Limited, an Ontario corporation (“MCW”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“Merger Sub”). Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “Merger”) and the Company will survive the Merger and continue as a subsidiary of MCW. The Merger Agreement has been approved by Boards of Directors of each of the Company, MCW and Merger Sub.  The merger is subject to customary closing conditions, including regulatory and shareholder approval.

F-9

3.         SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

U.S. GAAP—The Company’s financial statements have been prepared in accordance with accounting principles generally accepted within the United States of America (“U.S. GAAP”).

Use of Estimates and Significant Estimates—Certain amounts in GeoPetro’s financial statements are based upon significant estimates, including oil and gas reserve quantities which form the basis for the calculation of depreciation, depletion, amortization and impairment of oil and gas properties, the carrying values of unproved properties, asset retirement obligations, accounting for business combinations and share-based payments, and a provision for income taxes. Actual results could materially differ from those estimates.

Oil and Gas Properties—GeoPetro follows the full cost method of accounting for oil and gas producing activities and, accordingly, capitalizes all costs incurred in the acquisition,  exploration, and development of proved oil and gas properties, including the costs of abandoned properties, dry holes, geophysical costs, and annual lease rentals. All general corporate costs are expensed as incurred. In general, sales or other dispositions of oil and gas properties are accounted for as adjustments to capitalized costs, with no gain or loss recorded. Costs incurred for repairs and maintenance are expensed as incurred. Amortization of proved oil and gas properties is computed on the units of production method based on all proved reserves on a country by country basis. Unproved oil and gas properties are assessed for impairment either individually or on an aggregate basis. The net capitalized costs of proved oil and gas properties (full cost ceiling limitation) are not to exceed their related estimated future net revenues discounted at 10%, and the lower of cost or estimated fair value of unproved properties, net of tax considerations.

Asset Impairment—Under full cost accounting, a ceiling test is performed to ensure that unamortized capitalized costs in each cost center (country) do not exceed their fair value.  Impairment is recognized when the carrying value is greater than the discounted future cash flows.  In the event of impairment, the amount by which the carrying value exceeds the estimated fair value of the long-lived asset is charged to earnings. The present value of estimated future net revenues is computed by applying average oil and gas prices to estimated future production of proved oil and gas reserves as of period-end, less estimated future expenditures to be incurred in developing and producing the proved reserves assuming the continuation of existing economic conditions. SEC rules require that reserve calculations be based on the un-weighted average first-day-of-the-month prices for the prior twelve months. There was no impairment of proved oil and gas properties indicated at either December 31, 2012 or December 31, 2011.

For the unproved properties, the Company evaluates the possibility of potential impairment on a quarterly basis.  During the twelve months ended December 31, 2012 approximately $587,040 of unproved property costs related to Indonesia exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Indonesia full cost pool as negotiations with the Indonesian government for an extension of the Bengara II Production Sharing Contract (“PSC”) have terminated. The PSC shall now be relinquished and allowed to expire in accordance with its terms. In addition, approximately $33,616 of unproved property costs related to Canada exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Canada full cost pool. During the twelve months ended December 31, 2011 approximately $750,133 of unproved property costs related to Indonesia exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Indonesia full cost pool, as the decision was made to terminate CG Xploration and wind down operations. 

Joint Ventures—Some exploration and production activities are conducted jointly with others and, accordingly, the accounts reflect only GeoPetro’s proportionate interest in such activities.

Revenue Recognition—Revenue is recognized upon delivery of gas production.

Asset Retirement Obligation—The fair value of an asset retirement cost, and corresponding liability, are recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. GeoPetro recorded an asset retirement obligation to reflect GeoPetro’s legal obligations related to future plugging and abandonment of its oil and gas wells. GeoPetro estimated the expected cash flow associated with the obligation and discounted the amount using a credit-adjusted, risk-free interest rate. At least annually, GeoPetro reassesses the obligation to determine whether a change in the estimated obligation is necessary. GeoPetro evaluates whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest the estimated obligation has materially changed, GeoPetro will accordingly update its assessment.

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There are asset retirement obligations associated with the Plant. However, components of the Plant can be used for extended and indeterminate periods of time as long as they are properly maintained and/or upgraded. GeoPetro’s intent is to maintain the Plant assets and continue making improvements to those assets based on technological advances. As a result, GeoPetro’s management believes that the Plant has an indeterminate life for purposes of estimating asset retirement obligations because dates or ranges of dates upon which GeoPetro would retire the Plant cannot reasonably be estimated.

	December 31,
	2012		2011
Asset retirement obligations, beginning of period	$	75,000	$	71,510
Liabilities incurred		—		698
Accretion expense		—		2,792
Asset retirement obligations, end of period	$	75,000	$	75,000

Furniture, Fixtures and Equipment—Furniture, fixtures and equipment are stated at cost. Depreciation is provided on furniture, fixtures and equipment using the straight-line method over an estimated service life of three to seven years.

Income Taxes—GeoPetro accounts for income taxes using the asset and liability method wherein deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. Because management has determined that realization of deferred tax assets is not more likely than not, the net deferred tax assets are fully reserved.

Concentrations of Credit Risk—Credit risk represents the accounting loss that would be recognized at the reporting date if counterparties failed completely to perform as contracted. Concentrations of credit risk (whether on or off balance sheet) that arise from financial instruments exist for groups of customers or counterparties when they have similar economic characteristics that would cause their ability to meet contractual obligations to be similarly affected by changes in economic or other conditions described below. The credit risk amounts for cash and accounts receivable do not take into account the value of any collateral or security.

GeoPetro maintains several cash accounts with higher quality financial institutions in amounts which occasionally exceed current federal deposit insurance limits. Senior management continuously reviews these institutions for financial stability. The Company has not experienced any losses in connection with amounts in excess of federal deposit limits.

During the years ended December 31, 2012 and 2011, substantially all of the Company’s natural gas production was sold to Luminant Energy Company, LLC.

At December 31, 2011, all of the Company’s trade accounts receivable — oil and gas sales were due from Luminant Energy Company, LLC.  There were no trade accounts receivable at December 31, 2012.

Trade Accounts Receivable and Allowance for Doubtful Accounts—Accounts receivable, oil and gas sales, consist of uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days.  No interest is charged on past-due balances.  Payments made on all accounts receivable are applied to the earliest unpaid items.  Trade accounts receivable are recorded at net realizable value. If the financial condition of GeoPetro’s customers were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required. Delinquent trade accounts receivable are charged against the allowance for doubtful accounts once uncollectibility has been determined. The allowance is determined through an analysis of the past-due status of accounts receivable and assessments of risk that are based on historical trends and an evaluation of the impact of current and projected economic conditions. There was no allowance for doubtful accounts needed as of December 31, 2012 or 2011.

Fair Value of Financial Instruments—The estimated fair values for financial instruments are determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. For certain of GeoPetro’s financial instruments, including cash, accounts receivable, accounts payable and current portion of notes payable, the carrying amounts approximate fair value due to their maturities.

F-11

Share-Based Payments—The Company has a stock-based compensation plan that allows employees to purchase common shares of the Company. Option exercise prices approximate the market price for the common shares on the date the options were issued. Options granted under the plan are generally fully exercisable after five years and expire five to ten years after the grant date. The Company measures and records stock-based awards to directors, employees and consultants based on the grant-date fair value, determined using the Black-Scholes option pricing model with assumptions for: risk free interest rates, expected dividend yield, expected life of the option, and the expected volatility. The compensation expense was recorded ratably over the requisite service period defined in the award.  The Company recorded $422,999 and $407,311 of stock-based employee compensation for the twelve months ended December 31, 2012 and 2011, respectively. (Note 8)

Net Loss perCommon Share—Basic net loss per common share is computed by dividing the net loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period.

Diluted net loss per common share is computed in the same manner, but also considers the effect of common stock shares underlying the following:

	Years Ended December 31,
	2012		2011
Stock options (Note 8)		3,445,000		2,770,000
Warrants (Note 9)		5,983,265		5,424,044
Convertible preferred stock, Series B		5,423,000		5,423,000

All of the common shares underlying the stock options and warrants above were excluded from diluted weighted average shares outstanding for each of the years in the period ended December 31, 2012 and 2011 because their effects were antidilutive.

Segment Reporting—GeoPetro has oil and gas exploration, development and production operations in the United States, Canada, Australia and Indonesia. All revenues and related costs are associated with operations in the United States. A summary of assets and capital expenditures by geographical segment is included in Note 4.

Cash and Cash Equivalents—Cash and cash equivalents include cash on hand, amounts held in banks and highly liquid investments purchased with an original maturity of three months or less.

Reclassification—Certain prior year amounts have been reclassified for consistency in reporting with current year amounts to avoid confusion.  Sublease income has been included as a reduction in general and administrative expenses in the accompanying statements of operations.

Recently Issued Accounting Pronouncements— The Company has evaluated recent accounting pronouncements and their adoption and we have not identified any that would have a material impact on the Company’s financial position, or statements.

4.         SUMMARY OF OIL AND GAS OPERATIONS

Capitalized costs at year end and costs incurred relating to GeoPetro’s oil and gas properties are summarized as follows:

Capitalized costs as of December 31, 2012 are as follows:

	United States			Australia			Indonesia			Canada			Totals
Proved properties	$	46,621,800		$	2,388,051		$	1,361,817		$	2,719,275		$	53,090,943
Unproved properties		4,635,781			1,522,718			—			366,320			6,524,819
Gas processing plant		5,533,910			—			—			—			5,533,910
Less—accumulated depletion and impairment		(35,156,126	)		(2,388,051	)		(1,361,817	)		(2,719,275	)		(41,625,269	)
Net capitalized costs	$	21,635,365		$	1,522,718		$	—		$	366,320		$	23,524,403

Costs incurred for the year ended December 31, 2012 are as follows:

Exploration	$	149,037	$	—	$	—	$	64,939	$	213,976
Development		16,841		—		—		—		16,841
Total costs incurred	$	165,878	$	—	$	—	$	64,939	$	230,817

F-12

Capitalized costs as of December 31, 2011 are as follows:

	United States			Australia			Indonesia			Canada			Totals
Proved properties	$	47,128,745		$	2,388,051		$	774,777		$	2,685,659		$	52,977,232
Unproved properties		4,486,744			1,522,718			587,040			334,997			6,931,499
Gas processing plant		5,533,910			—			—			—			5,533,910
Less—accumulated depletion and impairment		(34,974,595	)		(2,388,051	)		(774,777	)		(2,685,659	)		(40,823,082	)
Net capitalized costs	$	22,174,804		$	1,522,718		$	587,040		$	334,997		$	24,619,559

Costs incurred for the year ended December 31, 2011 are as follows:

Gas processing plant upgrade	$	428,698	$	—	$	—	$	—	$	428,698
Exploration		66,277		—		—		2,347		68,624
Development		878,476		—		—		6,355		884,831
Total costs incurred	$	1,373,451	$	—	$	—	$	8,702	$	1,382,153

In April 2012, the Company's wholly-owned subsidiary, Redwood Energy Production, L.P., elected to temporarily shut-in its natural gas production at the Madisonville Field, Madison County, Texas in light of depressed natural gas prices.  The Company will monitor market conditions and bring its natural gas production back on stream as market conditions warrant.

In August 2012, the Company sold certain oil and gas properties for approximately $500,000.

The Company reclassified costs associated with Indonesia projects of $587,040 and $750,133 to the full cost pool for the years ended December 31, 2012 and 2011, respectively.  Considering that we do not have any proved reserves in Indonesia, those costs were immediately charged to impairment.

The Company reclassified costs associated with Canada projects of $33,616 to the full cost pool for the year ended December 31, 2012.  Considering that we do not have any proved reserves in Canada, those costs were immediately charged to impairment.

The Company has proved undeveloped reserves included in the carrying value of its proved properties.  The Company is confident capital will be raised to further develop these reserves. If the capital is not raised the Company may be required to impair the Proved property asset in the future.

Unproved Oil and Gas Properties—United States—As GeoPetro’s properties are evaluated through exploration, they will be included in the amortization base. The prospects and their related costs in unproved properties have been assessed individually and no impairment charges were considered necessary for the United States properties for any of the periods presented. The current status of these prospects is that seismic data is being interpreted on an on-going basis on the subject lands within the prospects.

Unproved properties in the United States as of December 31, 2012 and 2011 consist primarily of exploration costs related to our retained interest in the Alaska prospect following the sale of our working interest to Linc Energy (Alaska) Inc. (“Linc”) on February 26, 2010.

On May 2, 2011 Linc reported that drilling and testing on the LEA #1 well located in the Point MacKenzie Block of the Cook Inlet Basin had been completed. Three sandstone targets were tested separately. Despite the fact that gas shows were encountered while drilling, the sandstone targets were too tight to produce commercial quantities of gas. Although the LEA#1 has not proved to be commercial, the operator intends to use information acquired while drilling the well to continue exploration in the Cook Inlet Basin.  The cost basis of unproved properties in Alaska as of December 31, 2012 is $3,710,658.

Costs incurred in connection with unproved properties in the United States during the year ended December 31, 2012 consisted primarily of exploration costs in connection with GeoPetro’s California prospect.  Drilling on the California prospect is expected to commence in 2013 or 2014, and is expected to continue in future periods.

F-13

Unproved Oil and Gas Properties—Australia—Unproved costs incurred in Australia represent costs in connection with the exploration of two exploration permit areas in Australia. The prospects and their related costs in unproved properties have been assessed individually and no impairment charges were considered necessary for the Australian properties for any of the periods presented. On June 20, 2007, the Company entered into a contract to sell its Australian Properties to an unaffiliated third party. These costs remaining in unproved properties represent our retained interest.

Unproved Oil and Gas Properties—Indonesia—Unproved costs incurred in Indonesia related to the Bengara Block represent costs in connection with one production sharing contract area and the exploration efforts in Indonesia.

The Company had retained a carried 12% stake in the Bengara II Block PSC through its investment in Continental-GeoPetro (Bengara-II) Ltd. (“C-G Bengara”), the operator company of the project with offices in Jakarta, Indonesia. GeoPetro’s partner, Continental Energy Corporation likewise retained an 18% interest in C-G Bengara. CNPCHK (Indonesia) Limited owned the remaining 70% interest in C-G Bengara and has paid 100% of the cost of drilling certain exploratory and appraisal wells.

The Company has been notified that the operator of the Bengara II Production Sharing Contract (“PSC”) has terminated negotiations with the Indonesian government for an extension of the PSC’s terms. The PSC shall now be relinquished and allowed to expire in accordance with its terms. As a result, the Company has recorded an impairment charge of $587,040 to its oil and gas properties for the year ended December 31, 2012.

In September 2011, the decision was made to terminate CG Xploration and wind down operations.  The Company has recorded an impairment charge of $750,133 in September 2011 as a result.

Unproved Oil and Gas Properties—Canada—Unproved costs incurred in Canada primarily represent costs in connection with the Swan Hills Project in Alberta, Canada. The prospects and their related costs in unproved properties have been assessed individually and no impairment charges were considered necessary for the Canadian properties except for $33,616 in costs associated with an abandoned prospect. 

In June 2012, the Company’s wholly owned subsidiary, GeoPetro Canada Ltd., acquired the remaining two-thirds (2/3) working interest in the Swan Hills Project, Central Alberta, Canada in exchange for an overriding royalty interest.  Following the acquisition, the Company now owns 100% of the working interest in the Project.

Breakdown of Unproved Oil and Gas Properties—The following table sets forth a summary of oil and gas property costs not being amortized at December 31, 2012, by the period in which the costs were incurred:

			Year Ended		Year Ended		Year Ended
			December 31,		December 31,		December 31,		2009 and Prior
	Totals		2012		2011		2010		Years
Unproved property acquisition	$	2,150,134	$	—	$	—	$	—	$	2,150,134
Exploration		4,374,685		213,976		68,624		201,234		3,890,851
Total	$	6,524,819	$	213,976	$	68,624	$	201,234	$	6,040,985

Management expects that planned activities for the year 2013 will enable the evaluation of approximately 25% of the costs as of December 31, 2012. Evaluation of 30% of the remaining costs is expected to occur in 2014 with the remaining 45% in 2015 and beyond.

Gas Processing Plant

There are asset retirement obligations associated with the Plant. However, components of the Plant can be used for extended and indeterminate periods of time as long as they are properly maintained and/or upgraded. GeoPetro’s intent is to maintain the Plant assets and continue making improvements to those assets based on technological advances. As a result, GeoPetro’s management believes that the Plant has an indeterminate life for purposes of estimating asset retirement obligations because dates or ranges of dates upon which GeoPetro would retire the Plant cannot reasonably be estimated.

F-14

5.         DEBT

Debt at December 31, 2012 and December 31, 2011 consisted of the following:

	December 31, 2012			December 31, 2011
Current Portion
Related party notes (a)	$	565,000		$	—
Promissory notes 12/08 (b)		—			850,000
Promissory notes 06/09 (d)		—			300,000
Bridge notes 08/10, 10/10 (e)		900,000			—
Promissory note 09/10 (f)		75,000			75,000
Less discount on promissory notes		(30,050	)		(27,615	)
Net current notes payable		1,509,950			1,197,385
Long Term
Promissory notes 12/08 (b)		850,000			—
Promissory notes 05/09 (c)		365,000			365,000
Promissory notes 06/09 (d)		300,000			—
Bridge notes 08/10, 10/10 (e)		—			900,000
Promissory note 09/10 (f)		150,000			225,000
Less discount on promissory notes		(20,573	)		(66,293	)
Net Long term notes payable		1,644,427			1,423,707
Total	$	3,154,378		$	2,621,092

a) In February 2011, Stuart J. Doshi, President and CEO, advanced to the Company a loan in the amount of $125,000 which was payable on demand. The note bears an annual rate of eight percent (8%) interest.  In September 2011, the outstanding principal of $125,000 and the accrued interest thereon were paid in full.  During the year ended December 31, 2012, Stuart J. Doshi, President and CEO, advanced to the Company twelve loans totaling $565,000 which are payable on demand. The notes bear an annual rate of ten percent (10%), with such interest payable quarterly in arrears. These notes are secured by a first position deed of trust against the Company’s improved real property located in Madison County, Texas, commonly known as the Madisonville Gas Processing Plant site. In connection with these notes, the Company issued 113,000 warrants to purchase our common stock. The fair value of the warrants issued was $4,520 (Note 9), which has been recorded as a debt discount and will be amortized over the life of the note.  Since these notes are payable on demand, the debt discount has been fully amortized in 2012. Interest expense accrued on these notes for the year ended December 31, 2012 was $28,083.

b) In December 2008, the Company issued four promissory notes totaling $1,050,000 with maturity dates in December 2011. The notes may be repaid at any time without penalty. The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears. In connection with the notes, the Company paid loan origination fees totaling $6,000 and granted three-year exercisable warrants to purchase 105,000 Common Shares and reissued 15,000 warrants at $1.00 per share. We also issued 150,000 warrants as a finder’s fee. The fair value of the warrants on the dates of issuance of $122,764 and the $6,000 of loan origination fees, were recorded as a debt discount and have been amortized over the life of the promissory notes. In February 2011, we extended the maturity on three separate notes totaling $850,000 to December 2012. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year. The fair value associated with the warrant extension was $4,370 (Note 9), which has been recorded as a debt discount and has been amortized over the extended life of the notes. In December 2011, one of the four original promissory notes for $200,000, and the accrued interest thereon, was paid in full. In May 2012, we extended the maturity on the three remaining notes totaling $850,000 to January 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $1,766 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $1,736.

F-15

c) In May 2009, the Company issued two promissory notes totaling $365,000 with maturity dates in May 2012.  The notes may be repaid at any time without penalty.  The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears.  In connection with the notes, the Company granted three-year exercisable warrants to purchase 36,500 Common Shares at $1.00 per share. The fair value of the warrants on the dates of issuance of $12,724 was recorded as a debt discount and has been amortized over the life of the promissory notes. In February 2011, we extended the maturity of the notes to May 2013. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these two notes for an additional year. The fair value associated with the warrant extension was $1,876 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. In May 2012, we extended the maturity on the notes to May 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $971 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $1,674.

d) In June 2009, the Company issued two promissory notes totaling $300,000 with maturity dates in June 2010.  The notes may be repaid at any time without penalty.  The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears.  In connection with the notes, the Company granted three-year exercisable warrants to purchase 30,000 Common Shares at $1.00 per share. The fair value of the warrants on the date of issuance of $7,537 was recorded as a debt discount and has been amortized over the life of the promissory notes.  In March 2010, these two notes were extended for an additional one year and the new maturity was June 2011.  In February 2011, we extended the maturity on the notes to June 2012.  In connection with the extension, the Company extended the warrants to purchase our common stock associated with these two notes for an additional year. The fair value associated with the warrant extension was $1,542 (Note 9), which has been recorded as a debt discount and has been amortized over the extended life of the notes. In May 2012, we extended the maturity on the notes to January 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $839 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $574.

e) During August through October 2009, the Company borrowed an aggregate of $950,000 pursuant to four separate bridge loans with maturity dates in August 2010 and October 2010.  The notes may be repaid at any time without penalty.  The notes bear an annual rate of ten percent (10%), with such interest payable at maturity.  In connection with the issuance of these notes we issued 47,500 warrants to purchase our common stock. The fair value of the warrants on the dates of issuance of $24,162 was recorded as a debt discount and has been amortized over the life of the promissory notes.  During August through October 2010, we partially repaid a promissory note in the amount of $50,000. We renewed three promissory notes totaling $180,000 with new maturity dates of August 2011 and renewed one promissory note in the amount of $720,000 with a new maturity date of October 2011.  Prior to the note renewals we repaid all outstanding accrued interest on the notes.  The terms of the renewed notes payable remain materially consistent those previously issued.  In connection with the issuance of these notes we issued a total of 95,000 warrants to purchase our common stock and recorded $36,000 in renewal fees. The fair value of the warrants on the date of issuance of $23,286, and the $36,000 renewal fees, were recorded as a debt discount and have been amortized over the life of the promissory notes.  During August through October 2011, we renewed three promissory notes totaling $180,000 with new maturity dates of August 2013 and renewed one promissory note in the amount of $720,000 with a new maturity date of October 2013.  Prior to the note renewals we repaid all outstanding accrued interest on the notes. The terms of the renewed notes payable remain materially consistent those previously issued. In connection with the issuance of these notes we issued a total of 37,000 warrants to purchase our common stock and recorded $27,000 in renewal fees. The fair value of the warrants on the date of issuance of $5,374 (Note 9), and the $27,000 renewal fees, were recorded as a debt discount and are being amortized over the life of the promissory notes.  As of December 31, 2012 the unamortized portion of the debt discount was $12,803.

f) In September 2010, we issued a 5-year non-interest bearing note payable in the amount of $375,000 in connection with the execution of a settlement agreement. Payments are due as follows: $25,000 in March 2011, $50,000 in October 2011, and $75,000 each October thereafter until 2015.  Payments totaled $75,000 in the year ended December 31, 2011 and $75,000 in the year ended December 31, 2012.  An imputed interest rate of 10% per annum has been used to record a discount in connection with this note of $90,116, and is being amortized over the life of the note.  As of December 31, 2012 the unamortized portion of the debt discount was $33,836.

F-16

g) Effective December 31, 2008, the Company assumed certain bank debt related to the Company’s acquisition of the Madisonville Gas Treatment Plant (the “Plant”). The Company increased borrowing under this note by $600,000 in June 2011 and by $400,000 in July 2011.  In September 2011, the outstanding principal and accrued interest were paid in full. Total principal repaid in the year ended December 31, 2011 under this note was $5,372,847.

h) In December 2010, we issued 1-year notes payable at 6% per annum in the amount of $300,000 with maturity dates of December 2011. The notes were secured by the Swan Hills Project in Canada. In connection with the notes, the Company granted three-year exercisable warrants to purchase 75,000 shares of Common Shares at $0.50 per share. The fair value of the stock purchase warrants issued in connection with this note of $16,662 was recorded as a debt discount and was amortized over the life of the promissory note.  In September 2011, these notes totaling $300,000 and the accrued interest thereon were paid in full.

A schedule of Maturities of our Debt Obligations as of December 31, 2012 is as follows;

Maturity Date	2013		2014		2015
January	$	565,000	$	1,150,000	$	—
May		—		365,000		—
August		180,000		—		—
October		795,000		75,000		75,000
Totals	$	1,540,000	$	1,590,000	$	75,000

6.         INCOME TAXES

The Company files income tax returns in the U.S. federal jurisdiction and various states.  There are currently no federal or state income tax examinations underway.  Furthermore, the Company is no longer subject to U.S. federal income tax examinations by the Internal Revenue Service for tax years before 2009 and for state and local tax authorities for tax years before 2008.  The Company does, however, have net operating losses generated in tax years 1997 and after, which remain open for examination.

The Company adopted the provisions of ASC 740 (formerly SFAS 109 and FIN 48), on January 1, 2007. As of December 31, 2007 the Company had no unrecognized tax benefits. There have been no changes during the year with respect to unrecognized tax benefits.  The Company does not foresee the total amounts of unrecognized tax benefits significantly increasing within the next 12 months.  Furthermore, no corresponding interest and penalties have been accrued as the Company is in a net operating loss position.

ASC 740 requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of the assets and liabilities. Where it is more likely than not that a tax benefit will not be realized, a valuation allowance is recorded to reduce the deferred tax asset to its realizable value.

A valuation allowance has been provided against the Company’s net deferred tax assets as the Company believes that it is more likely than not that the net deferred tax assets will not be realized.

The effective tax rate for the year ended December 31, 2012 is negligible.

The provision for income taxes consists of the following:

	2012		2011
Current
Federal	$	—	$	—
State		9,664		800
Foreign		—		—
Total		9,664		800
Deferred
Federal		—		—
State		—		—
Foreign		—		—
Total		—		—
Total Income Tax Provision	$	9,664	$	800

F-17

The actual income tax (benefit) expense differs from the expected tax (benefit) expense as computed by applying the U.S. Federal corporate income tax rate of 35% for each period as follows:

	2012			2011
Amount of expected tax benefit	$	(1,456,563	)	$	(515,000	)
Non-deductible expenses		3,560			4,000
Alternative minimum tax		—			—
State Taxes		9,664			800
Valuation allowance adjustments		1,453,003			511,000
	$	9,664		$	800

Deferred income taxes reflect the net tax effects of temporary differences between carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Significant components of the Company’s deferred tax assets (liabilities) are as follows:

	2012			2011
Deferred tax assets (liabilities)
Net operating loss carry forwards	$	14,150,000		$	12,127,000
Oil and gas property basis differences		3,662,000			3,480,000
Stock compensation		793,000			633,000
Other		(990,000	)		(726,000	)
Total deferred tax assets		17,615,000			15,514,000
Valuation allowance		(17,615,000	)		(15,514,000	)
Total net deferred taxes	$	—		$	—

As of December 31, 2012, GeoPetro had net operating loss (NOL) carryforwards of approximately $39,500,000 for federal income tax purposes which begin to expire in 2017.  If the Company were to experience a change in ownership under Section 382, the Company may be limited in its ability to fully utilize its net operating losses.

However, in accordance with ASC 718 (formerly SFAS 123(R)), a deferred tax asset has not been recognized for the portion of the net operating loss carryforwards that is attributable to excess tax deductions associated with the exercise of stock options which do not reduce income taxes payable. Accordingly, approximately $3,536,000 of GeoPetro’s federal NOL has not been benefited for financial statement purposes as it relates to excess tax deductions that have not reduced income taxes payable. The benefit of these excess tax deductions will not be recognized for financial statement purposes until the related deductions reduce income taxes payable.

The Company also has approximately $12,430,000 of California net operating losses and approximately $670,000 of Alaska net operating losses which begin to expire in 2012 and 2026, respectively. In accordance with ASC 718, a portion of the state NOLs has similarly not been benefited for financial statement purposes as it relates to excess tax deductions which have not resulted in the reduction of income taxes payable. The benefit of such excess tax deductions will not be recognized for financial statement purposes until the related deductions reduce state income taxes payable.

In addition, the Company has approximately $318,264 of carryforward credits in Texas, a portion of which may be utilized each year against Texas Margin Tax liability through 2027.

7.         SHAREHOLDERS’ EQUITY

GeoPetro’s articles of incorporation allow for the issuance of 100,000,000 shares of common stock, 1,000,000 shares of Series A preferred stock, 5,000,000 shares of Series AA preferred stock, and an additional 44,000,000 shares of preferred stock which may be issued from time to time in one or more series, with such rights and preferences as determined by our Board of Directors.

Common Stock—The holders of our common stock are entitled to one vote per share. Subject to preferences on outstanding preferred stock, the holders of common stock are entitled to receive ratably such dividends as may be declared by the board of directors. In the event of a liquidation, the holders of common stock are entitled to share ratably in all assets remaining after payment of liabilities, subject to prior distribution rights of preferred stock.

F-18

In March 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants (Note 9).  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In August 2012, we agreed to issue 225,000 shares of common stock to our independent directors. The shares were valued at the closing price of $0.14 per share and have been recorded as share-based compensation in the financial statements.  The aggregate value of the shares issued was $31,500.  We agreed to grant "piggyback" registration rights to the directors with respect to the shares of common stock.

In November 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $10,000, and represented the sale of 100,000 common shares and 50,000 warrants (Note 9).  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In December 2012, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $100,000, and represented the sale of 1,000,000 common shares and 500,000 warrants (Note 9).  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In March 2011, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.45 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.75 for a period of three years. The total aggregate purchase price for the units sold was $922,648, and represented the sale of 2,050,328 common shares and 1,025,164 warrants (Note 9).  We granted “piggyback” registration rights to the investors with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investors acquired in the transaction.

In June 2011, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.55 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $1.00 for a period of three years. The total aggregate purchase price for the units sold was $556,560, and represented the sale of 1,011,928 common shares and 505,965 warrants (Note 9).  We granted “piggyback” registration rights to the investors with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investors acquired in the transaction.

Series B Preferred Stock— As of December 31, 2012, there are 5,423,000 shares of Series B Stock issued and outstanding.  The holders of Series B Stock are entitled to receive an annual dividend at the rate of $0.06 per share and are entitled to such number of votes per share as equals the number of common shares into which each share of Series B Stock is convertible. Each share of Series B Stock is convertible, at the option of the holder, into fully paid and non-assessable common shares on a one-for-one basis, subject to certain adjustments. The Series B Stock will automatically convert into common shares on a one-for-one share basis effective the first trading day after the reported high selling price for the Company’s common shares on any international, national or regional securities exchange or inter-dealer quotation system including but not limited to, NASDAQ, the Pink Sheets or the Over-the-Counter Bulletin Board, is at least $1.50 per share for any ten consecutive trading days. If an automatic conversion occurs within one year after the Series B Stock was purchased from the Company, a holder will receive, on the one-year anniversary date of his, her or its purchase, a cash dividend equivalent to a full year of dividends less any dividends paid before such conversion. In 2012 and 2011, we incurred $325,380 and $434,639 in dividends on the Series B Stock, respectively, of which $0 and $0 were paid in 2012 and 2011, respectively.

In March 2011, a holder of 20,000 shares of the Company’s Series B Preferred Stock, converted shares on a one-for-one basis into fully paid and non-assessable shares of the Company’s Common Stock.

F-19

In July 2011, a holder of 80,000 shares of the Company’s Series B Preferred Stock, converted shares on a one-for-one basis into fully paid and non-assessable shares of the Company’s Common Stock.

In November 2011, holders of 2,000,000 shares of the Company’s Series B Preferred Stock, converted shares on a one-for-one basis into fully paid and non-assessable shares of the Company’s Common Stock.

8.         COMMON STOCK OPTIONS

Effective as of September 10, 2001, the board of directors approved an incentive stock plan (“Stock Incentive Plan”), providing for awards under the terms and provisions of such plan of incentive stock options, stock appreciation rights and restricted stock awards to officers, directors and employees of GeoPetro and its consultants. The plan provides, among other provisions, the following:

· The maximum number of Common Shares which may be awarded, optioned and sold under the plan is 5,000,000 (subject to adjustment for stock splits, stock dividends and certain other adjustments to GeoPetro’s common stock); and the per share exercise price for Common Shares to be issued pursuant to the exercise of an option shall be no less than the fair market value of GeoPetro’s Common Shares as of the date of grant;

· The Stock Incentive Plan provides for the granting to employees incentive stock options within the meaning of Section 422 of the United States Internal Revenue Code of 1986, as amended, and for the granting of non-statutory stock options to directors who are not employees and consultants. In the case of employees who receive incentive stock options which are first exercisable in a particular calendar year and the aggregate fair market value of which exceeds $100,000, the excess of the $100,000 limitation shall be treated as a nonstatutory stock option under the Stock Incentive Plan;

· The Stock Incentive Plan is being administered by the Board of Directors. The Board of Directors determines the terms of the options granted, including the number of Common Shares subject to each option, the exercisability and vesting requirements of each option, and the form of consideration payable upon the exercise of such option (i.e., whether cash or exchange of existing Common Shares in a cashless transaction or a combination thereof); and

· The Stock Incentive Plan will continue in effect for 10 years from September 10, 2001 (i.e., the date first adopted by the Board), unless sooner terminated by the board of directors. In 2004, we implemented a new 2004 Stock Option and Appreciation Rights Plan (“Stock Option Plan”) providing for awards of incentive stock options, non-qualified stock options and stock appreciation rights. The Stock Option Plan replaced the Stock Incentive Plan as to new award grants effective in 2004 or thereafter to our directors, officers, employees and consultants. Outstanding awards issued under the Stock Incentive Plan will continue to be outstanding in accordance with their terms and the terms of the Stock Incentive Plan, but will count toward the limits in the number of shares of common stock available to be issued under the Stock Option Plan, which is 5,000,000. The exercise price of stock options granted under the Stock Option Plan may not be less than 110% of the fair market value of our common stock on the date of grant.

In August 2012, we granted 675,000 stock options at an exercise price of $0.16 per share.  These options will vest ratably over five years pursuant to the terms of the Stock Option Plan.  The grant date fair value of the options was $70,831.

In April 2011, 150,000 common stock options with an exercise price of $3.85 per share expired.

In August 2011, we granted 25,000 stock options at an exercise price of $0.50 per share.  These options will vest ratably over five years pursuant to the terms of the Stock Option Plan.  The grant date fair value of the options was $6,852.

The Company recorded stock compensation expense of $422,999 and $407,311 for the twelve months period ended December 31, 2012 and 2011, respectively.

F-20

A summary of the status of GeoPetro’s stock option plan is as follows:

	Options			Exercise Prices			Weighted Average Exercise Price
Outstanding at January 1, 2011		2,895,000		$0.50	to	$3.85	$	1.59
Granted		25,000			$0.50			0.50
Exercised		—			—			—
Expired		(150,000	)		$3.85			3.85
Outstanding at December 31, 2011		2,770,000		$0.50	to	$2.10		1.46
Granted		675,000			$0.16			0.16
Exercised		—			—			—
Expired		—			—			—
Outstanding at December 31, 2012		3,445,000		$0.16	to	$2.10	$	1.21

We estimated the fair values of each option granted using the Black-Scholes model with the following assumptions for options granted during the years ended December 31:

	2012			2011
Expected dividend yield		—			—
Expected volatility		105.6	%		149.8	%
Risk-free interest rates		0.59	%		0.99	%
Expected lives (years)		5			5
Weighted average fair values per share	$	0.11		$	0.27

 We estimated the dividend yield at 0% considering that we have not historically paid dividends on our common stock, nor do we expect to pay dividends in the foreseeable future.  Volatility estimates represent the historic trading volatility underlying our common stock at the date of grant.  We estimated risk-free interest rates based on the U.S. Treasury yield curve at the date of grant.  Expected lives are based on our historic experience with employee option exercise behavior and consider the vesting period and the contractual lives of the related options.

The options outstanding as of December 31, 2012 have the following contractual lives:

Number of Options Outstanding		Number of Options Exercisable		Exercise Prices		Weighted Average Remaining Contractual Life
	675,000		—		0.16		4.67
	960,000		675,000		0.50		0.99
	210,000		186,000		1.00		0.68
	1,600,000		1,600,000		2.10		0.39
	3,445,000		2,461,000

The total intrinsic value of options outstanding was $nil at December 31, 2012 and 2011, respectively. The intrinsic value for exercisable options was $nil at December 31, 2012 and 2011, respectively.

As of December 31, 2012, there are 2,461,000 options which are exercisable. The remaining 984,000 options will become exercisable over the next four years. The stock compensation expense related to the unvested awards is $286,951. The weighted average remaining contractual life of the remaining 984,000 unvested options is 3.69 years.

9.         COMMON STOCK WARRANTS

In February 2012, warrants for 50,000 shares with an exercise price of $1.00 per share expired.

In March 2012, we issued 20,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of a note payable to Stuart J. Doshi, President and CEO, for $100,000 (Note 5). The warrants expire in March 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,609.

In March 2012, we issued 500,000 warrants to purchase our common shares at $0.50 per share in conjunction with a private placement of our common stock (Note 7). The warrants expire in March 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $40,070.

F-21

 In May 2012, we extended 151,500 warrants to purchase our common shares for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share in connection with the extension of seven notes payable totaling $1,515,000 (Note 5). The extended warrants expire in December 2013, May 2014 and June 2014.  The total fair value of the extension of the warrants as calculated using the Black-Scholes pricing model was $3,575.

In May 2012, we issued 15,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of two notes payable to Stuart J. Doshi, President and CEO, totaling $75,000 (Note 5). The warrants expire in May 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $561.

In June 2012, we issued 45,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of four notes payable to Stuart J. Doshi, President and CEO, totaling $225,000 (Note 5). The warrants expire in June 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,481.

In July 2012, we issued 15,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of two notes payable to Stuart J. Doshi, President and CEO, totaling $75,000 (Note 5). The warrants expire in July 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $315. 

In August 2012, warrants for 600,779 shares with an exercise price of $4.50 per share expired.

In August 2012, we issued 45,000 warrants to purchase our common shares at $0.50 per share in exchange for certain consulting services. The warrants expire in August 2016.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $2,986.

In September 2012, warrants for 14,000 shares with an exercise price of $1.00 per share expired.

In October 2012, we issued 72,000 warrants to purchase our common shares at a price ranging from $0.10 to $0.23 per share in exchange for certain consulting services. The warrants expire in October 2017.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $5,887.

In October 2012, warrants for 36,000 shares with an exercise price of $1.00 per share expired.

In November 2012, we issued 12,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of two notes payable to Stuart J. Doshi, President and CEO, totaling $60,000 (Note 5). The warrants expire in November 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $413.

In November 2012, we issued 30,000 warrants to purchase our common shares at $0.50 per share in exchange for certain consulting services. The warrants expire in November 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,014.

In November 2012, warrants for 50,000 shares with an exercise price of $1.25 per share expired.

In November 2012, we issued 50,000 warrants to purchase our common shares at $0.50 per share in conjunction with a private placement of our common stock (Note 7). The warrants expire in November 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,452.

In December 2012, we issued 6,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of a note payable to Stuart J. Doshi, President and CEO, for $30,000 (Note 5). The warrants expire in December 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $141.

In December 2012, we issued 500,000 warrants to purchase our common shares at $0.50 per share in conjunction with a private placement of our common stock (Note 7). The warrants expire in December 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $18,429.

The fair value of the warrants for 2012 was calculated using the Black-Scholes pricing model. Key assumptions used in valuing the warrants included: an estimated dividend yield of 0%; volatility between 81% to 137%; an estimated risk-free interest rate based on the U.S. Treasury yield curve at the date of grant of between 0.27% to 0.80%; and an expected life of three to five years.

F-22

In February 2011 we extended a total of 151,500 warrants for an additional year in conjunction with the renewal of seven of our promissory notes payable (Note 5). The warrants expire in December 2012, May 2013, and June 2013, respectively.  The total fair value of the extension of the warrants as calculated using the Black-Scholes pricing model was $7,788.

In March 2011, we issued 1,025,164 warrants to purchase our common shares at $0.75 in conjunction with a private placement of our common stock (Note 7). The warrants expire in March 2014.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $207,943.

In April 2011, we issued 505,965 warrants to purchase our common shares at $1.00 in conjunction with a private placement of our common stock (Note 7). The warrants expire in April 2014.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $165,105.

In August 2011 we extended 150,000 warrants for an additional two years.  The warrants expire in January 2014.  The total fair value of the extension of the warrants as calculated using the Black-Scholes pricing model was $17,539.

In September 2011, we issued 10,000 warrants to purchase our common shares at $0.50 in conjunction with the renewal of one of our promissory notes payable (Note 5).  The warrants expire in August 2014.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $2,204.

In September 2011, warrants for 27,150 shares with an exercise price of $1.00 per share expired.

In November 2011, we issued 27,000 warrants to purchase our common shares at $0.50 in conjunction with the renewal of four of our promissory notes payable (Note 5).  The warrants expire in November 2013.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $3,170.

In December 2011, warrants for 114,000 shares with an exercise price of $3.50 per share expired and warrants for 35,000 shares with an exercise price of $1.00 per share expired.

The fair value of the warrants for 2011 was calculated using the Black-Scholes pricing model. Key assumptions used in valuing the warrants included: an estimated dividend yield of 0%; volatility of between 78% to 140%; an estimated risk-free interest rate based on the U.S. Treasury yield curve at the date of grant of between 0.23% to 1.15%; and an expected life of between two and three years.

F-23

The following table summarizes the number of shares reserved for the exercise of common stock purchase warrants as of December 31, 2012:

Expiration	Exercise		Outstanding at		Warrants		Warrants		Warrants			Outstanding at
Date	Price		12/31/2011		Exercised		Granted		(Expired/Canceled)			12/31/2012
02/22/12	$	1.00		50,000		—		—		(50,000	)		—
08/13/12	$	4.50		600,779		—		—		(600,779	)		—
09/30/12	$	1.00		14,000		—		—		(14,000	)		—
10/22/12	$	1.00		36,000		—		—		(36,000	)		—
11/22/12	$	1.25		50,000		—		—		(50,000	)		—
08/31/13	$	0.50		23,000		—		—		—			23,000
09/29/13	$	0.75		1,847,500		—		—		—			1,847,500
10/31/13	$	0.50		72,000		—		—		—			72,000
11/30/13	$	0.50		27,000		—		—		—			27,000
12/23/13	$	0.50		120,000		—		—		—			120,000
12/25/13	$	0.50		40,000		—		—		—			40,000
12/30/13	$	0.75		555,596		—		—		—			555,596
01/02/14	$	1.00		150,000		—		—		—			150,000
03/01/14	$	0.75		1,025,164		—		—		—			1,025,164
03/31/14	$	5.25		100,000		—		—		—			100,000
04/28/14	$	1.00		505,965		—		—		—			505,965
05/17/14	$	0.50		36,500		—		—		—			36,500
06/29/14	$	0.50		30,000		—		—		—			30,000
08/31/14	$	0.50		10,000		—		—		—			10,000
10/19/14	$	1.00		130,540		—		—		—			130,540
03/20/15	$	0.50		—		—		20,000		—			20,000
03/21/15	$	0.50		—		—		500,000		—			500,000
05/29/15	$	0.50		—		—		5,000		—			5,000
05/30/15	$	0.50		—		—		10,000		—			10,000
06/04/15	$	0.50		—		—		8,000		—			8,000
06/18/15	$	0.50		—		—		5,000		—			5,000
06/25/15	$	0.50		—		—		12,000		—			12,000
06/29/15	$	0.50		—		—		20,000		—			20,000
07/27/15	$	0.50		—		—		2,000		—			2,000
07/31/15	$	0.50		—		—		13,000		—			13,000
11/09/15	$	0.50		—		—		2,000		—			2,000
11/20/15	$	0.50		—		—		10,000		—			10,000
11/21/15	$	0.50		—		—		30,000		—			30,000
11/29/15	$	0.50		—		—		50,000		—			50,000
12/04/15	$	0.50		—		—		6,000		—			6,000
12/10/15	$	0.50		—		—		125,000		—			125,000
12/31/15	$	0.50		—		—		375,000		—			375,000
08/15/16	$	0.50		—		—		45,000		—			45,000
10/01/17	$	0.23		—		—		12,000		—			12,000
10/01/17	$	0.21		—		—		12,000		—			12,000
10/01/17	$	0.20		—		—		12,000		—			12,000
10/01/17	$	0.17		—		—		12,000		—			12,000
10/01/17	$	0.14		—		—		12,000		—			12,000
10/01/17	$	0.10		—		—		12,000		—			12,000
				5,424,044		—		1,310,000		(750,779	)		5,983,265

F-24

The following table summarizes the number of shares reserved for the exercise of common stock purchase warrants as of December 31, 2011:

Expiration	Exercise		Outstanding at		Warrants		Warrants		Warrants			Outstanding at
Date	Price		12/31/2010		Exercised		Granted		(Expired/Canceled)			12/31/2011
09/30/11	$	1.00		27,150		—		—		(27,150	)		—
12/15/11	$	3.50		114,000		—		—		(114,000	)		—
12/22/11	$	1.00		35,000		—		—		(35,000	)		—
02/22/12	$	1.00		50,000		—		—		—			50,000
08/13/12	$	4.50		600,779		—		—		—			600,779
09/30/12	$	1.00		14,000		—		—		—			14,000
10/22/12	$	1.00		36,000		—		—		—			36,000
11/22/12	$	1.25		50,000		—		—		—			50,000
12/23/12	$	1.00		45,000		—		—		—			45,000
12/25/12	$	1.00		40,000		—		—		—			40,000
05/17/13	$	1.00		36,500		—		—		—			36,500
06/29/13	$	1.00		30,000		—		—		—			30,000
08/31/13	$	0.50		23,000		—		—		—			23,000
09/29/13	$	0.75		1,847,500		—		—		—			1,847,500
10/31/13	$	0.50		72,000		—		—		—			72,000
11/30/13	$	0.50		—		—		27,000		—			27,000
12/23/13	$	0.50		75,000		—		—		—			75,000
12/30/13	$	0.75		555,596		—		—		—			555,596
01/02/14	$	1.00		150,000		—		—		—			150,000
03/01/14	$	0.75		—		—		1,025,164		—			1,025,164
03/31/14	$	5.25		100,000		—		—		—			100,000
04/28/14	$	1.00		—		—		505,965		—			505,965
08/31/14	$	0.50		—		—		10,000		—			10,000
10/19/14	$	1.00		130,540		—		—		—			130,540
				4,032,065		—		1,568,129		(176,150	)		5,424,044

10.       COMMITMENTS AND CONTINGENCIES

Employment Agreements—The Company entered into a contract of employment with Stuart J. Doshi, Founder, President, Chief Executive Officer and Chairman of the Board of Directors, as amended through December 31, 2008. The contract, as amended, provides for a five-year term commencing May 1, 2005 which term is automatically extended for successive two-year renewal terms unless: (a) the board of directors elects not to renew the contract and the Company provides notice to Mr. Doshi of such non-renewal at least six months prior to the expiry of his employment term or any renewal term, or (b) Mr. Doshi attains age 75, in which case the term ends upon the completion of the calendar year in which he becomes 75 years old unless the Company and Mr. Doshi mutually agree to one-year extensions. The contract of employment currently provides for an annual base salary of $300,000 and further provides that in the event of a change of control of the Company or if Mr. Doshi is terminated without cause, he is entitled to receive (a) in exchange for all of his vested stock options and vested restricted shares, such number of Common Shares having a market value equal to the difference between (x) the aggregate total market value of all vested restricted shares and Common Shares he would receive upon exercise of all vested stock options less (y) the aggregate total exercise price for all of his vested stock options; provided, however, that if the Common Shares to be delivered to Mr. Doshi upon such change of control or termination have not been registered so as to permit immediate public resale, Mr. Doshi shall instead receive a cash payment equal to the market value on the date of termination of all vested stock options and restricted shares without any discount for liquidity or minority position against cancellation of such options and restricted shares, (b) a cash payment equal to the greater of (i) his compensation for the remainder of his term, including salary and the aggregate amount of his bonuses in respect of the last four fiscal years and (ii) four times his compensation in the current year, including his then-current salary and the average amount of his bonuses for the last four fiscal years, and (c) an additional cash payment representing his employment benefits equal to 20% of the amount of salary he is entitled to receive under (b)(i) or (b)(ii) above, as applicable. In addition, in the event of a change of control or termination without cause, all unvested options issued by the Company to Mr. Doshi will vest.

F-25

Office Lease—On February 15, 2010, we entered into a new lease for our principal executive office located at 150 California Street, Suite 600, San Francisco, CA 94111.  The terms of the lease provide for an eighty-four (84) month term. Minimum annual rentals due under this agreement as of December 31, 2012 are as follows:

2013	$	154,037
2014	158,238
2015	162,439
2016	166,640
2017	56,013
Total	$	697,367

Rent expense for the years ended December 31, 2012 and 2011, was approximately $144,834 and $144,834, respectively, and is included in general and administrative expenses in the accompanying statements of operations.

On January 6, 2011, we entered into a sublease agreement whereby a portion of the Company’s principal executive offices have been leased to a third party. The terms of the sublease agreement include a seventy-five month term cancelable by either party with ninety days written notice after December 31, 2011. The Company will recoup approximately 50% of the base rental obligation through the sublease agreement. This amount was approximately $82,419 and $67,289 for the years ended December 31, 2012 and 2011, respectively, and has been included as a reduction in general and administrative expenses in the accompanying statements of operations.

Madisonville Net Profits Interest—Redwood LP’s 100% working interest is subject to a net profits interest in favor of unrelated third parties. The net profits interest is 12.5% (proportionately reduced) of the net operating profits until payout is achieved. After payout, the net profits interest increases to 30% (proportionately reduced). Payout, for purposes of the net profits interest, is defined and achieved at such time as Redwood LP has recouped from net operating cash flows its total net investment in the project plus a 33% cash on cash return.

11.       SUBSEQUENT EVENTS

In January 2013, Stuart J. Doshi, President and CEO, advanced to the Company a loan for $5,000.  The note bears interest at 10% per annum and is payable on demand.  In connection with this note, the Company issued 1,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In January 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $132,500, and represented the sale of 1,325,000 common shares and 662,500 warrants. 

In January 2013, we agreed to rescind a unit subscription agreement. Units were originally priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitled the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units originally sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  The Company is reacquiring the common shares and warrants in exchange for a non-interest bearing unsecured note for $250,000 which matures in July 2014.

In February 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $122,500, and represented the sale of 1,225,000 common shares and 612,500 warrants. 

On February 28, 2013, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”), with MCW Energy Group Limited, an Ontario corporation (“MCW”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“Merger Sub”). Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “Merger”) and the Company will survive the Merger and continue as a subsidiary of MCW. The Merger Agreement has been approved by Boards of Directors of each of the Company, MCW and Merger Sub.  The merger is subject to customary closing conditions, including regulatory and shareholder approval.

F-26

In March 2013, Stuart J. Doshi, President and CEO, advanced to the Company three loans totaling $85,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 17,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In March 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $50,000, and represented the sale of 500,000 common shares and 250,000 warrants. 

In April 2013, Stuart J. Doshi, President and CEO, advanced to the Company three loans totaling $55,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 11,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

F-27

12.       SUPPLEMENTARY OIL AND GAS RESERVE INFORMATION: (UNAUDITED)

The reserve quantities and valuations are based upon estimates by MHA Petroleum Consultants LLC. The proved reserves presented herein are located entirely within the United States. Proved reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, i.e. prices and costs as of the date the estimate is made. SEC rules require that reserve calculations be based on the un-weighted average first-day-of-the-month prices for the prior twelve months. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions. Reservoirs are considered proved if economic productivity is supported by either actual production or a conclusive formation test. The area of a reservoir considered proved includes (A) that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any, and (B) the immediately adjoining portions not yet drilled, but which can reasonably be judged as economically productive on the basis of available geological and engineering data. In the absence of information on fluid contacts the lowest known structural occurrence of hydrocarbons controls the lower proved limit of the reservoir.

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

The estimates included in the following tables are by their nature inexact and are subject to changing economic, operating and contractual conditions. At December 31, 2012, all of GeoPetro’s reserves are attributable to two wells capable of production, one shut-in well and two undeveloped locations. Other than the producing wells and one shut-in well, there is no other production history as of or subsequent to that date. Reserve estimates for these wells are subject to substantial upward or downward revisions after production commences and a production history is obtained.   Accordingly, reserve estimates of future net revenues from production may be subject to substantial revision from year to year. Reserve information presented herein is based on reports prepared by independent petroleum engineers.

The assumptions used to compute the standardized measure are those prescribed by the Financial Accounting Standards Board and, as such, do not necessarily reflect GeoPetro’s expectations for actual revenues to be derived from those reserves nor their present worth. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these are the basis for the valuation process.

	Natural Gas (Mcf)
Proved Developed and Undeveloped Reserves
January 1, 2011		18,308
Revisions of previous estimates		791
Production		(210	)
December 31, 2011		18,889
Revisions of previous estimates		(984	)
Production		(116	)
December 31, 2012		17,789

	2012		2011
	(MMcf)		(MMcf)
Proved developed		—		2,453
Proved developed non-producing		9,126		7,328
Proved undeveloped		8,663		9,108
Total		17,789		18,889

Proved reserves presented herein are located entirely within in the United States

F-28

The following is a discussion of the material changes in our proved reserve quantities for the years ended December 31, 2012 and 2011.

Year Ended December 31, 2012

The downward revision of previous estimates of natural gas reserves during 2012 of 984 MMcf is attributable to decreases in gas prices as calculated under the new SEC pricing methodology, which has affected the economic life of the wells. Natural gas prices decreased approximately 35% from December 31, 2011 ($3.76 per Mcf) to December 31, 2012 ($2.46 per Mcf).

Year Ended December 31, 2011

The upward revision of previous estimates of natural gas reserves during 2011 of 791 MMcf is primarily attributable to a decrease in the anticipated operating costs of the wells and the operating costs of the plant, as well as an increase in the production rate following the workovers.

Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves

For purposes of the following disclosures, estimates were made of quantities of proved reserves and the periods during which they are expected to be produced. Future cash flows for the 2012 and 2011 estimates were computed by applying the simple arithmetic average of the natural gas price in effect on the first day of each month to estimated annual future net production from proved gas reserves, amounting to $2.46 per Mcf and $3.76 per Mcf at December 31, 2012 and 2011, respectively. For both 2012 and 2011, future development and production costs were computed by applying year-end costs to be incurred in producing and further developing the proved reserves. Future income tax expenses were computed by applying, generally, year-end statutory tax rates (adjusted for permanent differences, tax credits and allowances) to the estimated net future pre-tax cash flows. The discount was computed by application of a 10% discount factor. The calculations assume the continuation of existing economic, operating and contractual conditions. However, such arbitrary assumptions have not proven to be the case in the past. Other assumptions of equal validity could give rise to substantially different results.

	Year Ended December 31,
	2012			2011
	(in thousands)
Future cash inflows	$	44,045		$	72,305
Future production costs		(10,555	)		(16,512	)
Future development costs		(10,916	)		(10,916	)
Future income taxes		—			—
Future net cash flows		22,574			44,877
10% annual discount		(6,426	)		(12,258	)
Standardized measure of discounted future net cash flows	$	16,148		$	32,619

The PV-10 values shown in the aforementioned table are not intended to represent the current market value of the estimated proved oil and gas reserves owned by us.

Changes in the Standardized Measure of Discounted Futures Net Cash Flows from Proved Petroleum and Natural Gas Reserve Quantities.

	Years Ended December 31,
	2012			2011
Balance, beginning of period		32,619			29,102
Sales of oil and gas, net		(877	)		(1,509	)
Net change in prices and production costs		(16,452	)		6,121
Net change in future development costs		—			(2,760	)
Revisions of previous quantity estimates		(1,325	)		1,698
Net change in income taxes		—			—
Accretion of discount		3,674			2,505
Other		(1,491	)		(2,538	)
Balance, end of period	$	16,148		$	32,619

F-29

EXHIBIT INDEX

Exhibit   Number		Description
2.	1 (13)	Agreement and Plan of Merger dated February 28, 2013
2.	2 (14)	Amendment No. 1 to the Agreement and Plan of Merger dated April 4, 2013.
3.	1 (2)	Amended and Restated Articles of Incorporation of GeoPetro Resources Company
3.	2 (4)	Second Amended and Restated Bylaws of the GeoPetro Resources Company
4.	1 (2)	Form of Warrant issued by GeoPetro Resources Company to various investors on various dates.
4.	2 (3)	Specimen Common Stock Certificate
4.	3	Form of common stock purchase warrant issued to various investors dated August 13, 2007 (filed as exhibit 4.1 to the Company’s Report on Form 8-K as filed with the Securities and Exchange Commission on August 16, 2007, and incorporated herein by reference)
4.	4	Registration Rights Agreement between GeoPetro Resources Company and various investors dated August 13, 2007 (filed as Exhibit B to the Form of Unit Subscription Agreement dated August 13, 2007 filed as Exhibit 10.20 to the Company’s Report on Form 8-K as filed with the Securities and Exchange Commission on August 16, 2007 and incorporated herein by reference)
4.	5 (6)	Placement Agent Warrant dated August 13, 2007
4.	6 (7)	Form of Common Stock Purchase Warrant dated as of various dates, issued to purchasers of promissory notes
4.	7(10)	Unit Subscription Agreement and Common Stock Purchase Warrant, Dated September 30, 2010.
4.	8(11)	Unit Subscription Agreement and Common Stock Purchase Warrant, Dated December 30, 2010.
10.	1 (2)	Joint Venture Agreement Bengara II, Dated January 1, 2000
10.	2 (2)	Production Sharing Contract Bengara II, Dated December 4, 1997
10.	4 (2)	Exploration Permit#408, Dated July 2, 1997
10.	5 (2)	Madisonville Field Development Agreement dated August 1, 2005
10.	6 (2)	Alaska Cook Inlet Option dated April 20, 2005
10.	7 (2)†	The 2001 Stock Incentive Plan
10.	8 (2)†	The 2004 Stock Option and Appreciation Rights Plan
10.	9 (2)†	Stuart Doshi Employment Agreement, Dated July 28, 1997 (effective July 1, 1997) and amendments dated January 11, 2001, July 1, 2003, April 20, 2004, May 9, 2005, July 28, 2005 and January 30, 2006
10.	10 (2)†	David Creel Employment Agreement, Dated April 28, 1998 and amendments dated June 15, 2000, May 12, 2003 and January 1, 2005, April, 26, 2010
10.	13 (4)	Form of Subscription Agreement for GeoPetro Resources Company stock executed by various investors on various dates.
10.	19 (5)	Shares Sale & Purchase Agreement Dated September 29, 2006
10.	20 (6)	Form of Unit Subscription Agreement Dated August 13, 2007
10.	23 (8)†	Seventh Amendment to Employment Agreement of Stuart Doshi, dated December 29, 2008
10.	24 (8)†	Eighth Amendment to Employee Agreement of Stuart Doshi, dated December 31, 2008
10.	25 (8)†	Fourth Amendment to Employment Agreement of David Creel, dated December 29, 2008
10.	26 (8)†	Fifth Amendment to Employee Agreement of David Creel, dated December 31, 2008
10.	32 (8)	Form of Promissory Note issued by GeoPetro Resources Company to various investors dated various dates from December 23, 2008 to December 26, 2008
10.	33 (9)†	Sixth Amendment to David Creel Employment Agreement dated April 28, 2009
10.	34 (12)	Promissory Note to Stuart J. Doshi dated March 20, 2012
21.	1 (1)	List of subsidiaries of GeoPetro Resources
23.	1 (1)	Consent of MHA Petroleum Consultants
23.	2 (1)	Consent of Burr Pinger Mayer, Inc.
23.	3 (1)	Consent of Hein & Associates LLP
31.	1 (1)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer.
31.	2 (1)	Rule 13a-14(a)/15d-14(a) Certification of Vice President of Finance.
32.	1 (1)	Certification of Chief Executive Officer and Vice President of Finance of GeoPetro Resources Company pursuant to 18 U.S.C. § 1350.
99.	1 (1)	Report of MHA Petroleum Consultants
101	(1)	The following materials from the GeoPetro Resources Company Form 10-K for the year ended December 31, 2012 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Consolidated Statements of Operations, (ii) the Condensed Consolidated Balance Sheets, (iii) Condensed Consolidated Statements of Cash Flows and (iv) related notes, tagged as blocks of text.

(1)	Filed herewith.
(2)	Filed as the identically numbered exhibit to the Registration Statement on Form S-1, (No. 333-135485), as filed with the Securities and Exchange Commission on June 30, 2006, and incorporated herein by reference.
(3)	Filed as the identically numbered exhibit to the Registration Statement on Form S-1, (No. 333-135485), as filed with the Securities and Exchange Commission on January 31, 2007, and incorporated herein by reference.
(4)	Filed as the Exhibit 3(ii) to the Company’s Report on Form 8-K as filed with the Securities and Exchange Commission on April 25, 2008, and incorporated herein by reference.
(5)	Filed as the identically numbered exhibit to the Registration Statement on Form S-1 (No. 333-135485), as filed with the Securities and Exchange Commission on January 9, 2007, and incorporated herein by reference.
(6)	Filed as the identically numbered exhibit to the Registration Statement on Form S-1 (No. 333-146557), as filed with the Securities and Exchange Commission on October 9, 2007, and incorporated herein by reference.
(7)	Filed as Exhibit 4.1 to the Company’s Report on Form 8-K, as filed with the Securities and Exchange Commission on January 7, 2009, and incorporated herein by reference.
(8)	Filed as the identically numbered exhibit to the Company’s Report on Form 10-K, as filed with the Securities and Exchange Commission on March 23, 2009, and incorporated herein by reference.
(9)	Filed as Exhibit 10.25 to the Form 10-Q, as filed with the Securities and Exchange Commission on May 11, 2009, and incorporated herein by reference.
(10)	Filed as Exhibits 4.1 and 4.2 to the Company’s Report on Form 8-K as filed with the Securities and Exchange Commission on October 6, 2010, and incorporated herein by reference.
(11)	Filed as Exhibits 4.1 and 4.2 to the Company’s Report on Form 8-K as filed with the Securities and Exchange Commission on March 4, 2011, and incorporated herein by reference.
(12)	Filed as the identically numbered exhibit to the Company’s Report on Form 10-K, as filed with the Securities and Exchange Commission on March 30, 2012, and incorporated herein by reference.
(13)	Filed as Exhibit 2.1 to the Company’s Report on Form 8-K as filed with the Securities and Exchange Commission on March 1, 2013, and incorporated herein by reference.
(14)	Filed as Exhibit 2.1 to the Company's Report on Form 8-K as filed with the Securities and Exchange Commission on April 10, 2013, and incorporated herein by reference.
†	Indicates a management or compensatory plan or arrangement.

EX-21.1

EXHIBIT 21.1

GeoPetro Resources Company

Subsidiary List — April 1, 2013

(Percentage ownership is indicated below)

Subsidiaries of GeoPetro Resources Company

GeoPetro Alaska LLC, an Alaska limited liability company (100%)

GeoPetro Canada Ltd., an Alberta corporation (100%)

GeoPetro International Ltd., a British Virgin Islands company (100%)

GeoPetro Pacific LLC, a Delaware limited liability company (100%)

Redwood Energy Company, a Texas corporation (100%)

South Texas GeoPetro, LLC, a Texas limited liability company (100%)

Redwood Energy Production, L.P., a Texas limited partnership (95%)

Continental-GeoPetro (Bengara II) Ltd., a British Virgin Islands company (12%)

Subsidiaries of Redwood Energy Company

Madisonville Midstream LLC, a Texas limited liability company (100%)

Redwood Energy Production, L.P., a Texas limited partnership (5%)

EX-23.1

EXHIBIT 23.1

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS

MHA Petroleum Consultants LLC does hereby consent to the use of its reports relating to the proved oil and gas reserves of GeoPetro Resources Company and to the reference to the firm as an expert in the Form 10-K Annual Report being filed by GeoPetro Resources Company.

/s/ John W. Arsenault

John W. Arsenault

Vice President

MHA Petroleum Consultants LLC

Denver, CO

April 16, 2013

EX-23.2

EXHIBIT 23.2

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the Registration Statements (No. 333-146557 and No. 333-135485) on Form S-3 of GeoPetro Resources Company of our report dated April 16, 2013, relating to our audit of the consolidated financial statements, which appears in this Annual Report on Form 10-K of GeoPetro Resources Company for the year ended December 31, 2012.

/s/ Burr Pilger Mayer, Inc.

San Francisco, California

April 16, 2013

EX-23.3

EXHIBIT 23.3

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statements (No. 333-146557 and No. 333-135485) on Form S-3 of GeoPetro Resources Company of our report dated March 30, 2012, relating to our audit of the consolidated financial statements, which appears in this Annual Report on Form 10-K of GeoPetro Resources Company for the year ended December 31, 2012.

/s/ Hein & Associates LLP

Dallas, TX

April 16, 2013

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF

CHIEF EXECUTIVE OFFICER

PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Stuart J. Doshi, certify that:

1. I have reviewed this annual report on Form 10-K of GeoPetro Resources Company;

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

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

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

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

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

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

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

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

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

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

Date: April 16, 2013	/s/ Stuart J. Doshi
	Stuart J. Doshi, President and
	Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATION OF

VICE-PRESIDENT OF FINANCE

PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Dale W. Dvoracek, certify that:

1. I have reviewed this annual report on Form 10-K of GeoPetro Resources Company;

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

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

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

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

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

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

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

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

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

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

Date: April 16, 2013	/s/ Dale W. Dvoracek
	Dale W. Dvoracek
	Vice-President of Finance

EX-32.1

EXHIBIT 32.1

CERTIFICATION

PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002*

In connection with the Annual Report of GeoPetro Resources Company (the “Company”) on Form 10-K for the period ending December 31, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), the undersigned, Stuart J. Doshi, President, Chief Executive Officer and Chairman of the Board, and Dale W. Dvoracek, Vice-President of Finance of the Company, each hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to his knowledge, that:

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

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

Dated: April 16, 2013	/s/ Stuart J. Doshi
	Stuart J. Doshi
	President, Chief Executive Officer
	and Chairman of the Board
Dated: April 16, 2013	/s/Dale W. Dvoracek
	Dale W. Dvoracek
	Vice-President of Finance

A signed original of this written statement required by Section 906 has been provided to GeoPetro Resources Company and will be retained by GeoPetro Resources Company and furnished to the Securities and Exchange Commission or its staff upon request.

* This certification is being furnished solely to accompany the Report pursuant to 18 U.S.C. Section 1350 and is not being filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and is not to be incorporated by reference into any filing of the Company, whether made before or after the date hereof, regardless of any general incorporation language in such filing.

EX-99.1

EXHIBIT 99.1

Securities and Exchange Commission Evaluation

of the Natural Gas Reserves of

Madisonville Field, Madison County, Texas

GeoPetro Resources Company

(As of December 31, 2012)

Prepared for

GeoPetro Resources Company

March 2013

MHA Petroleum Consultants LLC

730 17th Street, Suite 410 Denver, Colorado 80202  USA Telephone: 303-277-0270 Fax: 303-277-0267

March 25, 2013

Mr. Stuart Doshi

GeoPetro Resources Company

150 California Street, Suite 600

San Francisco, CA 94111

Dear Mr. Doshi:

Pursuant to your request, MHA Petroleum Consultants LLC (MHA) has prepared an estimate of the reserves and income attributable to the Madisonville Field owned by GeoPetro Resources Company (GeoPetro) as of December 31, 2012.  It is MHA’s understanding that the proved reserves estimated in this report constitute all of the proved reserves owned by GeoPetro.  The subject property is located in the state of Texas.  This report has been prepared for GeoPetro’s use in filing with the Securities and Exchange Commission (“SEC”).

The reserve and income data have been estimated using the Securities and Exchange Commission (SEC) technical guidelines, as modified at year end 2009.  Forecast oil and gas prices and all operating costs remain constant for the life of the wells.  Hydrocarbon prices used in the preparation of the report were based on the average price from the first day of the month of each month in 2012.  Reserve estimates and cash flow estimates are dependent on the pricing and cost parameters used in the report.  Future variations in the pricing and cost parameters will cause variations in the reserve and cash flow estimates reported in the evaluation.  The results of this study are summarized below.

	Gross Oil MBBLS		Gross Gas* MMCF		Net Oil MBBLS		Net Gas* MMCF		BFIT Net Income M$		Disc Net Income M$ @ 10%
Proved Developed Producing		—		—		—		—		—		—
Proved Developed Non-Producing		—		14,778.2		—		9,125.9		16,021.2		12,853.7
Proved Undeveloped		—		14,143.3		—		8,662.7		6,552.9		3,294.8
Total Proved		—		28,921.5		—		17,788.7		22,574.1		16,148.5

*Gas volumes shown in the above table represent processed, pipeline ready gas.  Net gas volumes specifically exclude volumes associated with the net profits interest (NPI) which burdens the field.

Note: Numbers in the above table may not exactly match economic output due to rounding.

The future net revenue in this report was based on net hydrocarbon volume sold multiplied by the appropriate price.  Expenses include severance and ad valorem taxes, and the normal cost of operating the wells.  Future net cash flow is future net revenue minus expenses and any development costs.  The future net cash flow has not been adjusted for outstanding loans, which may exist, nor does it include any adjustments for cash on hand or undistributed income.  No attempt has been made to quantify or otherwise account for any accumulated gas production imbalances that may exist.

Reserve Estimates

Reserve estimates included in this study were assigned on the basis of the SEC definitions (as of year-end 2009), included under the tab “Reserve Definitions”. All reserve categories assigned in this report follow the guidelines of the SEC reserve definitions. The reserve estimates included in this study were estimated by performance methods, volumetric methods and comparisons with analogous wells, where applicable. These methods were deemed appropriate for the purpose of the report.

The reserves shown in this report are estimates only and should not be construed as exact quantities.  Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible.  If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts.  Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing this report.  Estimates of reserves may increase or decrease as a result of future operations, market conditions, or changes in regulations.

1

The Company’s Natural Gas reserves for the Madisonville Field are located in Madison County, Texas, in the United States.  As of the effective date of this report, there are two wells capable of current production (the Ruby Magness #1, and Angela Farris Fannin #1), which are completed in the Rodessa “A” and Rodessa “C” limestones.  These two wells have been shut in since early 2012 at the companies election, due to low gas prices.  The Mitchell #1 well has produced, but currently needs a downhole pump.  One other well (the Wilson #1) has been drilled and is slated to begin production about September 2013.  The Rodessa zones generally contain significant natural fractures.  Additionally, at least one of the two sub-zones of the Rodessa “C” is vuggy.  The production from these zones is sour gas containing approximately 28% impurities, including a percentage of H2S.  Because of this, a plant was built near the field to strip out the impurities.  The plant was initially completed in April 2003 and is currently capable of normal operation, and can treat approximately 20 MMcfpd of raw gas.  The plant is slated to undergo a modification to increase the processing capacity to 30 MMcfpd.  This modification is projected to be completed by July 2013.  Historical fuel use for the plant has been approximately 10-12% of the produced gas, and this fuel use percentage has been projected for the time period from January 2013 through June 2013.  Following the planned modification to the plant (and due to higher throughput), there will be a reduced need for fuel gas due to operating efficiencies.  Therefore, as of July 2013, the fuel use has been reduced to approximately 7% of the produced gas.

In order to capitalize on the Madisonville Field Rodessa gas reserves, the Company has developed a plan to treat the Madisonville Project natural gas and has purchased the gas plant which treats the produced gas.  Following treatment, the gas is transported by Gateway Processing Company (“Gateway”) approximately nine miles west to the Atmos pipeline or the ETC Katy pipeline.

The Company has a 100% working interest in approximately 56% (areally) of the Madisonville Field, and a 100% working interest in all existing and future wells has been used for the economic projections.  The net revenue interest (NRI) to the Company is 75.13% in the Ruby Magness #1 well, 69.9% in the Fannin well, and 70.0% in the remaining wells, the Mitchell #1, the Wilson #1, and PUD #1.  There is a net profits interest (NPI) of 12.5% burdening the field, which increases to 30% when the Company has recouped all capital costs plus a 33% cash on cash return.

The natural gas reserves for the Madisonville field were estimated volumetrically, based upon seismic data and well log information.  Volumetric reserves were estimated using the net pay encountered in the existing wellbores along with the structure of the formation from the seismic data.  Reservoir thickness was estimated using log data.  Reservoir rock and fluid property data were obtained from well logs, PVT data, gas analyses, and published information.  Reservoir pressures were derived from pressure surveys, daily flowing tubing pressure measurements and published reports.  Additionally, the Ruby Magness #1 well has a capillary string for the injection of chemicals — this string is also used to monitor pressure.  Recovery factors for gas reserves were estimated by taking into consideration well depths, deliverability characteristics, product prices, assumed abandonment pressures, and operating cost information.  The natural gas reserves are presented in millions of cubic feet at standard conditions of 14.65 psia and 60 degrees Fahrenheit.

Forecasts of net revenue were prepared by predicting annual production from the reserves and product prices. Annual production was forecasted taking into account historical production trends, planned equipment upgrades, applicable regulatory conditions, and existing or anticipated contract rates.

Note that reserves were assigned only to those lands directly under GeoPetro owned leases.

Prices and Costs

The hydrocarbon prices used in the report were based on the average prices from the first day of the twelve calendar months in 2012, per SEC regulations.  Adjustments were made to this price based on differentials to the posted prices due to hydrocarbon quality, transportation fees, contract terms, etc.  All hydrocarbon prices were held constant for the life of the properties with no future escalation.

Oil and condensate prices were not relevant to the report, as there is no oil production from the Rodessa Formation in the Madisonville Field.

Natural gas prices were based on the actual average Houston Ship Channel price received by GeoPetro on the first day of each month of 2012, which was $2.46 per MMBTU.  This price has been adjusted for gas quality, contractual agreements, transportation and marketing fees, shrinkage and regional price variations.  The gas being produced has a heating value of approximately 1000 BTU per cubic foot.

2

Operating costs used in the report were provided by GeoPetro and were estimated at approximately $7,660 per producing well per month going forward.  All operating costs were held constant over the life of the properties with no future escalation.  Plant operating expenses were applied in accordance with average values over the past 12 months, adjusted for known treatment modifications.  Gas treatment fees are collected from the royalty owners in accordance with recently executed contractual agreements.  Transportation fees are also paid to Gateway.  The methodology is approximately summarized as follows:

·Gathering, Processing and Marketing Fees (paid to GeoPetro by the royalty owners):

All gas $1.31 per Mcf inlet gas

·Transportation Fees

All gas $0.10 per Mcf outlet gas

·Plant Costs

Approx. fixed monthly base costs	$207,250 (volumes up to 18 MMcfpd)
	$250,000 (volumes between 18-20 MMcfpd)
	$275,000 (volumes over 20 MMcfpd)

These costs were not independently verified by MHA, but were checked for reasonableness.

Development costs for the PUD well have been estimated at approximately $4.2 million.  GeoPetro does have plans to fracture treat the Wilson #1 well in 2013 and lay gathering lines to the plant. These costs have been estimated at $1,445,000.  Additionally, a cost of $650,000 was included to install a submersible pump into the Mitchell #1 well.  The cost to modify the plant to increase the throughput was estimated at $4,000,000 and included in July 2013.  Abandonment costs for the wells have been forecast at $15,000 each, including the waste disposal well on the property.  An additional $500,000 was added for the cost of abandoning the gas plant.  These costs were not independently verified by MHA, but were checked for reasonableness.

No deductions were made for indirect costs such as loan repayments, interest expenses, and exploration and development prepayments.

Following is the procedure used in calculating the economics for the production streams:

1) Gas production streams from rate analysis were adjusted for GeoPetro lease ownership and then adjusted for shrinkage.  A shrinkage factor of approximately 40% was applied to future gas production prior to the plant modification (28% impurities plus 12% fuel use).  Subsequent to the plant upgrade, the shrinkage factor used was 35% (28% impurities, 7% fuel).  Gross revenue was calculated based on this adjusted stream, using the constant gas price.

2) Net revenue was calculated based on a 100% working interest to the Company, and a 75.13% net revenue interest (NRI) in the Ruby Magness #1 well, a 69.9% NRI in the Angela Farris Fannin #1 well, and a 70.0% NRI in the Wilson #1, Mitchell #1 and PUD#1 wells.

3) Severance taxes were applied at 7.5% of the gas revenue net of gas treatment costs.  Note that the Company has a 10 year moratorium on severance taxes for the Ruby Magness #1 well.

4) Operating expenses (including ad valorem tax) were deducted at the rates stated above.

5) A net profits interest (NPI) was deducted from the revenue stream.  The amount of the NPI is 12.5% of the net operating profits until payout is achieved.  After payout, the NPI increases to 30%.  Payout is defined and achieved at such time as the Company has recouped from net operating cash flows its total net investment in the project plus a 33% cash on cash return.

6) Capital expenditures are applied and net cash flow determined.

A one line summary showing each of the cases is included under the tab “One Line Summary”, and a detailed output by year is included under the tab titled “Summary Economics and Plots”.  Plots for each case are also presented under the same tab.

3

Statement of Risk

The accuracy of reserve and economic evaluations is always subject to uncertainty.  The magnitude of this uncertainty is generally proportional to the quantity and quality of data available for analysis.  As a well matures and new information becomes available, revisions may be required which may either increase or decrease the previous reserve assignments.  Sometimes these revisions may result not only in a significant change to the reserves and value assigned to a property, but also may impact the total company reserve and economic status.  The reserves and forecasts contained in this report were based upon a technical analysis of the available data using accepted engineering principles.  However, they must be accepted with the understanding that further information and future reservoir performance subsequent to the date of the estimate may justify their revision.  It is also possible that current or future regulation may have an impact on the reserves, or the company’s ability to produce these reserves.

It is MHA’s opinion that the estimated proven reserves and other reserve information as specified in this report are reasonable, and have been prepared in accordance with generally accepted petroleum engineering and evaluation principles, as set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserve Information, promulgated by the Society of Petroleum Engineers.  Notwithstanding the aforementioned opinion, MHA makes no warranties concerning the data and interpretations of such data.  In no event shall MHA be liable for any special or consequential damages arising from GeoPetro’s use of MHA’s interpretation, reports, or services produced as a result of its work for GeoPetro.

Neither MHA, nor any of our employees have any interest in the subject properties and neither the employment to do this work, nor the compensation, is contingent on our estimates of reserves for the properties in this report.

This report was prepared for the exclusive use of GeoPetro and will not be released by MHA to any other parties without GeoPetro’s written permission.  The data and work papers used in the preparation of this report are available for examination by authorized parties in our offices.

It was a pleasure performing this work for GeoPetro.  If you have any questions regarding this evaluation or if additional information is needed, please contact the undersigned at this office.

Sincerely,

/s/ John W. Arsenault

John W. Arsenault

Vice President

/s/ Dennis P. Holler

Dennis P. Holler

Senior Geological Associate

4

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Note 6 - Income Taxes (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012
Effective Income Tax Rate, Continuing Operations	35.00%
Operating Loss Carryforwards	$ 39,500,000
Tax Credit Carryforward, Amount	318,264
Portion of Federal NOL Not Benefited for Financial Statement Purposes [Member]
Operating Loss Carryforwards	3,536,000
California [Member]
Operating Loss Carryforwards	12,430,000
Alaska [Member]
Operating Loss Carryforwards	$ 670,000

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited) (Detail) - Proved Developed and Undeveloped Reserves	12 Months Ended
	Dec. 31, 2012 MMcf	Dec. 31, 2011 MMcf	Dec. 31, 2010 MMcf
Balance	17,789	18,889	18,308
Revisions of previous estimates	(984)	791
Production	(116)	(210)

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Note 9 - Common Stock Warrants (Detail) (USD $)	1 Months Ended	3 Months Ended	12 Months Ended												1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended	1 Months Ended		1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended				1 Months Ended	12 Months Ended						1 Months Ended	12 Months Ended				1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended				1 Months Ended	12 Months Ended	2 Months Ended	12 Months Ended	2 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended					1 Months Ended	12 Months Ended				1 Months Ended	12 Months Ended						12 Months Ended
	May 31, 2012	Oct. 31, 2009	Dec. 31, 2012	Dec. 31, 2011	Feb. 28, 2011	Dec. 31, 2010	Jun. 30, 2009	May 31, 2009	Dec. 31, 2008	May 31, 2012 Original [Member] Extended Warrants [Member]	May 31, 2012 New [Member] Extended Warrants [Member]	Dec. 31, 2012 Expiration on 02/22/12 [Member]	Feb. 22, 2012 Expiration on 02/22/12 [Member]	Dec. 31, 2011 Expiration on 02/22/12 [Member]	Mar. 31, 2012 Expiration on 03/20/15 [Member]	Dec. 31, 2012 Expiration on 03/20/15 [Member]	Mar. 31, 2012 Expiration on 03/21/15 [Member]	Dec. 31, 2012 Expiration on 03/21/15 [Member]	Feb. 28, 2011 Extended Warrants [Member]	May 31, 2012 Extended Warrants [Member]	May 31, 2012 Expiration on 05/30/15 [Member]	Dec. 31, 2012 Expiration on 05/30/15 [Member]	Jun. 30, 2012 Expiration on 06/29/15 [Member]	Dec. 31, 2012 Expiration on 06/29/15 [Member]	Jul. 31, 2012 Expiration on 07/31/15 [Member]	Dec. 31, 2012 Expiration on 07/31/15 [Member]	Dec. 31, 2012 Expiration on 08/13/12 [Member]	Aug. 13, 2012 Expiration on 08/13/12 [Member]	Dec. 31, 2011 Expiration on 08/13/12 [Member]	Aug. 31, 2012 Expiration on 08/15/16 [Member]	Dec. 31, 2012 Expiration on 08/15/16 [Member]	Dec. 31, 2012 Expiration on 09/30/12 [Member]	Sep. 30, 2012 Expiration on 09/30/12 [Member]	Dec. 31, 2011 Expiration on 09/30/12 [Member]	Oct. 31, 2012 Expiration on 10/01/17 Grant 1 [Member] Minimum [Member]	Oct. 31, 2012 Expiration on 10/01/17 Grant 1 [Member] Maximum [Member]	Oct. 31, 2012 Expiration on 10/01/17 Grant 1 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 1 [Member]	Dec. 31, 2012 Expiration on 10/22/12 [Member]	Oct. 31, 2012 Expiration on 10/22/12 [Member]	Dec. 31, 2011 Expiration on 10/22/12 [Member]	Nov. 30, 2012 Expiration on 11/20/15 [Member]	Dec. 31, 2012 Expiration on 11/20/15 [Member]	Nov. 30, 2012 Expiration on 11/21/15 [Member]	Dec. 31, 2012 Expiration on 11/21/15 [Member]	Dec. 31, 2012 Expiration on 11/22/12 [Member]	Nov. 30, 2012 Expiration on 11/22/12 [Member]	Dec. 31, 2011 Expiration on 11/22/12 [Member]	Nov. 30, 2012 Expiration on 11/29/15 [Member]	Dec. 31, 2012 Expiration on 11/29/15 [Member]	Dec. 31, 2012 Expiration on 12/04/15 [Member]	Dec. 31, 2012 Expiration on 12/04/15 [Member]	Dec. 31, 2012 Expiration on 12/31/15 [Member]	Dec. 31, 2012 Expiration on 12/31/15 [Member]	Mar. 31, 2012 Expiration on 03/01/14 [Member]	Dec. 31, 2011 Expiration on 03/01/14 [Member]	Dec. 31, 2012 Expiration on 03/01/14 [Member]	Apr. 30, 2011 Expiration on 04/28/14 [Member]	Dec. 31, 2011 Expiration on 04/28/14 [Member]	Dec. 31, 2012 Expiration on 04/28/14 [Member]	Dec. 31, 2012 Expiration on 01/02/14 [Member]	Dec. 31, 2011 Expiration on 01/02/14 [Member]	Aug. 31, 2011 Expiration on 01/02/14 [Member]	Sep. 30, 2011 Expiration on 08/31/14 [Member]	Dec. 31, 2011 Expiration on 08/31/14 [Member]	Dec. 31, 2012 Expiration on 08/31/14 [Member]	Dec. 31, 2011 Expiration on 09/30/11 [Member]	Sep. 30, 2011 Expiration on 09/30/11 [Member]	Nov. 30, 2011 Expiration on 11/30/13 [Member]	Dec. 31, 2011 Expiration on 11/30/13 [Member]	Dec. 31, 2012 Expiration on 11/30/13 [Member]	Dec. 31, 2011 Expiration on 12/15/11 [Member]	Dec. 15, 2011 Expiration on 12/15/11 [Member]	Dec. 31, 2011 Expiration on 12/22/11 [Member]	Dec. 22, 2011 Expiration on 12/22/11 [Member]	Dec. 31, 2012 Minimum [Member]	Dec. 31, 2011 Minimum [Member]	Dec. 31, 2012 Maximum [Member]	Dec. 31, 2011 Maximum [Member]	Mar. 31, 2012 Stuart Doshi Loan One [Member]	May 31, 2012 Stuart Doshi Loan Two [Member]	Jun. 30, 2012 Stuart Doshi Loan Three [Member]	Jul. 31, 2012 Stuart Doshi Loan Four [Member]	Nov. 30, 2012 Stuart Doshi Loan Five [Member]	Dec. 31, 2012 Stuart Doshi Loan Six [Member]
			750,779	176,150								50,000	50,000														600,779	600,779				14,000	14,000						36,000	36,000						50,000	50,000																				27,150	27,150				114,000	114,000	35,000	35,000
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per Item)						0.50	1.00	1.00		1.00	0.50	1.00	1.00	1.00	0.50	0.50	0.50	0.50			0.50	0.50	0.50	0.50	0.50	0.50	4.50	4.50	4.50	0.50	0.50	1.00	1.00	1.00	0.10	0.23		0.23	1.00	1.00	1.00	0.50	0.50	0.50	0.50	1.25	1.25	1.25	0.50	0.50	0.50	0.50	0.50	0.50	0.75	0.75	0.75	1.00	1.00	1.00	1.00	1.00		0.50	0.50	0.50	1.00	1.00	0.50	0.50	0.50	3.50	3.50	1.00	1.00
Number of Warrants Issued		47,500	1,310,000	1,568,129											20,000	20,000	500,000	500,000			15,000	10,000	45,000	20,000	15,000	13,000				45,000	45,000						72,000	12,000				12,000	10,000	30,000	30,000				50,000	50,000	6,000	6,000	500,000	375,000	1,025,164	1,025,164		505,965	505,965					10,000	10,000				27,000	27,000
Notes Payable, Related Parties (in Dollars)					$ 125,000																																																																											$ 100,000	$ 75,000	$ 225,000	$ 75,000	$ 60,000	$ 30,000
Warrants and Rights Outstanding (in Dollars)		24,162				16,662	7,537		122,764						1,609		40,070		7,788	3,575	561		1,481		315					2,986							5,887					413		1,014					1,452		141	141	18,429	18,429	207,943			165,105					17,539	2,204					3,170
Class of Warrant or Right, Outstanding																			151,500	151,500																																											150,000
Number of Notes Payable Extended	7																		7
Other Notes Payable (in Dollars)	$ 1,515,000	$ 50,000
Fair Value Assumptions, Expected Dividend Rate			0.00%	0.00%
Fair Value Assumptions, Expected Volatility Rate																																																																												81.00%	78.00%	137.00%	140.00%
Fair Value Assumptions, Risk Free Interest Rate																																																																												0.27%	0.23%	0.80%	1.15%
Fair Value Assumptions, Expected Term																																																																												3 years	2 years	5 years	3 years

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited) (Detail) - Proved Developed and Undeveloped Reserves	Dec. 31, 2012 MMcf	Dec. 31, 2011 MMcf	Dec. 31, 2010 MMcf
Proved developed		2,453
Proved developed non-producing	9,126	7,328
Proved undeveloped	8,663	9,108
Total	17,789	18,889	18,308

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Note 8 - Common Stock Options (Detail) - Stock option valuation assumptions (USD $)	1 Months Ended	12 Months Ended
	Aug. 31, 2012	Dec. 31, 2012	Dec. 31, 2011
Expected volatility		105.60%	149.80%
Risk-free interest rates		0.59%	0.99%
Expected lives (years)		5 years	5 years
Weighted average fair values per share (in Dollars per share)	$ 0.14	$ 0.11	$ 0.27

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Note 4 - Summary of Oil and Gas Operations (Detail) - Capitalized costs (USD $)	Dec. 31, 2012	Dec. 31, 2011
Proved properties	$ 53,090,943	$ 52,977,232
Unproved properties	6,524,819	6,931,499
Gas processing plant	5,533,910	5,533,910
Less—accumulated depletion and impairment	(41,625,269)	(40,823,082)
Net capitalized costs	23,524,403	24,619,559
United States [Member]
Proved properties	46,621,800	47,128,745
Unproved properties	4,635,781	4,486,744
Gas processing plant	5,533,910	5,533,910
Less—accumulated depletion and impairment	(35,156,126)	(34,974,595)
Net capitalized costs	21,635,365	22,174,804
Australia [Member]
Proved properties	2,388,051	2,388,051
Unproved properties	1,522,718	1,522,718
Less—accumulated depletion and impairment	(2,388,051)	(2,388,051)
Net capitalized costs	1,522,718	1,522,718
Indonesia [Member]
Proved properties	1,361,817	774,777
Unproved properties		587,040
Less—accumulated depletion and impairment	(1,361,817)	(774,777)
Net capitalized costs		587,040
Canada [Member]
Proved properties	2,719,275	2,685,659
Unproved properties	366,320	334,997
Less—accumulated depletion and impairment	(2,719,275)	(2,685,659)
Net capitalized costs	$ 366,320	$ 334,997

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited) (Detail) - Changes in the Standardized Measure of Discounted Futures Net Cash Flows from Proved Petroleum and Natural Gas Reserve Quantities (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Balance, beginning of period	$ 32,619	$ 29,102
Balance, end of period	16,148	32,619
Sales of oil and gas, net	(877)	(1,509)
Net change in prices and production costs	(16,452)	6,121
Net change in future development costs		(2,760)
Revisions of previous quantity estimates	(1,325)	1,698
Accretion of discount	3,674	2,505
Other	$ (1,491)	$ (2,538)

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Note 9 - Common Stock Warrants (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Stockholders' Equity Note, Warrants or Rights [Table Text Block]

Expiration	Exercise		Outstanding at		Warrants		Warrants		Warrants			Outstanding at
Date	Price		12/31/2011		Exercised		Granted		(Expired/Canceled)			12/31/2012
02/22/12	$	1.00		50,000		—		—		(50,000	)		—
08/13/12	$	4.50		600,779		—		—		(600,779	)		—
09/30/12	$	1.00		14,000		—		—		(14,000	)		—
10/22/12	$	1.00		36,000		—		—		(36,000	)		—
11/22/12	$	1.25		50,000		—		—		(50,000	)		—
08/31/13	$	0.50		23,000		—		—		—			23,000
09/29/13	$	0.75		1,847,500		—		—		—			1,847,500
10/31/13	$	0.50		72,000		—		—		—			72,000
11/30/13	$	0.50		27,000		—		—		—			27,000
12/23/13	$	0.50		120,000		—		—		—			120,000
12/25/13	$	0.50		40,000		—		—		—			40,000
12/30/13	$	0.75		555,596		—		—		—			555,596
01/02/14	$	1.00		150,000		—		—		—			150,000
03/01/14	$	0.75		1,025,164		—		—		—			1,025,164
03/31/14	$	5.25		100,000		—		—		—			100,000
04/28/14	$	1.00		505,965		—		—		—			505,965
05/17/14	$	0.50		36,500		—		—		—			36,500
06/29/14	$	0.50		30,000		—		—		—			30,000
08/31/14	$	0.50		10,000		—		—		—			10,000
10/19/14	$	1.00		130,540		—		—		—			130,540
03/20/15	$	0.50		—		—		20,000		—			20,000
03/21/15	$	0.50		—		—		500,000		—			500,000
05/29/15	$	0.50		—		—		5,000		—			5,000
05/30/15	$	0.50		—		—		10,000		—			10,000
06/04/15	$	0.50		—		—		8,000		—			8,000
06/18/15	$	0.50		—		—		5,000		—			5,000
06/25/15	$	0.50		—		—		12,000		—			12,000
06/29/15	$	0.50		—		—		20,000		—			20,000
07/27/15	$	0.50		—		—		2,000		—			2,000
07/31/15	$	0.50		—		—		13,000		—			13,000
11/09/15	$	0.50		—		—		2,000		—			2,000
11/20/15	$	0.50		—		—		10,000		—			10,000
11/21/15	$	0.50		—		—		30,000		—			30,000
11/29/15	$	0.50		—		—		50,000		—			50,000
12/04/15	$	0.50		—		—		6,000		—			6,000
12/10/15	$	0.50		—		—		125,000		—			125,000
12/31/15	$	0.50		—		—		375,000		—			375,000
08/15/16	$	0.50		—		—		45,000		—			45,000
10/01/17	$	0.23		—		—		12,000		—			12,000
10/01/17	$	0.21		—		—		12,000		—			12,000
10/01/17	$	0.20		—		—		12,000		—			12,000
10/01/17	$	0.17		—		—		12,000		—			12,000
10/01/17	$	0.14		—		—		12,000		—			12,000
10/01/17	$	0.10		—		—		12,000		—			12,000
				5,424,044		—		1,310,000		(750,779	)		5,983,265

Expiration	Exercise		Outstanding at		Warrants		Warrants		Warrants			Outstanding at
Date	Price		12/31/2010		Exercised		Granted		(Expired/Canceled)			12/31/2011
09/30/11	$	1.00		27,150		—		—		(27,150	)		—
12/15/11	$	3.50		114,000		—		—		(114,000	)		—
12/22/11	$	1.00		35,000		—		—		(35,000	)		—
02/22/12	$	1.00		50,000		—		—		—			50,000
08/13/12	$	4.50		600,779		—		—		—			600,779
09/30/12	$	1.00		14,000		—		—		—			14,000
10/22/12	$	1.00		36,000		—		—		—			36,000
11/22/12	$	1.25		50,000		—		—		—			50,000
12/23/12	$	1.00		45,000		—		—		—			45,000
12/25/12	$	1.00		40,000		—		—		—			40,000
05/17/13	$	1.00		36,500		—		—		—			36,500
06/29/13	$	1.00		30,000		—		—		—			30,000
08/31/13	$	0.50		23,000		—		—		—			23,000
09/29/13	$	0.75		1,847,500		—		—		—			1,847,500
10/31/13	$	0.50		72,000		—		—		—			72,000
11/30/13	$	0.50		—		—		27,000		—			27,000
12/23/13	$	0.50		75,000		—		—		—			75,000
12/30/13	$	0.75		555,596		—		—		—			555,596
01/02/14	$	1.00		150,000		—		—		—			150,000
03/01/14	$	0.75		—		—		1,025,164		—			1,025,164
03/31/14	$	5.25		100,000		—		—		—			100,000
04/28/14	$	1.00		—		—		505,965		—			505,965
08/31/14	$	0.50		—		—		10,000		—			10,000
10/19/14	$	1.00		130,540		—		—		—			130,540
				4,032,065		—		1,568,129		(176,150	)		5,424,044

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Note 10 - Commitments and Contingencies (Detail) (USD $)	1 Months Ended	12 Months Ended			12 Months Ended					12 Months Ended
	Jun. 30, 2012	Dec. 31, 2012	Dec. 31, 2011	Jan. 06, 2011	Dec. 31, 2012 Stuart J Doshi [Member] Amended Contract Term [Member]	Dec. 31, 2012 Stuart J Doshi [Member] Renewal Term [Member]	Dec. 31, 2012 Madisonville [Member]	Feb. 15, 2010 Principal Executive Office [Member]	Jan. 06, 2011 Sublease [Member]	Dec. 31, 2012 Before Payout [Member]	Dec. 31, 2012 After Payout [Member]
Employment Agreement Term					5 years	2 years
Annual Base Salary Pursuant to the Employment Agreement (in Dollars)		$ 300,000
Additional Cash Payment Representing Employment Benefit as Percentage of Salary		20.00%
Operating Lease Term								84 months	75 months
Operating Leases, Rent Expense (in Dollars)		144,834	144,834
Percent of Base Rental Obligation				50.00%
Operating Leases, Income Statement, Sublease Revenue (in Dollars)		$ 82,419	$ 67,289
Acquired Working Interest in Oil and Gas Project, Percent	2/3						100%
Net Profits Interest as Percentage of Net Operating Profits from Madisonville										12.50%	30.00%
Percentage of Cash on Cash Return		33.00%

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Note 6 - Income Taxes (Detail) - Significant components of the Company’s deferred tax assets (liabilities) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Deferred tax assets (liabilities)
Net operating loss carry forwards	$ 14,150,000	$ 12,127,000
Oil and gas property basis differences	3,662,000	3,480,000
Stock compensation	793,000	633,000
Other	(990,000)	(726,000)
Total deferred tax assets	17,615,000	15,514,000
Valuation allowance	$ (17,615,000)	$ (15,514,000)

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Note 5 - Debt (Detail) - Table of Debt (USD $)	Dec. 31, 2012		Dec. 31, 2011
Current Portion
Net current notes payable	$ 1,509,950		$ 1,197,385
Long Term
Net Long term notes payable	1,644,427		1,423,707
Total	3,154,378		2,621,092
Related Party Notes [Member]
Current Portion
Related party notes (a)	565,000	[1]		[1]
Promissory Notes 12/08 [Member]
Current Portion
Current notes payable		[2]	850,000	[2]
Long Term
Long term notes payable	850,000	[2]		[2]
Promissory Notes 06/09 [Member]
Current Portion
Current notes payable		[3]	300,000	[3]
Long Term
Long term notes payable	300,000	[3]		[3]
Bridge Notes 08/10, 10/10 [Member]
Current Portion
Current notes payable	900,000	[4]		[4]
Long Term
Long term notes payable		[4]	900,000	[4]
Promissory Notes 09/10 [Member]
Current Portion
Current notes payable	75,000	[5]	75,000	[5]
Long Term
Long term notes payable	150,000	[5]	225,000	[5]
Current [Member]
Current Portion
Less discount on promissory notes payable	(30,050)		(27,615)
Promissory Notes 05/09 [Member]
Long Term
Long term notes payable	365,000	[6]	365,000	[6]
Non-Current [Member]
Current Portion
Less discount on promissory notes payable	$ (20,573)		$ (66,293)

[1] In February 2011, Stuart J. Doshi, President and CEO, advanced to the Company a loan in the amount of $125,000 which was payable on demand. The note bears an annual rate of eight percent (8%) interest. In September 2011, the outstanding principal of $125,000 and the accrued interest thereon were paid in full. During the year ended December 31, 2012, Stuart J. Doshi, President and CEO, advanced to the Company twelve loans totaling $565,000 which are payable on demand. The notes bear an annual rate of ten percent (10%), with such interest payable quarterly in arrears. These notes are secured by a first position deed of trust against the Company's improved real property located in Madison County, Texas, commonly known as the Madisonville Gas Processing Plant site. In connection with these notes, the Company issued 113,000 warrants to purchase our common stock. The fair value of the warrants issued was $4,520 (Note 9), which has been recorded as a debt discount and will be amortized over the life of the note. Since these notes are payable on demand, the debt discount has been fully amortized in 2012. Interest expense accrued on these notes for the year ended December 31, 2012 was $28,083.

[2] In December 2008, the Company issued four promissory notes totaling $1,050,000 with maturity dates in December 2011. The notes may be repaid at any time without penalty. The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears. In connection with the notes, the Company paid loan origination fees totaling $6,000 and granted three-year exercisable warrants to purchase 105,000 Common Shares and reissued 15,000 warrants at $1.00 per share. We also issued 150,000 warrants as a finder's fee. The fair value of the warrants on the dates of issuance of $122,764 and the $6,000 of loan origination fees, were recorded as a debt discount and have been amortized over the life of the promissory notes. In February 2011, we extended the maturity on three separate notes totaling $850,000 to December 2012. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year. The fair value associated with the warrant extension was $4,370 (Note 9), which has been recorded as a debt discount and has been amortized over the extended life of the notes. In December 2011, one of the four original promissory notes for $200,000, and the accrued interest thereon, was paid in full. In May 2012, we extended the maturity on the three remaining notes totaling $850,000 to January 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $1,766 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $1,736.

[3] In June 2009, the Company issued two promissory notes totaling $300,000 with maturity dates in June 2010. The notes may be repaid at any time without penalty. The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears. In connection with the notes, the Company granted three-year exercisable warrants to purchase 30,000 Common Shares at $1.00 per share. The fair value of the warrants on the date of issuance of $7,537 was recorded as a debt discount and has been amortized over the life of the promissory notes. In March 2010, these two notes were extended for an additional one year and the new maturity was June 2011. In February 2011, we extended the maturity on the notes to June 2012. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these two notes for an additional year. The fair value associated with the warrant extension was $1,542 (Note 9), which has been recorded as a debt discount and has been amortized over the extended life of the notes. In May 2012, we extended the maturity on the notes to January 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $839 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $574.

[4] During August through October 2009, the Company borrowed an aggregate of $950,000 pursuant to four separate bridge loans with maturity dates in August 2010 and October 2010. The notes may be repaid at any time without penalty. The notes bear an annual rate of ten percent (10%), with such interest payable at maturity. In connection with the issuance of these notes we issued 47,500 warrants to purchase our common stock. The fair value of the warrants on the dates of issuance of $24,162 was recorded as a debt discount and has been amortized over the life of the promissory notes. During August through October 2010, we partially repaid a promissory note in the amount of $50,000. We renewed three promissory notes totaling $180,000 with new maturity dates of August 2011 and renewed one promissory note in the amount of $720,000 with a new maturity date of October 2011. Prior to the note renewals we repaid all outstanding accrued interest on the notes. The terms of the renewed notes payable remain materially consistent those previously issued. In connection with the issuance of these notes we issued a total of 95,000 warrants to purchase our common stock and recorded $36,000 in renewal fees. The fair value of the warrants on the date of issuance of $23,286, and the $36,000 renewal fees, were recorded as a debt discount and have been amortized over the life of the promissory notes. During August through October 2011, we renewed three promissory notes totaling $180,000 with new maturity dates of August 2013 and renewed one promissory note in the amount of $720,000 with a new maturity date of October 2013. Prior to the note renewals we repaid all outstanding accrued interest on the notes. The terms of the renewed notes payable remain materially consistent those previously issued. In connection with the issuance of these notes we issued a total of 37,000 warrants to purchase our common stock and recorded $27,000 in renewal fees. The fair value of the warrants on the date of issuance of $5,374 (Note 9), and the $27,000 renewal fees, were recorded as a debt discount and are being amortized over the life of the promissory notes. As of December 31, 2012 the unamortized portion of the debt discount was $12,803.

[5] In September 2010, we issued a 5-year non-interest bearing note payable in the amount of $375,000 in connection with the execution of a settlement agreement. Payments are due as follows: $25,000 in March 2011, $50,000 in October 2011, and $75,000 each October thereafter until 2015. Payments totaled $75,000 in the year ended December 31, 2011 and $75,000 in the year ended December 31, 2012. An imputed interest rate of 10% per annum has been used to record a discount in connection with this note of $90,116, and is being amortized over the life of the note. As of December 31, 2012 the unamortized portion of the debt discount was $33,836.

[6] In May 2009, the Company issued two promissory notes totaling $365,000 with maturity dates in May 2012. The notes may be repaid at any time without penalty. The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears. In connection with the notes, the Company granted three-year exercisable warrants to purchase 36,500 Common Shares at $1.00 per share. The fair value of the warrants on the dates of issuance of $12,724 was recorded as a debt discount and has been amortized over the life of the promissory notes. In February 2011, we extended the maturity of the notes to May 2013. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these two notes for an additional year. The fair value associated with the warrant extension was $1,876 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. In May 2012, we extended the maturity on the notes to May 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $971 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $1,674.

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Note 11 - Subsequent Events (Detail) (USD $)	1 Months Ended				3 Months Ended	12 Months Ended			1 Months Ended
	Dec. 31, 2010	Jun. 30, 2009	May 31, 2009	Dec. 31, 2008	Oct. 31, 2009	Dec. 31, 2012	Dec. 31, 2011	Feb. 28, 2011	Jan. 31, 2013 Subsequent Event [Member] January 2013 Private Placement [Member]	Jan. 31, 2013 Subsequent Event [Member] Rescind Unit Subscription Agreement [Member]	Feb. 28, 2013 Subsequent Event [Member] February 2013 Private Placement [Member]	Apr. 30, 2013 Subsequent Event [Member] Stuart J Doshi [Member]	Mar. 31, 2013 Subsequent Event [Member] Stuart J Doshi [Member]	Mar. 31, 2013 Subsequent Event [Member] March 2013 Private Placement [Member]	Jan. 31, 2013 Subsequent Event [Member] Stuart J Doshi [Member]	Apr. 30, 2013 Subsequent Event [Member] Stuart J Doshi [Member]	Mar. 31, 2013 Subsequent Event [Member] Stuart J Doshi [Member]	Jan. 31, 2013 Subsequent Event [Member] Maturity Date July 2014 [Member]
Notes Payable, Related Parties (in Dollars)								$ 125,000							$ 5,000	$ 55,000	$ 85,000
Debt Instrument, Interest Rate, Stated Percentage	6.00%	8.00%	8.00%	8.00%	10.00%	10.00%		8.00%							10.00%	10.00%	10.00%
Number of Warrants Issued					47,500	1,310,000	1,568,129		662,500	500,000	612,500	11,000	17,000	250,000	1,000
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per Item)	0.50	1.00	1.00						0.50	0.50	0.50	0.50	0.50	0.50	0.50
Warrant Term	3 years	3 years	3 years	3 years					3 years	3 years	3 years	3 years	3 years	3 years	3 years
Equity Issuance, Per Share Amount (in Dollars per share)									$ 0.10	$ 0.25	$ 0.10			$ 0.10
Proceeds from Issuance or Sale of Equity (in Dollars)									132,500	250,000	122,500			50,000
Stock Issued During Period, Shares, New Issues									1,325,000	1,000,000	1,225,000			500,000
Notes Payable (in Dollars)						$ 3,154,378	$ 2,621,092											$ 250,000

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Note 8 - Common Stock Options (Detail) - Options outstanding (USD $)				12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012 Exercise Prices $0.16 [Member]	Dec. 31, 2012 Exercise Prices $0.50 [Member]	Dec. 31, 2012 Exercise Prices $1.00 [Member]	Dec. 31, 2012 Exercise Prices $2.10 [Member]
Number of options outstanding	3,445,000	2,770,000	2,895,000	675,000	960,000	210,000	1,600,000
Number of options exercisable	2,461,000				675,000	186,000	1,600,000
Exercise prices (in Dollars per share)				$ 0.16	$ 0.50	$ 1.00	$ 2.10
Weighted average remaining contractual life				4 years 244 days	361 days	248 days	142 days

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Note 3 - Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2012

Significant Accounting Policies [Text Block]

3.         SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

U.S. GAAP—The Company’s financial statements have been prepared in accordance with accounting principles generally accepted within the United States of America (“U.S. GAAP”).

Use of Estimates and Significant Estimates—Certain amounts in GeoPetro’s financial statements are based upon significant estimates, including oil and gas reserve quantities which form the basis for the calculation of depreciation, depletion, amortization and impairment of oil and gas properties, the carrying values of unproved properties, asset retirement obligations, accounting for business combinations and share-based payments, and a provision for income taxes. Actual results could materially differ from those estimates.

Oil and Gas Properties—GeoPetro follows the full cost method of accounting for oil and gas producing activities and, accordingly, capitalizes all costs incurred in the acquisition,  exploration, and development of proved oil and gas properties, including the costs of abandoned properties, dry holes, geophysical costs, and annual lease rentals. All general corporate costs are expensed as incurred. In general, sales or other dispositions of oil and gas properties are accounted for as adjustments to capitalized costs, with no gain or loss recorded. Costs incurred for repairs and maintenance are expensed as incurred. Amortization of proved oil and gas properties is computed on the units of production method based on all proved reserves on a country by country basis. Unproved oil and gas properties are assessed for impairment either individually or on an aggregate basis. The net capitalized costs of proved oil and gas properties (full cost ceiling limitation) are not to exceed their related estimated future net revenues discounted at 10%, and the lower of cost or estimated fair value of unproved properties, net of tax considerations.

Asset Impairment—Under full cost accounting, a ceiling test is performed to ensure that unamortized capitalized costs in each cost center (country) do not exceed their fair value.  Impairment is recognized when the carrying value is greater than the discounted future cash flows.  In the event of impairment, the amount by which the carrying value exceeds the estimated fair value of the long-lived asset is charged to earnings. The present value of estimated future net revenues is computed by applying average oil and gas prices to estimated future production of proved oil and gas reserves as of period-end, less estimated future expenditures to be incurred in developing and producing the proved reserves assuming the continuation of existing economic conditions. SEC rules require that reserve calculations be based on the un-weighted average first-day-of-the-month prices for the prior twelve months. There was no impairment of proved oil and gas properties indicated at either December 31, 2012 or December 31, 2011.

For the unproved properties, the Company evaluates the possibility of potential impairment on a quarterly basis.  During the twelve months ended December 31, 2012 approximately $587,040 of unproved property costs related to Indonesia exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Indonesia full cost pool as negotiations with the Indonesian government for an extension of the Bengara II Production Sharing Contract (“PSC”) have terminated. The PSC shall now be relinquished and allowed to expire in accordance with its terms. In addition, approximately $33,616 of unproved property costs related to Canada exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Canada full cost pool. During the twelve months ended December 31, 2011 approximately $750,133 of unproved property costs related to Indonesia exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Indonesia full cost pool, as the decision was made to terminate CG Xploration and wind down operations. 

Joint Ventures—Some exploration and production activities are conducted jointly with others and, accordingly, the accounts reflect only GeoPetro’s proportionate interest in such activities.

Revenue Recognition—Revenue is recognized upon delivery of gas production.

Asset Retirement Obligation—The fair value of an asset retirement cost, and corresponding liability, are recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. GeoPetro recorded an asset retirement obligation to reflect GeoPetro’s legal obligations related to future plugging and abandonment of its oil and gas wells. GeoPetro estimated the expected cash flow associated with the obligation and discounted the amount using a credit-adjusted, risk-free interest rate. At least annually, GeoPetro reassesses the obligation to determine whether a change in the estimated obligation is necessary. GeoPetro evaluates whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest the estimated obligation has materially changed, GeoPetro will accordingly update its assessment.

There are asset retirement obligations associated with the Plant. However, components of the Plant can be used for extended and indeterminate periods of time as long as they are properly maintained and/or upgraded. GeoPetro’s intent is to maintain the Plant assets and continue making improvements to those assets based on technological advances. As a result, GeoPetro’s management believes that the Plant has an indeterminate life for purposes of estimating asset retirement obligations because dates or ranges of dates upon which GeoPetro would retire the Plant cannot reasonably be estimated.

	December 31,
	2012		2011
Asset retirement obligations, beginning of period	$	75,000	$	71,510
Liabilities incurred		—		698
Accretion expense		—		2,792
Asset retirement obligations, end of period	$	75,000	$	75,000

Furniture, Fixtures and Equipment—Furniture, fixtures and equipment are stated at cost. Depreciation is provided on furniture, fixtures and equipment using the straight-line method over an estimated service life of three to seven years.

Income Taxes—GeoPetro accounts for income taxes using the asset and liability method wherein deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. Because management has determined that realization of deferred tax assets is not more likely than not, the net deferred tax assets are fully reserved.

Concentrations of Credit Risk—Credit risk represents the accounting loss that would be recognized at the reporting date if counterparties failed completely to perform as contracted. Concentrations of credit risk (whether on or off balance sheet) that arise from financial instruments exist for groups of customers or counterparties when they have similar economic characteristics that would cause their ability to meet contractual obligations to be similarly affected by changes in economic or other conditions described below. The credit risk amounts for cash and accounts receivable do not take into account the value of any collateral or security.

GeoPetro maintains several cash accounts with higher quality financial institutions in amounts which occasionally exceed current federal deposit insurance limits. Senior management continuously reviews these institutions for financial stability. The Company has not experienced any losses in connection with amounts in excess of federal deposit limits.

During the years ended December 31, 2012 and 2011, substantially all of the Company’s natural gas production was sold to Luminant Energy Company, LLC.

At December 31, 2011, all of the Company’s trade accounts receivable — oil and gas sales were due from Luminant Energy Company, LLC.  There were no trade accounts receivable at December 31, 2012.

Trade Accounts Receivable and Allowance for Doubtful Accounts—Accounts receivable, oil and gas sales, consist of uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days.  No interest is charged on past-due balances.  Payments made on all accounts receivable are applied to the earliest unpaid items.  Trade accounts receivable are recorded at net realizable value. If the financial condition of GeoPetro’s customers were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required. Delinquent trade accounts receivable are charged against the allowance for doubtful accounts once uncollectibility has been determined. The allowance is determined through an analysis of the past-due status of accounts receivable and assessments of risk that are based on historical trends and an evaluation of the impact of current and projected economic conditions. There was no allowance for doubtful accounts needed as of December 31, 2012 or 2011.

Fair Value of Financial Instruments—The estimated fair values for financial instruments are determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. For certain of GeoPetro’s financial instruments, including cash, accounts receivable, accounts payable and current portion of notes payable, the carrying amounts approximate fair value due to their maturities.

Share-Based Payments—The Company has a stock-based compensation plan that allows employees to purchase common shares of the Company. Option exercise prices approximate the market price for the common shares on the date the options were issued. Options granted under the plan are generally fully exercisable after five years and expire five to ten years after the grant date. The Company measures and records stock-based awards to directors, employees and consultants based on the grant-date fair value, determined using the Black-Scholes option pricing model with assumptions for: risk free interest rates, expected dividend yield, expected life of the option, and the expected volatility. The compensation expense was recorded ratably over the requisite service period defined in the award.  The Company recorded $422,999 and $407,311 of stock-based employee compensation for the twelve months ended December 31, 2012 and 2011, respectively. (Note 8)

Net Loss perCommon Share—Basic net loss per common share is computed by dividing the net loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period.

Diluted net loss per common share is computed in the same manner, but also considers the effect of common stock shares underlying the following:

	Years Ended December 31,
	2012		2011
Stock options (Note 8)		3,445,000		2,770,000
Warrants (Note 9)		5,983,265		5,424,044
Convertible preferred stock, Series B		5,423,000		5,423,000

All of the common shares underlying the stock options and warrants above were excluded from diluted weighted average shares outstanding for each of the years in the period ended December 31, 2012 and 2011 because their effects were antidilutive.

Segment Reporting—GeoPetro has oil and gas exploration, development and production operations in the United States, Canada, Australia and Indonesia. All revenues and related costs are associated with operations in the United States. A summary of assets and capital expenditures by geographical segment is included in Note 4.

Cash and Cash Equivalents—Cash and cash equivalents include cash on hand, amounts held in banks and highly liquid investments purchased with an original maturity of three months or less.

Reclassification—Certain prior year amounts have been reclassified for consistency in reporting with current year amounts to avoid confusion.  Sublease income has been included as a reduction in general and administrative expenses in the accompanying statements of operations.

Recently Issued Accounting Pronouncements— The Company has evaluated recent accounting pronouncements and their adoption and we have not identified any that would have a material impact on the Company’s financial position, or statements.

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Note 7 - Shareholders' Equity (Detail) (USD $)	1 Months Ended								3 Months Ended	12 Months Ended		1 Months Ended								1 Months Ended
	Aug. 31, 2012	Nov. 30, 2011	Jul. 31, 2011	Mar. 31, 2011	Dec. 31, 2010	Jun. 30, 2009	May 31, 2009	Dec. 31, 2008	Oct. 31, 2009	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2012 March 2012 Private Placement [Member]	Nov. 30, 2012 November 2012 Private Placement [Member]	Dec. 31, 2012 December 2012 Private Placement [Member]	Mar. 31, 2011 March 2011 Private Placement [Member]	Jun. 30, 2011 June 2011 Private Placement [Member]	Dec. 31, 2012 Series A Preferred Stock [Member]	Dec. 31, 2012 Series AA Prefered Stock [Member]	Dec. 31, 2012 In One or More Series [Member]	Dec. 31, 2012 Series B Preferred Stock [Member]
Common Stock, Shares Authorized										100,000,000	100,000,000
Preferred Stock, Shares Authorized										7,523,000	7,523,000						1,000,000	5,000,000	44,000,000
Equity Issuance, Per Share Amount (in Dollars per share)												$ 0.25	$ 0.10	$ 0.10	$ 0.45	$ 0.55
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per Item)					0.50	1.00	1.00					0.50	0.50	0.50	0.75	1.00
Warrant Term					3 years	3 years	3 years	3 years				3 years	3 years	3 years	3 years	3 years
Proceeds from Issuance or Sale of Equity (in Dollars)												$ 250,000	$ 10,000	$ 100,000	$ 922,648	$ 556,560
Stock Issued During Period, Shares, New Issues												1,000,000	100,000	1,000,000	2,050,328	1,011,928
Number of Warrants Issued									47,500	1,310,000	1,568,129	500,000	50,000	500,000	1,025,164	505,965
Stock Issued During Period, Shares, Share-based Compensation, Gross	225,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value (in Dollars per share)	$ 0.14									$ 0.11	$ 0.27
Stock Issued During Period, Value, Share-based Compensation, Gross (in Dollars)	31,500
Preferred Stock, Shares Issued										5,423,000	5,423,000									5,423,000
Preferred Stock, Shares Outstanding										5,423,000	5,423,000									5,423,000
Preferred Stock, Dividend Rate, Per-Dollar-Amount (in Dollars per share)																				$ 0.06
Preferred Stock, Conversion Basis																				one-for-one
Minimum Common Shares Price which Triggers Automatic Conversion of Series B Preferred Stock to Common Shares (in Dollars per share)										$ 1.50
Preferred Stock Dividends, Income Statement Impact (in Dollars)										325,380	434,639
Payments of Ordinary Dividends (in Dollars)										$ 0	$ 0
Conversion of Stock, Shares Converted		2,000,000	80,000	20,000

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Note 3 - Summary of Significant Accounting Policies (Detail) (USD $)	1 Months Ended		12 Months Ended
	Aug. 31, 2012	Aug. 31, 2011	Dec. 31, 2012	Dec. 31, 2011
Impairment of Oil and Gas Properties (in Dollars)			$ 620,656	$ 750,133
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	5 years	5 years	5 years
Share-based Compensation (in Dollars)			422,999	407,311
Indonesia [Member]
Impairment of Oil and Gas Properties (in Dollars)			587,040	750,133
Canada [Member]
Impairment of Oil and Gas Properties (in Dollars)			$ 33,616
Minimum [Member]
Property, Plant and Equipment, Useful Life			3 years
Share-Based Compensation Arrangement by Share-Based Payment Award Expiration			5 years
Maximum [Member]
Property, Plant and Equipment, Useful Life			7 years
Share-Based Compensation Arrangement by Share-Based Payment Award Expiration			10 years

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Note 2 - Liquidity (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Feb. 28, 2011	Dec. 31, 2010	Oct. 31, 2009	Jun. 30, 2009	May 31, 2009	Dec. 31, 2008
Working Capital	$ (4,200,568)
Retained Earnings (Accumulated Deficit)	(49,729,613)	(45,468,931)
Net Income (Loss) Available to Common Stockholders, Basic	(4,260,682)	(1,907,073)
Percent of Revenue from Natural Gas Production in Madisonville Field	100.00%
Debt Instrument, Interest Rate, Stated Percentage	10.00%		8.00%	6.00%	10.00%	8.00%	8.00%	8.00%
Stuart J Doshi [Member]
Due to Related Parties	$ 565,000
Debt Instrument, Interest Rate, Stated Percentage	10.00%

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited) (Detail) - Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Future cash inflows	$ 44,045	$ 72,305
Future production costs	(10,555)	(16,512)
Future development costs	(10,916)	(10,916)
10% annual discount	(6,426)	(12,258)
Standardized measure of discounted future net cash flows	16,148	32,619
Future net cash flows	$ 22,574	$ 44,877

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Note 8 - Common Stock Options (Detail) (USD $)	1 Months Ended			12 Months Ended
	Aug. 31, 2012	Aug. 31, 2011	Apr. 30, 2011	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized				5,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Description				In the case of employees who receive incentive stock options which are first exercisable in a particular calendar year and the aggregate fair market value of which exceeds $100,000, the excess of the $100,000 limitation shall be treated as a nonstatutory stock option under the Stock Incentive Plan
Number of Years the Stock Incentive Plan Will Continue in Effect				10
Minimum Exercise Price of Options Granted as Percentage of Fair Market Value of Common Stock on Date of Grant				110.00%
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	675,000	25,000		675,000	25,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price (in Dollars per share)	$ 0.16	$ 0.50		$ 0.16	$ 0.50
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	5 years	5 years		5 years
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value (in Dollars)	$ 70,831	$ 6,852
Share-based Compensation Arrangement by Share-based Payment Award, Options, Expirations in Period			150,000		150,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Expirations in Period, Weighted Average Exercise Price (in Dollars per share)			$ 3.85		$ 3.85
Share-based Compensation (in Dollars)				422,999	407,311
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate				0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number				2,461,000
Unvested Options Which Will Become Exercisable Over the Next Four Years				984,000
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized (in Dollars)				$ 286,951
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term				3 years 251 days

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Note 3 - Summary of Significant Accounting Policies (Detail) - Asset retirement obligations (USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2012
Asset retirement obligations, beginning of period	$ 71,510	$ 75,000
Liabilities incurred	698
Accretion expense	3,490
Asset retirement obligations, end of period	$ 75,000	$ 75,000

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Note 3 - Summary of Significant Accounting Policies (Detail) - Antidilutive securities	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Stock Options [Member]
Antidilutive securities	3,445,000	2,770,000
Warrant [Member]
Antidilutive securities	5,983,265	5,424,044
Convertible Preferred Stock Series B [Member]
Antidilutive securities	5,423,000	5,423,000

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Note 2 - Liquidity

12 Months Ended

Dec. 31, 2012

Liquidity Disclosure [Policy Text Block]

2.         LIQUIDITY

As of December 31, 2012, GeoPetro had a working capital deficit of $4,200,568 and an accumulated deficit of $49,729,613.  Further, GeoPetro generated net losses attributable to common sharesholders of $4,260,682 and $1,907,073 during the years ended December 31, 2012 and 2011 respectively.  GeoPetro’s ability to meet its contractual obligations and remit payment under its arrangements with its vendors depends on its ability to generate additional financing.  GeoPetro’s management continues to renegotiate the terms of its existing borrowing arrangements and raise additional capital through debt and equity issuances. These conditions raise substantial doubt about the Company's ability to continue as a going concern. These consolidated financial statements do not include any adjustment that might be necessary if the Company is unable to continue as a going concern.

Since its inception, GeoPetro has participated as a working interest owner in the acquisition of undeveloped leases, seismic options, lease options and foreign concessions and has participated in seismic surveys and the drilling of test wells on its undeveloped properties.  More recently, we acquired a natural gas treatment plant in East Texas.  Exploratory and development drilling is scheduled during 2013 and future periods on GeoPetro’s undeveloped properties and expansion is planned on the natural gas treatment plant.  The planned expansion at the natural gas treatment plant and the exploration activities together with others that may be entered into exceed the existing working capital of GeoPetro.  Management will need to raise additional equity and/or debt capital, to finance its continued activities.  Management believes that GeoPetro will be successful in obtaining adequate sources of cash to fund its anticipated capital expenditures and operating expense through the end of 2013, but there can be no assurance that management will be successful in raising sufficient additional equity and/or debt capital.  If additional financing is not available, GeoPetro will be compelled to reduce the scope of its business activities including, but not limited to, the following:

· Selling working interests and assets in its Madisonville operations to other parties;

· Farming-out its interest in proposed wells;

· Forfeiting its interest in wells that are proposed to be drilled and/or;

· Reducing general and administrative expenses;

As a result of the Company’s liquidity issues, it may be required to sell certain assets or raise capital with terms that may not be as favorable as might otherwise be available.

In April 2012, the Company's wholly-owned subsidiary, Redwood Energy Production, L.P., elected to temporarily shut-in its natural gas production at the Madisonville Field, Madison County, Texas in light of depressed natural gas prices.  The Company will monitor market conditions and bring its natural gas production back on stream as market conditions warrant. For the year ended December 31, 2012, 100% of the Company's revenue was derived from the natural gas production in the Madisonville Field.

As of December 31, 2012, Stuart J. Doshi, President and CEO, has advanced to the Company twelve loans totaling $565,000.  The notes bear interest at 10% per annum and are payable on demand (Note 5). 

On February 28, 2013, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”), with MCW Energy Group Limited, an Ontario corporation (“MCW”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“Merger Sub”). Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “Merger”) and the Company will survive the Merger and continue as a subsidiary of MCW. The Merger Agreement has been approved by Boards of Directors of each of the Company, MCW and Merger Sub.  The merger is subject to customary closing conditions, including regulatory and shareholder approval.

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Note 4 - Summary of Oil and Gas Operations (Detail) (USD $)	1 Months Ended		12 Months Ended
	Aug. 31, 2012	Jun. 30, 2012	Dec. 31, 2012	Dec. 31, 2011
Proceeds from Sale of Oil and Gas Property and Equipment (in Dollars)	$ 500,000		$ 523,786
Impairment of Oil and Gas Properties (in Dollars)			620,656	750,133
Capitalized Costs, Unproved Properties (in Dollars)			6,524,819	6,931,499
OilAndGasProducingPropertyOwnershipPercentage		100.00%
Acquired Working Interest in Oil and Gas Project, Percent		2/3
Indonesia [Member]
Impairment of Oil and Gas Properties (in Dollars)			587,040	750,133
Canada [Member]
Impairment of Oil and Gas Properties (in Dollars)			33,616
Alaska [Member]
Capitalized Costs, Unproved Properties (in Dollars)			$ 3,710,658
Bengara II Block PSC [Member]
OilAndGasProducingPropertyOwnershipPercentage			12.00%
As of Dec 31, 2012 [Member]
Evaluation of Costs in Percentage			25.00%
In 2014 [Member]
Evaluation of Costs in Percentage			30.00%
In 2015 and Beyond [Member]
Evaluation of Costs in Percentage			45.00%

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Note 6 - Income Taxes (Detail) - The provision for income taxes consists of the following (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Current
State	$ 9,664	$ 800
Total	9,664	800
Total Income Tax Provision	$ 9,664	$ 800

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited) (Detail)	12 Months Ended
	Dec. 31, 2012 MMcf	Dec. 31, 2011 MMcf
Increase in Natural Gas Prices	35.00%
Natural Gas Prices Per Mcf	2.46	3.76
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates (in Millions of Cubic Feet)	(984)	791

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Consolidated Balance Sheets (USD $)	Dec. 31, 2012	Dec. 31, 2011
Current Assets
Cash and cash equivalents	$ 59,432	$ 916,741
Trade accounts receivable—oil and gas sales		165,160
Accounts receivable—other	5,460	5,560
Prepaid expenses	65,266	88,931
Total current assets	130,158	1,176,392
Oil and gas properties, at cost (full cost method)
Unproved properties	6,524,819	6,931,499
Proved properties	53,090,943	52,977,232
Gas processing plant	5,533,910	5,533,910
Less—accumulated depletion, depreciation and impairment	(41,625,269)	(40,823,082)
Net oil and gas properties	23,524,403	24,619,559
Furniture, fixtures and equipment, at cost, net of depreciation	28,709	42,288
Other assets	36,733	44,600
Total Assets	23,720,003	25,882,839
Current Liabilities
Trade payables	1,346,510	969,617
Current portion of long term notes payable	944,950	1,197,385
Notes payable – related party	565,000
Interest payable	137,921	16,570
Dividends payable	873,791	548,411
Other taxes payable	134,704	164,796
Royalty owners payable	327,850	338,713
Total current liabilities	4,330,726	3,235,492
Long Term Notes Payable	1,644,427	1,423,707
Asset Retirement Obligations	75,000	75,000
Other Long Term Liabilities	66,548	75,750
Total Liabilities	6,116,701	4,809,949
Commitments and Contingencies (Notes 2 and 10)
Shareholders’ Equity
Series B preferred stock, no par value; 7,523,000 shares authorized; 5,423,000 shares issued and outstanding. Aggregate liquidation preference of $4,067,250.	3,873,602	3,873,602
Common stock, no par value; 100,000,000 shares authorized; 46,578,101 and 44,253,101 shares issued and outstanding at December 31, 2012 and December 31, 2011, respectively.	59,117,079	58,725,579
Additional paid-in-capital	4,342,234	3,942,640
Accumulated deficit	(49,729,613)	(45,468,931)
Total shareholders’ equity	17,603,302	21,072,890
Total Liabilities and Shareholders’ Equity	$ 23,720,003	$ 25,882,839

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Note 8 - Common Stock Options (Detail) - A summary of the status of GeoPetro’s stock option plan is as follows (USD $)	1 Months Ended			12 Months Ended
	Aug. 31, 2012	Aug. 31, 2011	Apr. 30, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Outstanding, number of options (in Shares)				3,445,000	2,770,000	2,895,000
Outstanding, weighted average exercise price				$ 1.21	$ 1.46	$ 1.59
Granted, number of options (in Shares)	675,000	25,000		675,000	25,000
Granted, exercise prices				$ 0.16	$ 0.50
Granted, weighted average exercise price	$ 0.16	$ 0.50		$ 0.16	$ 0.50
Expired, number of options (in Shares)			(150,000)		(150,000)
Expired, exercise prices					$ 3.85
Expired, weighted average exercise price			$ 3.85		$ 3.85
Minimum [Member]
Outstanding, exercise prices				$ 0.16	$ 0.50	$ 0.50
Maximum [Member]
Outstanding, exercise prices				$ 2.10	$ 2.10	$ 3.85

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Consolidated Statements of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Cash Flows From Operating Activities
Net loss	$ (3,935,302)	$ (1,472,434)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and depletion	195,110	449,537
Share-based compensation expense	422,999	407,311
Non-cash interest expense	51,380	140,251
Accretion of discount on asset retirement obligations		3,490
Impairment of oil and gas properties	620,656	750,133
Gain on sale of equipment		(4,069,640)
Changes in operating assets and liabilities:
Accounts receivable	165,160	(39,567)
Other assets	31,632	1,266
Current liabilities	457,289	(574,492)
Other	(9,202)	815
Net cash used in operating activities	(2,000,278)	(4,403,330)
Cash Flows from Investing Activities
Additions to oil and gas properties	(230,817)	(1,382,153)
Dispositions of oil and gas properties	523,786
Proceeds from sale of equipment		9,250,000
Net cash provided by investing activities	292,969	7,867,847
Cash Flows from Financing Activities
Proceeds from issuance of common shares	360,000	1,479,208
Proceeds from promissory notes		1,000,000
Repayments of promissory notes	(75,000)	(5,947,847)
Proceeds from related party notes	565,000	125,000
Repayments of related party notes		(125,000)
Payments of loan fee		(27,000)
Net cash provided by (used in) financing activities	850,000	(3,495,639)
Net Decrease in Cash and Cash Equivalents:	(857,309)	(31,122)
Cash and Cash Equivalents
Beginning of period	916,741	947,863
End of period	59,432	916,741
Supplemental Disclosure of Cash Flow Information
Cash paid for interest	122,889	664,761
Cash paid for income taxes	1,600	800
Non-Cash Transactions
Issuance of warrants in connection with promissory notes and private placements	77,932	403,749
Accrual of dividends on preferred stock	$ 325,380	$ 434,639

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Note 4 - Summary of Oil and Gas Operations (Detail) - Summary of oil and gas property costs not being amortized (USD $)	12 Months Ended				48 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2012
Unproved property acquisition				$ 2,150,134	$ 2,150,134
Exploration	213,976	68,624	201,234	3,890,851	4,374,685
Total	$ 213,976	$ 68,624	$ 201,234	$ 6,040,985	$ 6,524,819

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Note 5 - Debt (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Debt [Table Text Block]

	December 31, 2012			December 31, 2011
Current Portion
Related party notes (a)	$	565,000		$	—
Promissory notes 12/08 (b)		—			850,000
Promissory notes 06/09 (d)		—			300,000
Bridge notes 08/10, 10/10 (e)		900,000			—
Promissory note 09/10 (f)		75,000			75,000
Less discount on promissory notes		(30,050	)		(27,615	)
Net current notes payable		1,509,950			1,197,385
Long Term
Promissory notes 12/08 (b)		850,000			—
Promissory notes 05/09 (c)		365,000			365,000
Promissory notes 06/09 (d)		300,000			—
Bridge notes 08/10, 10/10 (e)		—			900,000
Promissory note 09/10 (f)		150,000			225,000
Less discount on promissory notes		(20,573	)		(66,293	)
Net Long term notes payable		1,644,427			1,423,707
Total	$	3,154,378		$	2,621,092

Schedule of Maturities of Long-term Debt [Table Text Block]

Maturity Date	2013		2014		2015
January	$	565,000	$	1,150,000	$	—
May		—		365,000		—
August		180,000		—		—
October		795,000		75,000		75,000
Totals	$	1,540,000	$	1,590,000	$	75,000

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Note 5 - Debt (Detail) (USD $)	1 Months Ended									3 Months Ended	12 Months Ended										12 Months Ended	1 Months Ended														3 Months Ended		1 Months Ended		1 Months Ended						12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jul. 31, 2011	Jun. 30, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2009	May 31, 2009	Dec. 31, 2008	Oct. 31, 2009	Dec. 31, 2012	Dec. 31, 2011	May 31, 2012	Feb. 28, 2011	May 31, 2012 Original [Member] Maturity Date January 2014 [Member]	Jun. 30, 2009 Original [Member] Maturity Date January 2014 [Member]	May 31, 2012 Original [Member] Maturity Date May 2014 [Member]	May 31, 2012 New [Member] Maturity Date January 2014 [Member]	Jun. 30, 2009 New [Member] Maturity Date January 2014 [Member]	May 31, 2012 New [Member] Maturity Date May 2014 [Member]	Dec. 31, 2012 Stuart Doshi Loan Feb 2011 [Member]	Dec. 31, 2008 Reissued [Member]	Dec. 31, 2008 Finder's Fee [Member]	Feb. 28, 2011 Maturity Date December 2012 [Member]	Dec. 31, 2012 Maturity Date January 2014 [Member]	May 31, 2012 Maturity Date January 2014 [Member]	Jun. 30, 2009 Maturity Date January 2014 [Member]	May 31, 2009 Maturity Date May 2012 [Member]	Feb. 28, 2011 Maturity Date May 2013 [Member]	Dec. 31, 2012 Maturity Date May 2014 [Member]	May 31, 2012 Maturity Date May 2014 [Member]	Jun. 30, 2009 Maturity Date June 2012 [Member]	Dec. 31, 2012 Extended Warrants Issued in June 2009 [Member]	Oct. 31, 2009 Maturity Date August 2011 [Member]	Oct. 31, 2009 Maturity Date October 2011 [Member]	Oct. 31, 2009 Maturity Date August and October 2011 [Member]	Oct. 31, 2011 Maturity Date August 2013 [Member]	Oct. 31, 2011 Maturity Date October 2013 [Member]	Dec. 31, 2012 Maturity Date October 2013 [Member]	Sep. 30, 2010 Due in March 2011 [Member]	Sep. 30, 2010 Due in October 2011 [Member]	Sep. 30, 2010 Due in October 2012 [Member]	Sep. 30, 2010 Due in October 2013 [Member]	Sep. 30, 2010 Due in October 2014 [Member]	Sep. 30, 2010 Due in October 2015 [Member]	Dec. 31, 2012 Five-Year Non-Interest Bearing Note [Member]	Dec. 31, 2011 Five-Year Non-Interest Bearing Note [Member]
Notes Payable, Related Parties (in Dollars)														$ 125,000
Debt Instrument, Interest Rate, Stated Percentage					6.00%		8.00%	8.00%	8.00%	10.00%	10.00%			8.00%																																10.00%
Repayments of Related Party Debt		125,000										125,000
Due to Related Parties, Current											565,000
Number of Warrants Issued (in Shares)										47,500	1,310,000	1,568,129									113,000	15,000	150,000													95,000		37,000
Warrants and Rights Outstanding (in Dollars)					16,662		7,537		122,764	24,162											4,520			4,370		1,766	839	12,724	1,876		971	1,542				23,286		5,374
Interest Expense, Related Party																					28,083
Proceeds from Notes Payable					300,000	375,000	300,000	365,000	1,050,000	950,000		1,000,000
Payments of Financing Costs									6,000			27,000
Warrant Term					3 years		3 years	3 years	3 years
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in Shares)					75,000		30,000	36,500	105,000
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per Item)					0.50		1.00	1.00							1.00	1.00	1.00	0.50	0.50	0.50		1.00
Other Notes Payable (in Dollars)										50,000			1,515,000											850,000		850,000								180,000	720,000		180,000	720,000
Debt Instrument, Face Amount	200,000											200,000
Debt Instrument, Unamortized Discount																									1,736					1,674			574						12,803							33,836
Debt Instrument, Fee Amount																																				36,000		27,000
Debt Instrument, Periodic Payment																																								25,000	50,000	75,000	75,000	75,000	75,000
Repayments of Notes Payable		300,000									75,000	5,947,847																																		75,000	75,000
Discount Recorded in Connection with Non-Interest Bearing Note Payable						90,116
Debt Instrument, Increase, Additional Borrowings			400,000	600,000
Repayments of Long-term Debt	$ 5,372,847

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Note 8 - Common Stock Options (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]

	Options			Exercise Prices			Weighted Average Exercise Price
Outstanding at January 1, 2011		2,895,000		$0.50	to	$3.85	$	1.59
Granted		25,000			$0.50			0.50
Exercised		—			—			—
Expired		(150,000	)		$3.85			3.85
Outstanding at December 31, 2011		2,770,000		$0.50	to	$2.10		1.46
Granted		675,000			$0.16			0.16
Exercised		—			—			—
Expired		—			—			—
Outstanding at December 31, 2012		3,445,000		$0.16	to	$2.10	$	1.21

Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]

	2012			2011
Expected dividend yield		—			—
Expected volatility		105.6	%		149.8	%
Risk-free interest rates		0.59	%		0.99	%
Expected lives (years)		5			5
Weighted average fair values per share	$	0.11		$	0.27

Schedule of Share-based Compensation, Activity [Table Text Block]

Number of Options Outstanding		Number of Options Exercisable		Exercise Prices		Weighted Average Remaining Contractual Life
	675,000		—		0.16		4.67
	960,000		675,000		0.50		0.99
	210,000		186,000		1.00		0.68
	1,600,000		1,600,000		2.10		0.39
	3,445,000		2,461,000

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Note 1 - Organization and Basis of Presentation

12 Months Ended

Dec. 31, 2012

Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]

1.         ORGANIZATION AND BASIS OF PRESENTATION

GeoPetro Resources Company (“we,” “us,” “our,” “GeoPetro” or the “Company”) was originally incorporated as GeoPetro Company under the laws of the State of Wyoming in 1994 to participate in the oil and gas acquisition, exploration, development and production business in the United States and internationally. GeoPetro Company was subsequently merged into GeoPetro Resources Subsidiary Company, a California corporation, on June 28, 1996. GeoPetro’s name was then changed to GeoPetro Resources Company. GeoPetro’s corporate offices are in San Francisco, California. The accompanying consolidated financial statements include the accounts of GeoPetro and its wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.

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Consolidated Balance Sheets (Parentheticals) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Preferred stock, liquidation preference (in Dollars)	$ 4,067,250	$ 4,067,250
Preferred stock, shares authorized	7,523,000	7,523,000
Preferred stock, shares issued	5,423,000	5,423,000
Preferred stock, shares outstanding	5,423,000	5,423,000
Preferred stock, Series B, no par value (in Dollars per share)	$ 0	$ 0
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	46,578,101	44,253,101
Common stock, shares outstanding	46,578,101	44,253,101
Common stock, no par value (in Dollars per share)	$ 0	$ 0

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Note 11 - Subsequent Events

12 Months Ended

Dec. 31, 2012

Subsequent Events [Text Block]

11.       SUBSEQUENT EVENTS

In January 2013, Stuart J. Doshi, President and CEO, advanced to the Company a loan for $5,000.  The note bears interest at 10% per annum and is payable on demand.  In connection with this note, the Company issued 1,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In January 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $132,500, and represented the sale of 1,325,000 common shares and 662,500 warrants. 

In January 2013, we agreed to rescind a unit subscription agreement. Units were originally priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitled the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units originally sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants.  The Company is reacquiring the common shares and warrants in exchange for a non-interest bearing unsecured note for $250,000 which matures in July 2014.

In February 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $122,500, and represented the sale of 1,225,000 common shares and 612,500 warrants. 

On February 28, 2013, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”), with MCW Energy Group Limited, an Ontario corporation (“MCW”), and MCW CA SUB, a California corporation and a wholly-owned subsidiary of Parent (“Merger Sub”). Pursuant to the Merger Agreement and subject to the terms and conditions set forth therein, Merger Sub will merge with and into the Company (the “Merger”) and the Company will survive the Merger and continue as a subsidiary of MCW. The Merger Agreement has been approved by Boards of Directors of each of the Company, MCW and Merger Sub.  The merger is subject to customary closing conditions, including regulatory and shareholder approval.

In March 2013, Stuart J. Doshi, President and CEO, advanced to the Company three loans totaling $85,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 17,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

In March 2013, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $50,000, and represented the sale of 500,000 common shares and 250,000 warrants. 

In April 2013, Stuart J. Doshi, President and CEO, advanced to the Company three loans totaling $55,000.  The notes bear interest at 10% per annum and are payable on demand.  In connection with these notes, the Company issued 11,000 warrants to purchase our common stock.  Each warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years.

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Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2012	Apr. 01, 2013	Jun. 29, 2012
Document and Entity Information [Abstract]
Entity Registrant Name	GeoPetro Resources Company
Document Type	10-K
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		48,681,074
Entity Public Float			$ 5,280,094
Amendment Flag	false
Entity Central Index Key	0001116927
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Smaller Reporting Company
Entity Well-known Seasoned Issuer	No
Document Period End Date	Dec. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	FY

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited)

12 Months Ended

Dec. 31, 2012

Oil and Gas Exploration and Production Industries Disclosures [Text Block]

12.       SUPPLEMENTARY OIL AND GAS RESERVE INFORMATION: (UNAUDITED)

The reserve quantities and valuations are based upon estimates by MHA Petroleum Consultants LLC. The proved reserves presented herein are located entirely within the United States. Proved reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, i.e. prices and costs as of the date the estimate is made. SEC rules require that reserve calculations be based on the un-weighted average first-day-of-the-month prices for the prior twelve months. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions. Reservoirs are considered proved if economic productivity is supported by either actual production or a conclusive formation test. The area of a reservoir considered proved includes (A) that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any, and (B) the immediately adjoining portions not yet drilled, but which can reasonably be judged as economically productive on the basis of available geological and engineering data. In the absence of information on fluid contacts the lowest known structural occurrence of hydrocarbons controls the lower proved limit of the reservoir.

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

The estimates included in the following tables are by their nature inexact and are subject to changing economic, operating and contractual conditions. At December 31, 2012, all of GeoPetro’s reserves are attributable to two wells capable of production, one shut-in well and two undeveloped locations. Other than the producing wells and one shut-in well, there is no other production history as of or subsequent to that date. Reserve estimates for these wells are subject to substantial upward or downward revisions after production commences and a production history is obtained.   Accordingly, reserve estimates of future net revenues from production may be subject to substantial revision from year to year. Reserve information presented herein is based on reports prepared by independent petroleum engineers.

The assumptions used to compute the standardized measure are those prescribed by the Financial Accounting Standards Board and, as such, do not necessarily reflect GeoPetro’s expectations for actual revenues to be derived from those reserves nor their present worth. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these are the basis for the valuation process.

	Natural Gas (Mcf)
Proved Developed and Undeveloped Reserves
January 1, 2011		18,308
Revisions of previous estimates		791
Production		(210	)
December 31, 2011		18,889
Revisions of previous estimates		(984	)
Production		(116	)
December 31, 2012		17,789

	2012		2011
	(MMcf)		(MMcf)
Proved developed		—		2,453
Proved developed non-producing		9,126		7,328
Proved undeveloped		8,663		9,108
Total		17,789		18,889

Proved reserves presented herein are located entirely within in the United States

The following is a discussion of the material changes in our proved reserve quantities for the years ended December 31, 2012 and 2011.

Year Ended December 31, 2012

The downward revision of previous estimates of natural gas reserves during 2012 of 984 MMcf is attributable to decreases in gas prices as calculated under the new SEC pricing methodology, which has affected the economic life of the wells. Natural gas prices decreased approximately 35% from December 31, 2011 ($3.76 per Mcf) to December 31, 2012 ($2.46 per Mcf).

Year Ended December 31, 2011

The upward revision of previous estimates of natural gas reserves during 2011 of 791 MMcf is primarily attributable to a decrease in the anticipated operating costs of the wells and the operating costs of the plant, as well as an increase in the production rate following the workovers.

Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves

For purposes of the following disclosures, estimates were made of quantities of proved reserves and the periods during which they are expected to be produced. Future cash flows for the 2012 and 2011 estimates were computed by applying the simple arithmetic average of the natural gas price in effect on the first day of each month to estimated annual future net production from proved gas reserves, amounting to $2.46 per Mcf and $3.76 per Mcf at December 31, 2012 and 2011, respectively. For both 2012 and 2011, future development and production costs were computed by applying year-end costs to be incurred in producing and further developing the proved reserves. Future income tax expenses were computed by applying, generally, year-end statutory tax rates (adjusted for permanent differences, tax credits and allowances) to the estimated net future pre-tax cash flows. The discount was computed by application of a 10% discount factor. The calculations assume the continuation of existing economic, operating and contractual conditions. However, such arbitrary assumptions have not proven to be the case in the past. Other assumptions of equal validity could give rise to substantially different results.

	Year Ended December 31,
	2012			2011
	(in thousands)
Future cash inflows	$	44,045		$	72,305
Future production costs		(10,555	)		(16,512	)
Future development costs		(10,916	)		(10,916	)
Future income taxes		—			—
Future net cash flows		22,574			44,877
10% annual discount		(6,426	)		(12,258	)
Standardized measure of discounted future net cash flows	$	16,148		$	32,619

The PV-10 values shown in the aforementioned table are not intended to represent the current market value of the estimated proved oil and gas reserves owned by us.

Changes in the Standardized Measure of Discounted Futures Net Cash Flows from Proved Petroleum and Natural Gas Reserve Quantities.

	Years Ended December 31,
	2012			2011
Balance, beginning of period		32,619			29,102
Sales of oil and gas, net		(877	)		(1,509	)
Net change in prices and production costs		(16,452	)		6,121
Net change in future development costs		—			(2,760	)
Revisions of previous quantity estimates		(1,325	)		1,698
Net change in income taxes		—			—
Accretion of discount		3,674			2,505
Other		(1,491	)		(2,538	)
Balance, end of period	$	16,148		$	32,619

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Consolidated Statements of Operations (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Revenues
Natural gas sales	$ 351,082	$ 976,571
Costs and Expenses
Plant operating	1,036,549	2,280,453
Lease operating	191,615	205,421
General and administrative	1,963,053	2,202,071
Depreciation and depletion	195,110	449,537
Impairment of oil and gas properties	620,656	750,133
Total costs and expenses	4,006,983	5,887,715
Loss from operations	(3,655,901)	(4,911,144)
Other Income (Expense)
Other income	25,705	3,771
Interest income	178	675
Interest expense	(295,620)	(634,576)
Gain on sale of equipment		4,069,640
Total other income (expense)	(269,737)	3,439,510
Loss Before Taxes	(3,925,638)	(1,471,634)
Income tax expense	(9,664)	(800)
Net Loss	(3,935,302)	(1,472,434)
Preferred stock dividend	(325,380)	(434,639)
Net Loss Available to Common Shareholders	$ (4,260,682)	$ (1,907,073)
Net Loss Per Common Shares Basic and Diluted (in Dollars per share)	$ (0.09)	$ (0.05)
Weighted average number of common shares outstanding basic and diluted (in Shares)	45,129,877	41,754,777

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Note 6 - Income Taxes

12 Months Ended

Dec. 31, 2012

Income Tax Disclosure [Text Block]

6.         INCOME TAXES

The Company files income tax returns in the U.S. federal jurisdiction and various states.  There are currently no federal or state income tax examinations underway.  Furthermore, the Company is no longer subject to U.S. federal income tax examinations by the Internal Revenue Service for tax years before 2009 and for state and local tax authorities for tax years before 2008.  The Company does, however, have net operating losses generated in tax years 1997 and after, which remain open for examination.

The Company adopted the provisions of ASC 740 (formerly SFAS 109 and FIN 48), on January 1, 2007. As of December 31, 2007 the Company had no unrecognized tax benefits. There have been no changes during the year with respect to unrecognized tax benefits.  The Company does not foresee the total amounts of unrecognized tax benefits significantly increasing within the next 12 months.  Furthermore, no corresponding interest and penalties have been accrued as the Company is in a net operating loss position.

ASC 740 requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of the assets and liabilities. Where it is more likely than not that a tax benefit will not be realized, a valuation allowance is recorded to reduce the deferred tax asset to its realizable value.

A valuation allowance has been provided against the Company’s net deferred tax assets as the Company believes that it is more likely than not that the net deferred tax assets will not be realized.

The effective tax rate for the year ended December 31, 2012 is negligible.

The provision for income taxes consists of the following:

	2012		2011
Current
Federal	$	—	$	—
State		9,664		800
Foreign		—		—
Total		9,664		800
Deferred
Federal		—		—
State		—		—
Foreign		—		—
Total		—		—
Total Income Tax Provision	$	9,664	$	800

The actual income tax (benefit) expense differs from the expected tax (benefit) expense as computed by applying the U.S. Federal corporate income tax rate of 35% for each period as follows:

	2012			2011
Amount of expected tax benefit	$	(1,456,563	)	$	(515,000	)
Non-deductible expenses		3,560			4,000
Alternative minimum tax		—			—
State Taxes		9,664			800
Valuation allowance adjustments		1,453,003			511,000
	$	9,664		$	800

Deferred income taxes reflect the net tax effects of temporary differences between carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Significant components of the Company’s deferred tax assets (liabilities) are as follows:

	2012			2011
Deferred tax assets (liabilities)
Net operating loss carry forwards	$	14,150,000		$	12,127,000
Oil and gas property basis differences		3,662,000			3,480,000
Stock compensation		793,000			633,000
Other		(990,000	)		(726,000	)
Total deferred tax assets		17,615,000			15,514,000
Valuation allowance		(17,615,000	)		(15,514,000	)
Total net deferred taxes	$	—		$	—

As of December 31, 2012, GeoPetro had net operating loss (NOL) carryforwards of approximately $39,500,000 for federal income tax purposes which begin to expire in 2017.  If the Company were to experience a change in ownership under Section 382, the Company may be limited in its ability to fully utilize its net operating losses.

However, in accordance with ASC 718 (formerly SFAS 123(R)), a deferred tax asset has not been recognized for the portion of the net operating loss carryforwards that is attributable to excess tax deductions associated with the exercise of stock options which do not reduce income taxes payable. Accordingly, approximately $3,536,000 of GeoPetro’s federal NOL has not been benefited for financial statement purposes as it relates to excess tax deductions that have not reduced income taxes payable. The benefit of these excess tax deductions will not be recognized for financial statement purposes until the related deductions reduce income taxes payable.

The Company also has approximately $12,430,000 of California net operating losses and approximately $670,000 of Alaska net operating losses which begin to expire in 2012 and 2026, respectively. In accordance with ASC 718, a portion of the state NOLs has similarly not been benefited for financial statement purposes as it relates to excess tax deductions which have not resulted in the reduction of income taxes payable. The benefit of such excess tax deductions will not be recognized for financial statement purposes until the related deductions reduce state income taxes payable.

In addition, the Company has approximately $318,264 of carryforward credits in Texas, a portion of which may be utilized each year against Texas Margin Tax liability through 2027.

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Note 5 - Debt

12 Months Ended

Dec. 31, 2012

Debt Disclosure [Text Block]

5.         DEBT

Debt at December 31, 2012 and December 31, 2011 consisted of the following:

	December 31, 2012			December 31, 2011
Current Portion
Related party notes (a)	$	565,000		$	—
Promissory notes 12/08 (b)		—			850,000
Promissory notes 06/09 (d)		—			300,000
Bridge notes 08/10, 10/10 (e)		900,000			—
Promissory note 09/10 (f)		75,000			75,000
Less discount on promissory notes		(30,050	)		(27,615	)
Net current notes payable		1,509,950			1,197,385
Long Term
Promissory notes 12/08 (b)		850,000			—
Promissory notes 05/09 (c)		365,000			365,000
Promissory notes 06/09 (d)		300,000			—
Bridge notes 08/10, 10/10 (e)		—			900,000
Promissory note 09/10 (f)		150,000			225,000
Less discount on promissory notes		(20,573	)		(66,293	)
Net Long term notes payable		1,644,427			1,423,707
Total	$	3,154,378		$	2,621,092

a) In February 2011, Stuart J. Doshi, President and CEO, advanced to the Company a loan in the amount of $125,000 which was payable on demand. The note bears an annual rate of eight percent (8%) interest.  In September 2011, the outstanding principal of $125,000 and the accrued interest thereon were paid in full.  During the year ended December 31, 2012, Stuart J. Doshi, President and CEO, advanced to the Company twelve loans totaling $565,000 which are payable on demand. The notes bear an annual rate of ten percent (10%), with such interest payable quarterly in arrears. These notes are secured by a first position deed of trust against the Company’s improved real property located in Madison County, Texas, commonly known as the Madisonville Gas Processing Plant site. In connection with these notes, the Company issued 113,000 warrants to purchase our common stock. The fair value of the warrants issued was $4,520 (Note 9), which has been recorded as a debt discount and will be amortized over the life of the note.  Since these notes are payable on demand, the debt discount has been fully amortized in 2012. Interest expense accrued on these notes for the year ended December 31, 2012 was $28,083.

b) In December 2008, the Company issued four promissory notes totaling $1,050,000 with maturity dates in December 2011. The notes may be repaid at any time without penalty. The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears. In connection with the notes, the Company paid loan origination fees totaling $6,000 and granted three-year exercisable warrants to purchase 105,000 Common Shares and reissued 15,000 warrants at $1.00 per share. We also issued 150,000 warrants as a finder’s fee. The fair value of the warrants on the dates of issuance of $122,764 and the $6,000 of loan origination fees, were recorded as a debt discount and have been amortized over the life of the promissory notes. In February 2011, we extended the maturity on three separate notes totaling $850,000 to December 2012. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year. The fair value associated with the warrant extension was $4,370 (Note 9), which has been recorded as a debt discount and has been amortized over the extended life of the notes. In December 2011, one of the four original promissory notes for $200,000, and the accrued interest thereon, was paid in full. In May 2012, we extended the maturity on the three remaining notes totaling $850,000 to January 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $1,766 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $1,736.

c) In May 2009, the Company issued two promissory notes totaling $365,000 with maturity dates in May 2012.  The notes may be repaid at any time without penalty.  The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears.  In connection with the notes, the Company granted three-year exercisable warrants to purchase 36,500 Common Shares at $1.00 per share. The fair value of the warrants on the dates of issuance of $12,724 was recorded as a debt discount and has been amortized over the life of the promissory notes. In February 2011, we extended the maturity of the notes to May 2013. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these two notes for an additional year. The fair value associated with the warrant extension was $1,876 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. In May 2012, we extended the maturity on the notes to May 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $971 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $1,674.

d) In June 2009, the Company issued two promissory notes totaling $300,000 with maturity dates in June 2010.  The notes may be repaid at any time without penalty.  The notes bear an annual rate of eight percent (8%), with such interest payable quarterly in arrears.  In connection with the notes, the Company granted three-year exercisable warrants to purchase 30,000 Common Shares at $1.00 per share. The fair value of the warrants on the date of issuance of $7,537 was recorded as a debt discount and has been amortized over the life of the promissory notes.  In March 2010, these two notes were extended for an additional one year and the new maturity was June 2011.  In February 2011, we extended the maturity on the notes to June 2012.  In connection with the extension, the Company extended the warrants to purchase our common stock associated with these two notes for an additional year. The fair value associated with the warrant extension was $1,542 (Note 9), which has been recorded as a debt discount and has been amortized over the extended life of the notes. In May 2012, we extended the maturity on the notes to January 2014. In connection with the extension, the Company extended the warrants to purchase our common stock associated with these three notes for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share. The fair value associated with the warrant extension is $839 (Note 9), which has been recorded as a debt discount and will be amortized over the extended life of the notes. As of December 31, 2012 the unamortized portion of the debt discount was $574.

e) During August through October 2009, the Company borrowed an aggregate of $950,000 pursuant to four separate bridge loans with maturity dates in August 2010 and October 2010.  The notes may be repaid at any time without penalty.  The notes bear an annual rate of ten percent (10%), with such interest payable at maturity.  In connection with the issuance of these notes we issued 47,500 warrants to purchase our common stock. The fair value of the warrants on the dates of issuance of $24,162 was recorded as a debt discount and has been amortized over the life of the promissory notes.  During August through October 2010, we partially repaid a promissory note in the amount of $50,000. We renewed three promissory notes totaling $180,000 with new maturity dates of August 2011 and renewed one promissory note in the amount of $720,000 with a new maturity date of October 2011.  Prior to the note renewals we repaid all outstanding accrued interest on the notes.  The terms of the renewed notes payable remain materially consistent those previously issued.  In connection with the issuance of these notes we issued a total of 95,000 warrants to purchase our common stock and recorded $36,000 in renewal fees. The fair value of the warrants on the date of issuance of $23,286, and the $36,000 renewal fees, were recorded as a debt discount and have been amortized over the life of the promissory notes.  During August through October 2011, we renewed three promissory notes totaling $180,000 with new maturity dates of August 2013 and renewed one promissory note in the amount of $720,000 with a new maturity date of October 2013.  Prior to the note renewals we repaid all outstanding accrued interest on the notes. The terms of the renewed notes payable remain materially consistent those previously issued. In connection with the issuance of these notes we issued a total of 37,000 warrants to purchase our common stock and recorded $27,000 in renewal fees. The fair value of the warrants on the date of issuance of $5,374 (Note 9), and the $27,000 renewal fees, were recorded as a debt discount and are being amortized over the life of the promissory notes.  As of December 31, 2012 the unamortized portion of the debt discount was $12,803.

f) In September 2010, we issued a 5-year non-interest bearing note payable in the amount of $375,000 in connection with the execution of a settlement agreement. Payments are due as follows: $25,000 in March 2011, $50,000 in October 2011, and $75,000 each October thereafter until 2015.  Payments totaled $75,000 in the year ended December 31, 2011 and $75,000 in the year ended December 31, 2012.  An imputed interest rate of 10% per annum has been used to record a discount in connection with this note of $90,116, and is being amortized over the life of the note.  As of December 31, 2012 the unamortized portion of the debt discount was $33,836.

g) Effective December 31, 2008, the Company assumed certain bank debt related to the Company’s acquisition of the Madisonville Gas Treatment Plant (the “Plant”). The Company increased borrowing under this note by $600,000 in June 2011 and by $400,000 in July 2011.  In September 2011, the outstanding principal and accrued interest were paid in full. Total principal repaid in the year ended December 31, 2011 under this note was $5,372,847.

h) In December 2010, we issued 1-year notes payable at 6% per annum in the amount of $300,000 with maturity dates of December 2011. The notes were secured by the Swan Hills Project in Canada. In connection with the notes, the Company granted three-year exercisable warrants to purchase 75,000 shares of Common Shares at $0.50 per share. The fair value of the stock purchase warrants issued in connection with this note of $16,662 was recorded as a debt discount and was amortized over the life of the promissory note.  In September 2011, these notes totaling $300,000 and the accrued interest thereon were paid in full.

A schedule of Maturities of our Debt Obligations as of December 31, 2012 is as follows;

Maturity Date	2013		2014		2015
January	$	565,000	$	1,150,000	$	—
May		—		365,000		—
August		180,000		—		—
October		795,000		75,000		75,000
Totals	$	1,540,000	$	1,590,000	$	75,000

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Note 6 - Income Taxes (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]

	2012		2011
Current
Federal	$	—	$	—
State		9,664		800
Foreign		—		—
Total		9,664		800
Deferred
Federal		—		—
State		—		—
Foreign		—		—
Total		—		—
Total Income Tax Provision	$	9,664	$	800

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

	2012			2011
Amount of expected tax benefit	$	(1,456,563	)	$	(515,000	)
Non-deductible expenses		3,560			4,000
Alternative minimum tax		—			—
State Taxes		9,664			800
Valuation allowance adjustments		1,453,003			511,000
	$	9,664		$	800

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]

	2012			2011
Deferred tax assets (liabilities)
Net operating loss carry forwards	$	14,150,000		$	12,127,000
Oil and gas property basis differences		3,662,000			3,480,000
Stock compensation		793,000			633,000
Other		(990,000	)		(726,000	)
Total deferred tax assets		17,615,000			15,514,000
Valuation allowance		(17,615,000	)		(15,514,000	)
Total net deferred taxes	$	—		$	—

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Accounting Policies, by Policy (Policies)

12 Months Ended

Dec. 31, 2012

Basis of Accounting, Policy [Policy Text Block]

U.S. GAAP—The Company’s financial statements have been prepared in accordance with accounting principles generally accepted within the United States of America (“U.S. GAAP”).

Use of Estimates, Policy [Policy Text Block]

Use of Estimates and Significant Estimates—Certain amounts in GeoPetro’s financial statements are based upon significant estimates, including oil and gas reserve quantities which form the basis for the calculation of depreciation, depletion, amortization and impairment of oil and gas properties, the carrying values of unproved properties, asset retirement obligations, accounting for business combinations and share-based payments, and a provision for income taxes. Actual results could materially differ from those estimates.

Oil and Gas Properties Policy [Policy Text Block]

Oil and Gas Properties—GeoPetro follows the full cost method of accounting for oil and gas producing activities and, accordingly, capitalizes all costs incurred in the acquisition,  exploration, and development of proved oil and gas properties, including the costs of abandoned properties, dry holes, geophysical costs, and annual lease rentals. All general corporate costs are expensed as incurred. In general, sales or other dispositions of oil and gas properties are accounted for as adjustments to capitalized costs, with no gain or loss recorded. Costs incurred for repairs and maintenance are expensed as incurred. Amortization of proved oil and gas properties is computed on the units of production method based on all proved reserves on a country by country basis. Unproved oil and gas properties are assessed for impairment either individually or on an aggregate basis. The net capitalized costs of proved oil and gas properties (full cost ceiling limitation) are not to exceed their related estimated future net revenues discounted at 10%, and the lower of cost or estimated fair value of unproved properties, net of tax considerations.

Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]

Asset Impairment—Under full cost accounting, a ceiling test is performed to ensure that unamortized capitalized costs in each cost center (country) do not exceed their fair value.  Impairment is recognized when the carrying value is greater than the discounted future cash flows.  In the event of impairment, the amount by which the carrying value exceeds the estimated fair value of the long-lived asset is charged to earnings. The present value of estimated future net revenues is computed by applying average oil and gas prices to estimated future production of proved oil and gas reserves as of period-end, less estimated future expenditures to be incurred in developing and producing the proved reserves assuming the continuation of existing economic conditions. SEC rules require that reserve calculations be based on the un-weighted average first-day-of-the-month prices for the prior twelve months. There was no impairment of proved oil and gas properties indicated at either December 31, 2012 or December 31, 2011.

For the unproved properties, the Company evaluates the possibility of potential impairment on a quarterly basis.  During the twelve months ended December 31, 2012 approximately $587,040 of unproved property costs related to Indonesia exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Indonesia full cost pool as negotiations with the Indonesian government for an extension of the Bengara II Production Sharing Contract (“PSC”) have terminated. The PSC shall now be relinquished and allowed to expire in accordance with its terms. In addition, approximately $33,616 of unproved property costs related to Canada exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Canada full cost pool. During the twelve months ended December 31, 2011 approximately $750,133 of unproved property costs related to Indonesia exploration projects were reclassified to proved property and ceiling test impairment was recorded in the Indonesia full cost pool, as the decision was made to terminate CG Xploration and wind down operations.

Interest in Unincorporated Joint Ventures or Partnerships, Policy [Policy Text Block]

Joint Ventures—Some exploration and production activities are conducted jointly with others and, accordingly, the accounts reflect only GeoPetro’s proportionate interest in such activities.

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition—Revenue is recognized upon delivery of gas production.

Asset Retirement Obligations, Policy [Policy Text Block]

Asset Retirement Obligation—The fair value of an asset retirement cost, and corresponding liability, are recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. GeoPetro recorded an asset retirement obligation to reflect GeoPetro’s legal obligations related to future plugging and abandonment of its oil and gas wells. GeoPetro estimated the expected cash flow associated with the obligation and discounted the amount using a credit-adjusted, risk-free interest rate. At least annually, GeoPetro reassesses the obligation to determine whether a change in the estimated obligation is necessary. GeoPetro evaluates whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest the estimated obligation has materially changed, GeoPetro will accordingly update its assessment.

There are asset retirement obligations associated with the Plant. However, components of the Plant can be used for extended and indeterminate periods of time as long as they are properly maintained and/or upgraded. GeoPetro’s intent is to maintain the Plant assets and continue making improvements to those assets based on technological advances. As a result, GeoPetro’s management believes that the Plant has an indeterminate life for purposes of estimating asset retirement obligations because dates or ranges of dates upon which GeoPetro would retire the Plant cannot reasonably be estimated.

	December 31,
	2012		2011
Asset retirement obligations, beginning of period	$	75,000	$	71,510
Liabilities incurred		—		698
Accretion expense		—		2,792
Asset retirement obligations, end of period	$	75,000	$	75,000

Property, Plant and Equipment, Policy [Policy Text Block]

Furniture, Fixtures and Equipment—Furniture, fixtures and equipment are stated at cost. Depreciation is provided on furniture, fixtures and equipment using the straight-line method over an estimated service life of three to seven years.

Income Tax, Policy [Policy Text Block]

Income Taxes—GeoPetro accounts for income taxes using the asset and liability method wherein deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. Because management has determined that realization of deferred tax assets is not more likely than not, the net deferred tax assets are fully reserved.

Concentration Risk, Credit Risk, Policy [Policy Text Block]

Concentrations of Credit Risk—Credit risk represents the accounting loss that would be recognized at the reporting date if counterparties failed completely to perform as contracted. Concentrations of credit risk (whether on or off balance sheet) that arise from financial instruments exist for groups of customers or counterparties when they have similar economic characteristics that would cause their ability to meet contractual obligations to be similarly affected by changes in economic or other conditions described below. The credit risk amounts for cash and accounts receivable do not take into account the value of any collateral or security.

GeoPetro maintains several cash accounts with higher quality financial institutions in amounts which occasionally exceed current federal deposit insurance limits. Senior management continuously reviews these institutions for financial stability. The Company has not experienced any losses in connection with amounts in excess of federal deposit limits.

During the years ended December 31, 2012 and 2011, substantially all of the Company’s natural gas production was sold to Luminant Energy Company, LLC.

At December 31, 2011, all of the Company’s trade accounts receivable — oil and gas sales were due from Luminant Energy Company, LLC.  There were no trade accounts receivable at December 31, 2012.

Receivables, Policy [Policy Text Block]

Trade Accounts Receivable and Allowance for Doubtful Accounts—Accounts receivable, oil and gas sales, consist of uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days.  No interest is charged on past-due balances.  Payments made on all accounts receivable are applied to the earliest unpaid items.  Trade accounts receivable are recorded at net realizable value. If the financial condition of GeoPetro’s customers were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required. Delinquent trade accounts receivable are charged against the allowance for doubtful accounts once uncollectibility has been determined. The allowance is determined through an analysis of the past-due status of accounts receivable and assessments of risk that are based on historical trends and an evaluation of the impact of current and projected economic conditions. There was no allowance for doubtful accounts needed as of December 31, 2012 or 2011.

Fair Value of Financial Instruments, Policy [Policy Text Block]

Fair Value of Financial Instruments—The estimated fair values for financial instruments are determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. For certain of GeoPetro’s financial instruments, including cash, accounts receivable, accounts payable and current portion of notes payable, the carrying amounts approximate fair value due to their maturities.

Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]

Share-Based Payments—The Company has a stock-based compensation plan that allows employees to purchase common shares of the Company. Option exercise prices approximate the market price for the common shares on the date the options were issued. Options granted under the plan are generally fully exercisable after five years and expire five to ten years after the grant date. The Company measures and records stock-based awards to directors, employees and consultants based on the grant-date fair value, determined using the Black-Scholes option pricing model with assumptions for: risk free interest rates, expected dividend yield, expected life of the option, and the expected volatility. The compensation expense was recorded ratably over the requisite service period defined in the award.  The Company recorded $422,999 and $407,311 of stock-based employee compensation for the twelve months ended December 31, 2012 and 2011, respectively. (Note 8)

Earnings Per Share, Policy [Policy Text Block]

Net Loss perCommon Share—Basic net loss per common share is computed by dividing the net loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period.

Diluted net loss per common share is computed in the same manner, but also considers the effect of common stock shares underlying the following:

	Years Ended December 31,
	2012		2011
Stock options (Note 8)		3,445,000		2,770,000
Warrants (Note 9)		5,983,265		5,424,044
Convertible preferred stock, Series B		5,423,000		5,423,000

All of the common shares underlying the stock options and warrants above were excluded from diluted weighted average shares outstanding for each of the years in the period ended December 31, 2012 and 2011 because their effects were antidilutive.

Segment Reporting, Policy [Policy Text Block]

Segment Reporting—GeoPetro has oil and gas exploration, development and production operations in the United States, Canada, Australia and Indonesia. All revenues and related costs are associated with operations in the United States. A summary of assets and capital expenditures by geographical segment is included in Note 4.

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash and Cash Equivalents—Cash and cash equivalents include cash on hand, amounts held in banks and highly liquid investments purchased with an original maturity of three months or less.

Reclassification, Policy [Policy Text Block]

Reclassification—Certain prior year amounts have been reclassified for consistency in reporting with current year amounts to avoid confusion.  Sublease income has been included as a reduction in general and administrative expenses in the accompanying statements of operations.

New Accounting Pronouncements, Policy [Policy Text Block]

Recently Issued Accounting Pronouncements— The Company has evaluated recent accounting pronouncements and their adoption and we have not identified any that would have a material impact on the Company’s financial position, or statements.

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Note 9 - Common Stock Warrants

12 Months Ended

Dec. 31, 2012

Common Stock Warrants Disclosure [Text Block]

9.         COMMON STOCK WARRANTS

In February 2012, warrants for 50,000 shares with an exercise price of $1.00 per share expired.

In March 2012, we issued 20,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of a note payable to Stuart J. Doshi, President and CEO, for $100,000 (Note 5). The warrants expire in March 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,609.

In March 2012, we issued 500,000 warrants to purchase our common shares at $0.50 per share in conjunction with a private placement of our common stock (Note 7). The warrants expire in March 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $40,070.

 In May 2012, we extended 151,500 warrants to purchase our common shares for an additional year and reduced the exercise price to purchase the common shares from $1.00 to $0.50 per share in connection with the extension of seven notes payable totaling $1,515,000 (Note 5). The extended warrants expire in December 2013, May 2014 and June 2014.  The total fair value of the extension of the warrants as calculated using the Black-Scholes pricing model was $3,575.

In May 2012, we issued 15,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of two notes payable to Stuart J. Doshi, President and CEO, totaling $75,000 (Note 5). The warrants expire in May 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $561.

In June 2012, we issued 45,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of four notes payable to Stuart J. Doshi, President and CEO, totaling $225,000 (Note 5). The warrants expire in June 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,481.

In July 2012, we issued 15,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of two notes payable to Stuart J. Doshi, President and CEO, totaling $75,000 (Note 5). The warrants expire in July 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $315. 

In August 2012, warrants for 600,779 shares with an exercise price of $4.50 per share expired.

In August 2012, we issued 45,000 warrants to purchase our common shares at $0.50 per share in exchange for certain consulting services. The warrants expire in August 2016.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $2,986.

In September 2012, warrants for 14,000 shares with an exercise price of $1.00 per share expired.

In October 2012, we issued 72,000 warrants to purchase our common shares at a price ranging from $0.10 to $0.23 per share in exchange for certain consulting services. The warrants expire in October 2017.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $5,887.

In October 2012, warrants for 36,000 shares with an exercise price of $1.00 per share expired.

In November 2012, we issued 12,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of two notes payable to Stuart J. Doshi, President and CEO, totaling $60,000 (Note 5). The warrants expire in November 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $413.

In November 2012, we issued 30,000 warrants to purchase our common shares at $0.50 per share in exchange for certain consulting services. The warrants expire in November 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,014.

In November 2012, warrants for 50,000 shares with an exercise price of $1.25 per share expired.

In November 2012, we issued 50,000 warrants to purchase our common shares at $0.50 per share in conjunction with a private placement of our common stock (Note 7). The warrants expire in November 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $1,452.

In December 2012, we issued 6,000 warrants to purchase our common shares at $0.50 per share in connection with the issuance of a note payable to Stuart J. Doshi, President and CEO, for $30,000 (Note 5). The warrants expire in December 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $141.

In December 2012, we issued 500,000 warrants to purchase our common shares at $0.50 per share in conjunction with a private placement of our common stock (Note 7). The warrants expire in December 2015.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $18,429.

The fair value of the warrants for 2012 was calculated using the Black-Scholes pricing model. Key assumptions used in valuing the warrants included: an estimated dividend yield of 0%; volatility between 81% to 137%; an estimated risk-free interest rate based on the U.S. Treasury yield curve at the date of grant of between 0.27% to 0.80%; and an expected life of three to five years.

In February 2011 we extended a total of 151,500 warrants for an additional year in conjunction with the renewal of seven of our promissory notes payable (Note 5). The warrants expire in December 2012, May 2013, and June 2013, respectively.  The total fair value of the extension of the warrants as calculated using the Black-Scholes pricing model was $7,788.

In March 2011, we issued 1,025,164 warrants to purchase our common shares at $0.75 in conjunction with a private placement of our common stock (Note 7). The warrants expire in March 2014.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $207,943.

In April 2011, we issued 505,965 warrants to purchase our common shares at $1.00 in conjunction with a private placement of our common stock (Note 7). The warrants expire in April 2014.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $165,105.

In August 2011 we extended 150,000 warrants for an additional two years.  The warrants expire in January 2014.  The total fair value of the extension of the warrants as calculated using the Black-Scholes pricing model was $17,539.

In September 2011, we issued 10,000 warrants to purchase our common shares at $0.50 in conjunction with the renewal of one of our promissory notes payable (Note 5).  The warrants expire in August 2014.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $2,204.

In September 2011, warrants for 27,150 shares with an exercise price of $1.00 per share expired.

In November 2011, we issued 27,000 warrants to purchase our common shares at $0.50 in conjunction with the renewal of four of our promissory notes payable (Note 5).  The warrants expire in November 2013.  The total fair value of the warrants as calculated using the Black-Scholes pricing model was $3,170.

In December 2011, warrants for 114,000 shares with an exercise price of $3.50 per share expired and warrants for 35,000 shares with an exercise price of $1.00 per share expired.

The fair value of the warrants for 2011 was calculated using the Black-Scholes pricing model. Key assumptions used in valuing the warrants included: an estimated dividend yield of 0%; volatility of between 78% to 140%; an estimated risk-free interest rate based on the U.S. Treasury yield curve at the date of grant of between 0.23% to 1.15%; and an expected life of between two and three years.

The following table summarizes the number of shares reserved for the exercise of common stock purchase warrants as of December 31, 2012:

Expiration	Exercise		Outstanding at		Warrants		Warrants		Warrants			Outstanding at
Date	Price		12/31/2011		Exercised		Granted		(Expired/Canceled)			12/31/2012
02/22/12	$	1.00		50,000		—		—		(50,000	)		—
08/13/12	$	4.50		600,779		—		—		(600,779	)		—
09/30/12	$	1.00		14,000		—		—		(14,000	)		—
10/22/12	$	1.00		36,000		—		—		(36,000	)		—
11/22/12	$	1.25		50,000		—		—		(50,000	)		—
08/31/13	$	0.50		23,000		—		—		—			23,000
09/29/13	$	0.75		1,847,500		—		—		—			1,847,500
10/31/13	$	0.50		72,000		—		—		—			72,000
11/30/13	$	0.50		27,000		—		—		—			27,000
12/23/13	$	0.50		120,000		—		—		—			120,000
12/25/13	$	0.50		40,000		—		—		—			40,000
12/30/13	$	0.75		555,596		—		—		—			555,596
01/02/14	$	1.00		150,000		—		—		—			150,000
03/01/14	$	0.75		1,025,164		—		—		—			1,025,164
03/31/14	$	5.25		100,000		—		—		—			100,000
04/28/14	$	1.00		505,965		—		—		—			505,965
05/17/14	$	0.50		36,500		—		—		—			36,500
06/29/14	$	0.50		30,000		—		—		—			30,000
08/31/14	$	0.50		10,000		—		—		—			10,000
10/19/14	$	1.00		130,540		—		—		—			130,540
03/20/15	$	0.50		—		—		20,000		—			20,000
03/21/15	$	0.50		—		—		500,000		—			500,000
05/29/15	$	0.50		—		—		5,000		—			5,000
05/30/15	$	0.50		—		—		10,000		—			10,000
06/04/15	$	0.50		—		—		8,000		—			8,000
06/18/15	$	0.50		—		—		5,000		—			5,000
06/25/15	$	0.50		—		—		12,000		—			12,000
06/29/15	$	0.50		—		—		20,000		—			20,000
07/27/15	$	0.50		—		—		2,000		—			2,000
07/31/15	$	0.50		—		—		13,000		—			13,000
11/09/15	$	0.50		—		—		2,000		—			2,000
11/20/15	$	0.50		—		—		10,000		—			10,000
11/21/15	$	0.50		—		—		30,000		—			30,000
11/29/15	$	0.50		—		—		50,000		—			50,000
12/04/15	$	0.50		—		—		6,000		—			6,000
12/10/15	$	0.50		—		—		125,000		—			125,000
12/31/15	$	0.50		—		—		375,000		—			375,000
08/15/16	$	0.50		—		—		45,000		—			45,000
10/01/17	$	0.23		—		—		12,000		—			12,000
10/01/17	$	0.21		—		—		12,000		—			12,000
10/01/17	$	0.20		—		—		12,000		—			12,000
10/01/17	$	0.17		—		—		12,000		—			12,000
10/01/17	$	0.14		—		—		12,000		—			12,000
10/01/17	$	0.10		—		—		12,000		—			12,000
				5,424,044		—		1,310,000		(750,779	)		5,983,265

The following table summarizes the number of shares reserved for the exercise of common stock purchase warrants as of December 31, 2011:

Expiration	Exercise		Outstanding at		Warrants		Warrants		Warrants			Outstanding at
Date	Price		12/31/2010		Exercised		Granted		(Expired/Canceled)			12/31/2011
09/30/11	$	1.00		27,150		—		—		(27,150	)		—
12/15/11	$	3.50		114,000		—		—		(114,000	)		—
12/22/11	$	1.00		35,000		—		—		(35,000	)		—
02/22/12	$	1.00		50,000		—		—		—			50,000
08/13/12	$	4.50		600,779		—		—		—			600,779
09/30/12	$	1.00		14,000		—		—		—			14,000
10/22/12	$	1.00		36,000		—		—		—			36,000
11/22/12	$	1.25		50,000		—		—		—			50,000
12/23/12	$	1.00		45,000		—		—		—			45,000
12/25/12	$	1.00		40,000		—		—		—			40,000
05/17/13	$	1.00		36,500		—		—		—			36,500
06/29/13	$	1.00		30,000		—		—		—			30,000
08/31/13	$	0.50		23,000		—		—		—			23,000
09/29/13	$	0.75		1,847,500		—		—		—			1,847,500
10/31/13	$	0.50		72,000		—		—		—			72,000
11/30/13	$	0.50		—		—		27,000		—			27,000
12/23/13	$	0.50		75,000		—		—		—			75,000
12/30/13	$	0.75		555,596		—		—		—			555,596
01/02/14	$	1.00		150,000		—		—		—			150,000
03/01/14	$	0.75		—		—		1,025,164		—			1,025,164
03/31/14	$	5.25		100,000		—		—		—			100,000
04/28/14	$	1.00		—		—		505,965		—			505,965
08/31/14	$	0.50		—		—		10,000		—			10,000
10/19/14	$	1.00		130,540		—		—		—			130,540
				4,032,065		—		1,568,129		(176,150	)		5,424,044

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Note 7 - Shareholders' Equity

12 Months Ended

Dec. 31, 2012

Stockholders' Equity Note Disclosure [Text Block]

7.         SHAREHOLDERS’ EQUITY

GeoPetro’s articles of incorporation allow for the issuance of 100,000,000 shares of common stock, 1,000,000 shares of Series A preferred stock, 5,000,000 shares of Series AA preferred stock, and an additional 44,000,000 shares of preferred stock which may be issued from time to time in one or more series, with such rights and preferences as determined by our Board of Directors.

Common Stock—The holders of our common stock are entitled to one vote per share. Subject to preferences on outstanding preferred stock, the holders of common stock are entitled to receive ratably such dividends as may be declared by the board of directors. In the event of a liquidation, the holders of common stock are entitled to share ratably in all assets remaining after payment of liabilities, subject to prior distribution rights of preferred stock.

In March 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.25 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $250,000, and represented the sale of 1,000,000 common shares and 500,000 warrants (Note 9).  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In August 2012, we agreed to issue 225,000 shares of common stock to our independent directors. The shares were valued at the closing price of $0.14 per share and have been recorded as share-based compensation in the financial statements.  The aggregate value of the shares issued was $31,500.  We agreed to grant "piggyback" registration rights to the directors with respect to the shares of common stock.

In November 2012, we completed a unit sale through a private placement transaction to an individual accredited investor. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $10,000, and represented the sale of 100,000 common shares and 50,000 warrants (Note 9).  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In December 2012, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.10 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.50 for a period of three years. The total aggregate purchase price for the units sold was $100,000, and represented the sale of 1,000,000 common shares and 500,000 warrants (Note 9).  We agreed to grant "piggyback" registration rights to the investor with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investor acquired in the transaction.

In March 2011, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.45 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $0.75 for a period of three years. The total aggregate purchase price for the units sold was $922,648, and represented the sale of 2,050,328 common shares and 1,025,164 warrants (Note 9).  We granted “piggyback” registration rights to the investors with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investors acquired in the transaction.

In June 2011, we completed a unit sale through a private placement transaction to certain institutional and individual accredited investors. Units were priced at $0.55 per unit, and each unit consisted of one share of no par value common stock, and a one-half common share purchase warrant. Each one whole warrant entitles the holder to acquire one common share at a price of $1.00 for a period of three years. The total aggregate purchase price for the units sold was $556,560, and represented the sale of 1,011,928 common shares and 505,965 warrants (Note 9).  We granted “piggyback” registration rights to the investors with respect to the shares of common stock and common stock issuable upon exercise of the warrants which the investors acquired in the transaction.

Series B Preferred Stock— As of December 31, 2012, there are 5,423,000 shares of Series B Stock issued and outstanding.  The holders of Series B Stock are entitled to receive an annual dividend at the rate of $0.06 per share and are entitled to such number of votes per share as equals the number of common shares into which each share of Series B Stock is convertible. Each share of Series B Stock is convertible, at the option of the holder, into fully paid and non-assessable common shares on a one-for-one basis, subject to certain adjustments. The Series B Stock will automatically convert into common shares on a one-for-one share basis effective the first trading day after the reported high selling price for the Company’s common shares on any international, national or regional securities exchange or inter-dealer quotation system including but not limited to, NASDAQ, the Pink Sheets or the Over-the-Counter Bulletin Board, is at least $1.50 per share for any ten consecutive trading days. If an automatic conversion occurs within one year after the Series B Stock was purchased from the Company, a holder will receive, on the one-year anniversary date of his, her or its purchase, a cash dividend equivalent to a full year of dividends less any dividends paid before such conversion. In 2012 and 2011, we incurred $325,380 and $434,639 in dividends on the Series B Stock, respectively, of which $0 and $0 were paid in 2012 and 2011, respectively.

In March 2011, a holder of 20,000 shares of the Company’s Series B Preferred Stock, converted shares on a one-for-one basis into fully paid and non-assessable shares of the Company’s Common Stock.

In July 2011, a holder of 80,000 shares of the Company’s Series B Preferred Stock, converted shares on a one-for-one basis into fully paid and non-assessable shares of the Company’s Common Stock.

In November 2011, holders of 2,000,000 shares of the Company’s Series B Preferred Stock, converted shares on a one-for-one basis into fully paid and non-assessable shares of the Company’s Common Stock.

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Note 8 - Common Stock Options

12 Months Ended

Dec. 31, 2012

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

8.         COMMON STOCK OPTIONS

Effective as of September 10, 2001, the board of directors approved an incentive stock plan (“Stock Incentive Plan”), providing for awards under the terms and provisions of such plan of incentive stock options, stock appreciation rights and restricted stock awards to officers, directors and employees of GeoPetro and its consultants. The plan provides, among other provisions, the following:

· The maximum number of Common Shares which may be awarded, optioned and sold under the plan is 5,000,000 (subject to adjustment for stock splits, stock dividends and certain other adjustments to GeoPetro’s common stock); and the per share exercise price for Common Shares to be issued pursuant to the exercise of an option shall be no less than the fair market value of GeoPetro’s Common Shares as of the date of grant;

· The Stock Incentive Plan provides for the granting to employees incentive stock options within the meaning of Section 422 of the United States Internal Revenue Code of 1986, as amended, and for the granting of non-statutory stock options to directors who are not employees and consultants. In the case of employees who receive incentive stock options which are first exercisable in a particular calendar year and the aggregate fair market value of which exceeds $100,000, the excess of the $100,000 limitation shall be treated as a nonstatutory stock option under the Stock Incentive Plan;

· The Stock Incentive Plan is being administered by the Board of Directors. The Board of Directors determines the terms of the options granted, including the number of Common Shares subject to each option, the exercisability and vesting requirements of each option, and the form of consideration payable upon the exercise of such option (i.e., whether cash or exchange of existing Common Shares in a cashless transaction or a combination thereof); and

· The Stock Incentive Plan will continue in effect for 10 years from September 10, 2001 (i.e., the date first adopted by the Board), unless sooner terminated by the board of directors. In 2004, we implemented a new 2004 Stock Option and Appreciation Rights Plan (“Stock Option Plan”) providing for awards of incentive stock options, non-qualified stock options and stock appreciation rights. The Stock Option Plan replaced the Stock Incentive Plan as to new award grants effective in 2004 or thereafter to our directors, officers, employees and consultants. Outstanding awards issued under the Stock Incentive Plan will continue to be outstanding in accordance with their terms and the terms of the Stock Incentive Plan, but will count toward the limits in the number of shares of common stock available to be issued under the Stock Option Plan, which is 5,000,000. The exercise price of stock options granted under the Stock Option Plan may not be less than 110% of the fair market value of our common stock on the date of grant.

In August 2012, we granted 675,000 stock options at an exercise price of $0.16 per share.  These options will vest ratably over five years pursuant to the terms of the Stock Option Plan.  The grant date fair value of the options was $70,831.

In April 2011, 150,000 common stock options with an exercise price of $3.85 per share expired.

In August 2011, we granted 25,000 stock options at an exercise price of $0.50 per share.  These options will vest ratably over five years pursuant to the terms of the Stock Option Plan.  The grant date fair value of the options was $6,852.

The Company recorded stock compensation expense of $422,999 and $407,311 for the twelve months period ended December 31, 2012 and 2011, respectively.

A summary of the status of GeoPetro’s stock option plan is as follows:

	Options			Exercise Prices			Weighted Average Exercise Price
Outstanding at January 1, 2011		2,895,000		$0.50	to	$3.85	$	1.59
Granted		25,000			$0.50			0.50
Exercised		—			—			—
Expired		(150,000	)		$3.85			3.85
Outstanding at December 31, 2011		2,770,000		$0.50	to	$2.10		1.46
Granted		675,000			$0.16			0.16
Exercised		—			—			—
Expired		—			—			—
Outstanding at December 31, 2012		3,445,000		$0.16	to	$2.10	$	1.21

We estimated the fair values of each option granted using the Black-Scholes model with the following assumptions for options granted during the years ended December 31:

	2012			2011
Expected dividend yield		—			—
Expected volatility		105.6	%		149.8	%
Risk-free interest rates		0.59	%		0.99	%
Expected lives (years)		5			5
Weighted average fair values per share	$	0.11		$	0.27

 We estimated the dividend yield at 0% considering that we have not historically paid dividends on our common stock, nor do we expect to pay dividends in the foreseeable future.  Volatility estimates represent the historic trading volatility underlying our common stock at the date of grant.  We estimated risk-free interest rates based on the U.S. Treasury yield curve at the date of grant.  Expected lives are based on our historic experience with employee option exercise behavior and consider the vesting period and the contractual lives of the related options.

The options outstanding as of December 31, 2012 have the following contractual lives:

Number of Options Outstanding		Number of Options Exercisable		Exercise Prices		Weighted Average Remaining Contractual Life
	675,000		—		0.16		4.67
	960,000		675,000		0.50		0.99
	210,000		186,000		1.00		0.68
	1,600,000		1,600,000		2.10		0.39
	3,445,000		2,461,000

The total intrinsic value of options outstanding was $nil at December 31, 2012 and 2011, respectively. The intrinsic value for exercisable options was $nil at December 31, 2012 and 2011, respectively.

As of December 31, 2012, there are 2,461,000 options which are exercisable. The remaining 984,000 options will become exercisable over the next four years. The stock compensation expense related to the unvested awards is $286,951. The weighted average remaining contractual life of the remaining 984,000 unvested options is 3.69 years.

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Note 10 - Commitments and Contingencies

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies Disclosure [Text Block]

10.       COMMITMENTS AND CONTINGENCIES

Employment Agreements—The Company entered into a contract of employment with Stuart J. Doshi, Founder, President, Chief Executive Officer and Chairman of the Board of Directors, as amended through December 31, 2008. The contract, as amended, provides for a five-year term commencing May 1, 2005 which term is automatically extended for successive two-year renewal terms unless: (a) the board of directors elects not to renew the contract and the Company provides notice to Mr. Doshi of such non-renewal at least six months prior to the expiry of his employment term or any renewal term, or (b) Mr. Doshi attains age 75, in which case the term ends upon the completion of the calendar year in which he becomes 75 years old unless the Company and Mr. Doshi mutually agree to one-year extensions. The contract of employment currently provides for an annual base salary of $300,000 and further provides that in the event of a change of control of the Company or if Mr. Doshi is terminated without cause, he is entitled to receive (a) in exchange for all of his vested stock options and vested restricted shares, such number of Common Shares having a market value equal to the difference between (x) the aggregate total market value of all vested restricted shares and Common Shares he would receive upon exercise of all vested stock options less (y) the aggregate total exercise price for all of his vested stock options; provided, however, that if the Common Shares to be delivered to Mr. Doshi upon such change of control or termination have not been registered so as to permit immediate public resale, Mr. Doshi shall instead receive a cash payment equal to the market value on the date of termination of all vested stock options and restricted shares without any discount for liquidity or minority position against cancellation of such options and restricted shares, (b) a cash payment equal to the greater of (i) his compensation for the remainder of his term, including salary and the aggregate amount of his bonuses in respect of the last four fiscal years and (ii) four times his compensation in the current year, including his then-current salary and the average amount of his bonuses for the last four fiscal years, and (c) an additional cash payment representing his employment benefits equal to 20% of the amount of salary he is entitled to receive under (b)(i) or (b)(ii) above, as applicable. In addition, in the event of a change of control or termination without cause, all unvested options issued by the Company to Mr. Doshi will vest.

Office Lease—On February 15, 2010, we entered into a new lease for our principal executive office located at 150 California Street, Suite 600, San Francisco, CA 94111.  The terms of the lease provide for an eighty-four (84) month term. Minimum annual rentals due under this agreement as of December 31, 2012 are as follows:

2013	$	154,037
2014	158,238
2015	162,439
2016	166,640
2017	56,013
Total	$	697,367

Rent expense for the years ended December 31, 2012 and 2011, was approximately $144,834 and $144,834, respectively, and is included in general and administrative expenses in the accompanying statements of operations.

On January 6, 2011, we entered into a sublease agreement whereby a portion of the Company’s principal executive offices have been leased to a third party. The terms of the sublease agreement include a seventy-five month term cancelable by either party with ninety days written notice after December 31, 2011. The Company will recoup approximately 50% of the base rental obligation through the sublease agreement. This amount was approximately $82,419 and $67,289 for the years ended December 31, 2012 and 2011, respectively, and has been included as a reduction in general and administrative expenses in the accompanying statements of operations.

Madisonville Net Profits Interest—Redwood LP’s 100% working interest is subject to a net profits interest in favor of unrelated third parties. The net profits interest is 12.5% (proportionately reduced) of the net operating profits until payout is achieved. After payout, the net profits interest increases to 30% (proportionately reduced). Payout, for purposes of the net profits interest, is defined and achieved at such time as Redwood LP has recouped from net operating cash flows its total net investment in the project plus a 33% cash on cash return.

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Note 4 - Summary of Oil and Gas Operations (Detail) - Costs incurred (USD $)	12 Months Ended				48 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2012
Exploration	$ 213,976	$ 68,624	$ 201,234	$ 3,890,851	$ 4,374,685
Development	16,841	884,831
Total costs incurred	230,817	1,382,153
Gas processing plant upgrade		428,698
United States [Member]
Exploration	149,037	66,277
Development	16,841	878,476
Total costs incurred	165,878	1,373,451
Gas processing plant upgrade		428,698
Canada [Member]
Exploration	64,939	2,347
Development		6,355
Total costs incurred	$ 64,939	$ 8,702

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Note 10 - Commitments and Contingencies (Detail) - Minimum annual rentals due under lease agreement (USD $)	Dec. 31, 2012
2013	$ 154,037
2014	158,238
2015	162,439
2016	166,640
2017	56,013
Total	$ 697,367

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Note 4 - Summary of Oil and Gas Operations (Tables)

12 Months Ended

Dec. 31, 2012

Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]

	United States			Australia			Indonesia			Canada			Totals
Proved properties	$	46,621,800		$	2,388,051		$	1,361,817		$	2,719,275		$	53,090,943
Unproved properties		4,635,781			1,522,718			—			366,320			6,524,819
Gas processing plant		5,533,910			—			—			—			5,533,910
Less—accumulated depletion and impairment		(35,156,126	)		(2,388,051	)		(1,361,817	)		(2,719,275	)		(41,625,269	)
Net capitalized costs	$	21,635,365		$	1,522,718		$	—		$	366,320		$	23,524,403

	United States			Australia			Indonesia			Canada			Totals
Proved properties	$	47,128,745		$	2,388,051		$	774,777		$	2,685,659		$	52,977,232
Unproved properties		4,486,744			1,522,718			587,040			334,997			6,931,499
Gas processing plant		5,533,910			—			—			—			5,533,910
Less—accumulated depletion and impairment		(34,974,595	)		(2,388,051	)		(774,777	)		(2,685,659	)		(40,823,082	)
Net capitalized costs	$	22,174,804		$	1,522,718		$	587,040		$	334,997		$	24,619,559

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]

Exploration	$	149,037	$	—	$	—	$	64,939	$	213,976
Development		16,841		—		—		—		16,841
Total costs incurred	$	165,878	$	—	$	—	$	64,939	$	230,817

Gas processing plant upgrade	$	428,698	$	—	$	—	$	—	$	428,698
Exploration		66,277		—		—		2,347		68,624
Development		878,476		—		—		6,355		884,831
Total costs incurred	$	1,373,451	$	—	$	—	$	8,702	$	1,382,153

Unproved Properties Disclosure [Table Text Block]

			Year Ended		Year Ended		Year Ended
			December 31,		December 31,		December 31,		2009 and Prior
	Totals		2012		2011		2010		Years
Unproved property acquisition	$	2,150,134	$	—	$	—	$	—	$	2,150,134
Exploration		4,374,685		213,976		68,624		201,234		3,890,851
Total	$	6,524,819	$	213,976	$	68,624	$	201,234	$	6,040,985

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Note 10 - Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

2013	$	154,037
2014	158,238
2015	162,439
2016	166,640
2017	56,013
Total	$	697,367

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Note 9 - Common Stock Warrants (Detail) - The number of shares reserved for the exercise of common stock purchase warrants	3 Months Ended	12 Months Ended																																																								1 Months Ended	12 Months Ended																											1 Months Ended	12 Months Ended											1 Months Ended	12 Months Ended											1 Months Ended	12 Months Ended									1 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended		12 Months Ended		1 Months Ended	12 Months Ended		12 Months Ended		12 Months Ended		12 Months Ended		1 Months Ended	12 Months Ended		12 Months Ended		1 Months Ended	12 Months Ended		12 Months Ended		1 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended		2 Months Ended	12 Months Ended		12 Months Ended		2 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended		12 Months Ended		12 Months Ended		12 Months Ended		12 Months Ended		12 Months Ended
	Oct. 31, 2009	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Jun. 30, 2009	May 31, 2009	Dec. 31, 2012 Expiration on 02/22/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 02/22/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 02/22/12 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 02/22/12 [Member]	Feb. 22, 2012 Expiration on 02/22/12 [Member]	Dec. 31, 2011 Expiration on 02/22/12 [Member]	Dec. 31, 2012 Expiration on 08/13/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 08/13/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 08/13/12 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 08/13/12 [Member]	Aug. 13, 2012 Expiration on 08/13/12 [Member]	Dec. 31, 2011 Expiration on 08/13/12 [Member]	Dec. 31, 2012 Expiration on 09/30/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 09/30/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 09/30/12 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 09/30/12 [Member]	Sep. 30, 2012 Expiration on 09/30/12 [Member]	Dec. 31, 2011 Expiration on 09/30/12 [Member]	Dec. 31, 2012 Expiration on 10/22/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 10/22/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 10/22/12 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/22/12 [Member]	Oct. 31, 2012 Expiration on 10/22/12 [Member]	Dec. 31, 2011 Expiration on 10/22/12 [Member]	Dec. 31, 2012 Expiration on 11/22/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 11/22/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 11/22/12 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 11/22/12 [Member]	Nov. 30, 2012 Expiration on 11/22/12 [Member]	Dec. 31, 2011 Expiration on 11/22/12 [Member]	Dec. 31, 2012 Expiration on 08/31/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 08/31/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 08/31/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 08/31/13 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 08/31/13 [Member]	Dec. 31, 2011 Expiration on 08/31/13 [Member]	Dec. 31, 2012 Expiration on 09/29/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 09/29/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 09/29/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 09/29/13 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 09/29/13 [Member]	Dec. 31, 2011 Expiration on 09/29/13 [Member]	Dec. 31, 2012 Expiration on 10/31/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 10/31/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 10/31/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 10/31/13 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/31/13 [Member]	Dec. 31, 2011 Expiration on 10/31/13 [Member]	Dec. 31, 2012 Expiration on 11/30/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 11/30/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 11/30/13 [Member] Ending Period [Member]	Nov. 30, 2011 Expiration on 11/30/13 [Member]	Dec. 31, 2011 Expiration on 11/30/13 [Member]	Dec. 31, 2012 Expiration on 11/30/13 [Member]	Dec. 31, 2012 Expiration on 12/23/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 12/23/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 12/23/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 12/23/13 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 12/23/13 [Member]	Dec. 31, 2011 Expiration on 12/23/13 [Member]	Dec. 31, 2012 Expiration on 12/25/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 12/25/13 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 12/25/13 [Member]	Dec. 31, 2012 Expiration on 12/30/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 12/30/13 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 12/30/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 12/30/13 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 12/30/13 [Member]	Dec. 31, 2011 Expiration on 12/30/13 [Member]	Dec. 31, 2012 Expiration on 01/02/14 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 01/02/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 01/02/14 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 01/02/14 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 01/02/14 [Member]	Dec. 31, 2011 Expiration on 01/02/14 [Member]	Aug. 31, 2011 Expiration on 01/02/14 [Member]	Dec. 31, 2012 Expiration on 03/01/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 03/01/14 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 03/01/14 [Member] Ending Period [Member]	Mar. 31, 2012 Expiration on 03/01/14 [Member]	Dec. 31, 2011 Expiration on 03/01/14 [Member]	Dec. 31, 2012 Expiration on 03/01/14 [Member]	Dec. 31, 2012 Expiration on 03/31/14 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 03/31/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 03/31/14 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 03/31/14 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 03/31/14 [Member]	Dec. 31, 2011 Expiration on 03/31/14 [Member]	Dec. 31, 2012 Expiration on 04/28/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 04/28/14 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 04/28/14 [Member] Ending Period [Member]	Apr. 30, 2011 Expiration on 04/28/14 [Member]	Dec. 31, 2011 Expiration on 04/28/14 [Member]	Dec. 31, 2012 Expiration on 04/28/14 [Member]	Dec. 31, 2012 Expiration on 05/17/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 05/17/14 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 05/17/14 [Member]	Dec. 31, 2012 Expiration on 06/29/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 06/29/14 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 06/29/14 [Member]	Dec. 31, 2012 Expiration on 08/31/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 08/31/14 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 08/31/14 [Member] Ending Period [Member]	Sep. 30, 2011 Expiration on 08/31/14 [Member]	Dec. 31, 2011 Expiration on 08/31/14 [Member]	Dec. 31, 2012 Expiration on 08/31/14 [Member]	Dec. 31, 2012 Expiration on 10/19/14 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 10/19/14 [Member] Beginning Period [Member]	Dec. 31, 2012 Expiration on 10/19/14 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 10/19/14 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/19/14 [Member]	Dec. 31, 2011 Expiration on 10/19/14 [Member]	Dec. 31, 2012 Expiration on 03/20/15 [Member] Ending Period [Member]	Mar. 31, 2012 Expiration on 03/20/15 [Member]	Dec. 31, 2012 Expiration on 03/20/15 [Member]	Dec. 31, 2012 Expiration on 03/21/15 [Member] Ending Period [Member]	Mar. 31, 2012 Expiration on 03/21/15 [Member]	Dec. 31, 2012 Expiration on 03/21/15 [Member]	Dec. 31, 2012 Expiration on 05/29/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 05/29/15 [Member]	Dec. 31, 2012 Expiration on 05/30/15 [Member] Ending Period [Member]	May 31, 2012 Expiration on 05/30/15 [Member]	Dec. 31, 2012 Expiration on 05/30/15 [Member]	Dec. 31, 2012 Expiration on 06/04/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 06/04/15 [Member]	Dec. 31, 2012 Expiration on 06/18/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 06/18/15 [Member]	Dec. 31, 2012 Expiration on 06/25/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 06/25/15 [Member]	Dec. 31, 2012 Expiration on 06/29/15 [Member] Ending Period [Member]	Jun. 30, 2012 Expiration on 06/29/15 [Member]	Dec. 31, 2012 Expiration on 06/29/15 [Member]	Dec. 31, 2012 Expiration on 07/27/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 07/27/15 [Member]	Dec. 31, 2012 Expiration on 07/31/15 [Member] Ending Period [Member]	Jul. 31, 2012 Expiration on 07/31/15 [Member]	Dec. 31, 2012 Expiration on 07/31/15 [Member]	Dec. 31, 2012 Expiration on 11/09/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 11/09/15 [Member]	Dec. 31, 2012 Expiration on 11/20/15 [Member] Ending Period [Member]	Nov. 30, 2012 Expiration on 11/20/15 [Member]	Dec. 31, 2012 Expiration on 11/20/15 [Member]	Dec. 31, 2012 Expiration on 11/21/15 [Member] Ending Period [Member]	Nov. 30, 2012 Expiration on 11/21/15 [Member]	Dec. 31, 2012 Expiration on 11/21/15 [Member]	Dec. 31, 2012 Expiration on 11/29/15 [Member] Ending Period [Member]	Nov. 30, 2012 Expiration on 11/29/15 [Member]	Dec. 31, 2012 Expiration on 11/29/15 [Member]	Dec. 31, 2012 Expiration on 12/04/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 12/04/15 [Member]	Dec. 31, 2012 Expiration on 12/04/15 [Member]	Dec. 31, 2012 Expiration on 12/10/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 12/10/15 [Member]	Dec. 31, 2012 Expiration on 12/31/15 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 12/31/15 [Member]	Dec. 31, 2012 Expiration on 12/31/15 [Member]	Dec. 31, 2012 Expiration on 08/15/16 [Member] Ending Period [Member]	Aug. 31, 2012 Expiration on 08/15/16 [Member]	Dec. 31, 2012 Expiration on 08/15/16 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 1 [Member] Ending Period [Member]	Oct. 31, 2012 Expiration on 10/01/17 Grant 1 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 1 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 2 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 2 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 3 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 3 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 4 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 4 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 5 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 5 [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 6 [Member] Ending Period [Member]	Dec. 31, 2012 Expiration on 10/01/17 Grant 6 [Member]	Dec. 31, 2011 Expiration on 09/30/11 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 09/30/11 [Member]	Sep. 30, 2011 Expiration on 09/30/11 [Member]	Dec. 31, 2011 Expiration on 12/15/11 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 12/15/11 [Member]	Dec. 15, 2011 Expiration on 12/15/11 [Member]	Dec. 31, 2011 Expiration on 12/22/11 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 12/22/11 [Member]	Dec. 22, 2011 Expiration on 12/22/11 [Member]	Dec. 31, 2011 Expiration on12/23/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on12/23/12 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on12/23/12 [Member]	Dec. 31, 2011 Expiration on 12/25/12 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 12/25/12 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 12/25/12 [Member]	Dec. 31, 2011 Expiration on 05/17/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 05/17/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 05/17/13 [Member]	Dec. 31, 2011 Expiration on 06/29/13 [Member] Beginning Period [Member]	Dec. 31, 2011 Expiration on 06/29/13 [Member] Ending Period [Member]	Dec. 31, 2011 Expiration on 06/29/13 [Member]	Dec. 31, 2012 Beginning Period [Member]	Dec. 31, 2011 Beginning Period [Member]	Dec. 31, 2012 Ending Period [Member]	Dec. 31, 2011 Ending Period [Member]
Exercise price (in Dollars per Item)				0.50	1.00	1.00				1.00	1.00	1.00				4.50	4.50	4.50				1.00	1.00	1.00				1.00	1.00	1.00				1.25	1.25	1.25					0.50	0.50					0.75	0.75					0.50	0.50				0.50	0.50	0.50					0.50	0.50			0.50					0.75	0.75					1.00	1.00					0.75	0.75	0.75					5.25	5.25				1.00	1.00	1.00			0.50			0.50				0.50	0.50	0.50					1.00	1.00		0.50	0.50		0.50	0.50		0.50		0.50	0.50		0.50		0.50		0.50		0.50	0.50		0.50		0.50	0.50		0.50		0.50	0.50		0.50	0.50		0.50	0.50		0.50	0.50		0.50		0.50	0.50		0.50	0.50			0.23		0.21		0.20		0.17		0.14		0.10		1.00	1.00		3.50	3.50		1.00	1.00			1.00			1.00			1.00			1.00
Outstanding, beginning period							50,000	50,000	50,000				600,779	600,779	600,779				14,000	14,000	14,000				36,000	36,000	36,000				50,000	50,000	50,000				23,000	23,000	23,000	23,000			1,847,500	1,847,500	1,847,500	1,847,500			72,000	72,000	72,000	72,000			27,000	27,000	27,000				120,000	75,000	120,000	75,000			40,000	40,000		555,596	555,596	555,596	555,596			150,000	150,000	150,000	150,000			150,000	1,025,164	1,025,164	1,025,164				100,000	100,000	100,000	100,000			505,965	505,965	505,965				36,500	36,500		30,000	30,000		10,000	10,000	10,000				130,540	130,540	130,540	130,540			20,000			500,000			5,000		10,000			8,000		5,000		12,000		20,000			2,000		13,000			2,000		10,000			30,000			50,000			6,000			125,000		375,000			45,000			12,000			12,000		12,000		12,000		12,000		12,000		27,150			114,000			35,000			45,000	45,000		40,000	40,000		36,500	36,500		30,000	30,000		5,424,044	4,032,065	5,983,265	5,424,044
Warrants granted	47,500	1,310,000	1,568,129																																																							27,000	27,000																											1,025,164	1,025,164											505,965	505,965											10,000	10,000									20,000	20,000		500,000	500,000		5,000		15,000	10,000		8,000		5,000		12,000		45,000	20,000		2,000		15,000	13,000		2,000		12,000	10,000		30,000	30,000		50,000	50,000		6,000	6,000		125,000		500,000	375,000		45,000	45,000		72,000	12,000		12,000		12,000		12,000		12,000		12,000
Warrants expired/cancelled		(750,779)	(176,150)							(50,000)	(50,000)					(600,779)	(600,779)					(14,000)	(14,000)					(36,000)	(36,000)					(50,000)	(50,000)																																																																																																																																																	(27,150)	(27,150)		(114,000)	(114,000)		(35,000)	(35,000)
Outstanding, ending period							50,000	50,000	50,000				600,779	600,779	600,779				14,000	14,000	14,000				36,000	36,000	36,000				50,000	50,000	50,000				23,000	23,000	23,000	23,000			1,847,500	1,847,500	1,847,500	1,847,500			72,000	72,000	72,000	72,000			27,000	27,000	27,000				120,000	75,000	120,000	75,000			40,000	40,000		555,596	555,596	555,596	555,596			150,000	150,000	150,000	150,000			150,000	1,025,164	1,025,164	1,025,164				100,000	100,000	100,000	100,000			505,965	505,965	505,965				36,500	36,500		30,000	30,000		10,000	10,000	10,000				130,540	130,540	130,540	130,540			20,000			500,000			5,000		10,000			8,000		5,000		12,000		20,000			2,000		13,000			2,000		10,000			30,000			50,000			6,000			125,000		375,000			45,000			12,000			12,000		12,000		12,000		12,000		12,000		27,150			114,000			35,000			45,000	45,000		40,000	40,000		36,500	36,500		30,000	30,000		5,424,044	4,032,065	5,983,265	5,424,044

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Note 6 - Income Taxes (Detail) - Effective income tax rate reconciliation (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Amount of expected tax benefit	$ (1,456,563)	$ (515,000)
Non-deductible expenses	3,560	4,000
State Taxes	9,664	800
Valuation allowance adjustments	1,453,003	511,000
	$ 9,664	$ 800

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Consolidated Statements of Shareholders' Equity (USD $)	Series B Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Total
Balances at Dec. 31, 2010	$ 5,448,602	$ 55,671,371	$ 3,522,167	$ (43,561,858)	$ 21,080,282
Balances (in Shares) at Dec. 31, 2010	7,523,000	39,090,845
Dividends on Series B preferred stock				(434,639)	(434,639)
Issuance of common stock for cash, net		1,479,208			1,479,208
Issuance of common stock for cash, net (in Shares)		3,062,256
Conversion of preferred stock to common stock	(1,575,000)	1,575,000
Conversion of preferred stock to common stock (in Shares)	(2,100,000)	2,100,000
Share-based compensation			407,311		407,311
Fair value of warrants issued in connection with notes payable			13,162		13,162
Net Loss				(1,472,434)	(1,472,434)
Balances at Dec. 31, 2011	3,873,602	58,725,579	3,942,640	(45,468,931)	21,072,890
Balances (in Shares) at Dec. 31, 2011	5,423,000	44,253,101
Dividends on Series B preferred stock				(325,380)	(325,380)
Issuance of common stock for cash, net		360,000			360,000
Issuance of common stock for cash, net (in Shares)		2,100,000
Share-based compensation		31,500	391,499		422,999
Share-based compensation (in Shares)		225,000
Fair value of warrants issued in connection with notes payable			8,095		8,095
Net Loss				(3,935,302)	(3,935,302)
Balances at Dec. 31, 2012	$ 3,873,602	$ 59,117,079	$ 4,342,234	$ (49,729,613)	$ 17,603,302
Balances (in Shares) at Dec. 31, 2012	5,423,000	46,578,101

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Note 4 - Summary of Oil and Gas Operations

12 Months Ended

Dec. 31, 2012

Oil and Gas Properties [Text Block]

4.         SUMMARY OF OIL AND GAS OPERATIONS

Capitalized costs at year end and costs incurred relating to GeoPetro’s oil and gas properties are summarized as follows:

Capitalized costs as of December 31, 2012 are as follows:

	United States			Australia			Indonesia			Canada			Totals
Proved properties	$	46,621,800		$	2,388,051		$	1,361,817		$	2,719,275		$	53,090,943
Unproved properties		4,635,781			1,522,718			—			366,320			6,524,819
Gas processing plant		5,533,910			—			—			—			5,533,910
Less—accumulated depletion and impairment		(35,156,126	)		(2,388,051	)		(1,361,817	)		(2,719,275	)		(41,625,269	)
Net capitalized costs	$	21,635,365		$	1,522,718		$	—		$	366,320		$	23,524,403

Costs incurred for the year ended December 31, 2012 are as follows:

Exploration	$	149,037	$	—	$	—	$	64,939	$	213,976
Development		16,841		—		—		—		16,841
Total costs incurred	$	165,878	$	—	$	—	$	64,939	$	230,817

Capitalized costs as of December 31, 2011 are as follows:

	United States			Australia			Indonesia			Canada			Totals
Proved properties	$	47,128,745		$	2,388,051		$	774,777		$	2,685,659		$	52,977,232
Unproved properties		4,486,744			1,522,718			587,040			334,997			6,931,499
Gas processing plant		5,533,910			—			—			—			5,533,910
Less—accumulated depletion and impairment		(34,974,595	)		(2,388,051	)		(774,777	)		(2,685,659	)		(40,823,082	)
Net capitalized costs	$	22,174,804		$	1,522,718		$	587,040		$	334,997		$	24,619,559

Costs incurred for the year ended December 31, 2011 are as follows:

Gas processing plant upgrade	$	428,698	$	—	$	—	$	—	$	428,698
Exploration		66,277		—		—		2,347		68,624
Development		878,476		—		—		6,355		884,831
Total costs incurred	$	1,373,451	$	—	$	—	$	8,702	$	1,382,153

In April 2012, the Company's wholly-owned subsidiary, Redwood Energy Production, L.P., elected to temporarily shut-in its natural gas production at the Madisonville Field, Madison County, Texas in light of depressed natural gas prices.  The Company will monitor market conditions and bring its natural gas production back on stream as market conditions warrant.

In August 2012, the Company sold certain oil and gas properties for approximately $500,000.

The Company reclassified costs associated with Indonesia projects of $587,040 and $750,133 to the full cost pool for the years ended December 31, 2012 and 2011, respectively.  Considering that we do not have any proved reserves in Indonesia, those costs were immediately charged to impairment.

The Company reclassified costs associated with Canada projects of $33,616 to the full cost pool for the year ended December 31, 2012.  Considering that we do not have any proved reserves in Canada, those costs were immediately charged to impairment.

The Company has proved undeveloped reserves included in the carrying value of its proved properties.  The Company is confident capital will be raised to further develop these reserves. If the capital is not raised the Company may be required to impair the Proved property asset in the future.

Unproved Oil and Gas Properties—United States—As GeoPetro’s properties are evaluated through exploration, they will be included in the amortization base. The prospects and their related costs in unproved properties have been assessed individually and no impairment charges were considered necessary for the United States properties for any of the periods presented. The current status of these prospects is that seismic data is being interpreted on an on-going basis on the subject lands within the prospects.

Unproved properties in the United States as of December 31, 2012 and 2011 consist primarily of exploration costs related to our retained interest in the Alaska prospect following the sale of our working interest to Linc Energy (Alaska) Inc. (“Linc”) on February 26, 2010.

On May 2, 2011 Linc reported that drilling and testing on the LEA #1 well located in the Point MacKenzie Block of the Cook Inlet Basin had been completed. Three sandstone targets were tested separately. Despite the fact that gas shows were encountered while drilling, the sandstone targets were too tight to produce commercial quantities of gas. Although the LEA#1 has not proved to be commercial, the operator intends to use information acquired while drilling the well to continue exploration in the Cook Inlet Basin.  The cost basis of unproved properties in Alaska as of December 31, 2012 is $3,710,658.

Costs incurred in connection with unproved properties in the United States during the year ended December 31, 2012 consisted primarily of exploration costs in connection with GeoPetro’s California prospect.  Drilling on the California prospect is expected to commence in 2013 or 2014, and is expected to continue in future periods.

Unproved Oil and Gas Properties—Australia—Unproved costs incurred in Australia represent costs in connection with the exploration of two exploration permit areas in Australia. The prospects and their related costs in unproved properties have been assessed individually and no impairment charges were considered necessary for the Australian properties for any of the periods presented. On June 20, 2007, the Company entered into a contract to sell its Australian Properties to an unaffiliated third party. These costs remaining in unproved properties represent our retained interest.

Unproved Oil and Gas Properties—Indonesia—Unproved costs incurred in Indonesia related to the Bengara Block represent costs in connection with one production sharing contract area and the exploration efforts in Indonesia.

The Company had retained a carried 12% stake in the Bengara II Block PSC through its investment in Continental-GeoPetro (Bengara-II) Ltd. (“C-G Bengara”), the operator company of the project with offices in Jakarta, Indonesia. GeoPetro’s partner, Continental Energy Corporation likewise retained an 18% interest in C-G Bengara. CNPCHK (Indonesia) Limited owned the remaining 70% interest in C-G Bengara and has paid 100% of the cost of drilling certain exploratory and appraisal wells.

The Company has been notified that the operator of the Bengara II Production Sharing Contract (“PSC”) has terminated negotiations with the Indonesian government for an extension of the PSC’s terms. The PSC shall now be relinquished and allowed to expire in accordance with its terms. As a result, the Company has recorded an impairment charge of $587,040 to its oil and gas properties for the year ended December 31, 2012.

In September 2011, the decision was made to terminate CG Xploration and wind down operations.  The Company has recorded an impairment charge of $750,133 in September 2011 as a result.

Unproved Oil and Gas Properties—Canada—Unproved costs incurred in Canada primarily represent costs in connection with the Swan Hills Project in Alberta, Canada. The prospects and their related costs in unproved properties have been assessed individually and no impairment charges were considered necessary for the Canadian properties except for $33,616 in costs associated with an abandoned prospect. 

In June 2012, the Company’s wholly owned subsidiary, GeoPetro Canada Ltd., acquired the remaining two-thirds (2/3) working interest in the Swan Hills Project, Central Alberta, Canada in exchange for an overriding royalty interest.  Following the acquisition, the Company now owns 100% of the working interest in the Project.

Breakdown of Unproved Oil and Gas Properties—The following table sets forth a summary of oil and gas property costs not being amortized at December 31, 2012, by the period in which the costs were incurred:

			Year Ended		Year Ended		Year Ended
			December 31,		December 31,		December 31,		2009 and Prior
	Totals		2012		2011		2010		Years
Unproved property acquisition	$	2,150,134	$	—	$	—	$	—	$	2,150,134
Exploration		4,374,685		213,976		68,624		201,234		3,890,851
Total	$	6,524,819	$	213,976	$	68,624	$	201,234	$	6,040,985

Management expects that planned activities for the year 2013 will enable the evaluation of approximately 25% of the costs as of December 31, 2012. Evaluation of 30% of the remaining costs is expected to occur in 2014 with the remaining 45% in 2015 and beyond.

Gas Processing Plant

There are asset retirement obligations associated with the Plant. However, components of the Plant can be used for extended and indeterminate periods of time as long as they are properly maintained and/or upgraded. GeoPetro’s intent is to maintain the Plant assets and continue making improvements to those assets based on technological advances. As a result, GeoPetro’s management believes that the Plant has an indeterminate life for purposes of estimating asset retirement obligations because dates or ranges of dates upon which GeoPetro would retire the Plant cannot reasonably be estimated.

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Note 12 - Supplementary Oil and Gas Reserve Information: (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2012

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]

	Year Ended December 31,
	2012			2011
	(in thousands)
Future cash inflows	$	44,045		$	72,305
Future production costs		(10,555	)		(16,512	)
Future development costs		(10,916	)		(10,916	)
Future income taxes		—			—
Future net cash flows		22,574			44,877
10% annual discount		(6,426	)		(12,258	)
Standardized measure of discounted future net cash flows	$	16,148		$	32,619

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]

	Years Ended December 31,
	2012			2011
Balance, beginning of period		32,619			29,102
Sales of oil and gas, net		(877	)		(1,509	)
Net change in prices and production costs		(16,452	)		6,121
Net change in future development costs		—			(2,760	)
Revisions of previous quantity estimates		(1,325	)		1,698
Net change in income taxes		—			—
Accretion of discount		3,674			2,505
Other		(1,491	)		(2,538	)
Balance, end of period	$	16,148		$	32,619

Natural Gas [Member]

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]

	Natural Gas (Mcf)
Proved Developed and Undeveloped Reserves
January 1, 2011		18,308
Revisions of previous estimates		791
Production		(210	)
December 31, 2011		18,889
Revisions of previous estimates		(984	)
Production		(116	)
December 31, 2012		17,789

Proved Developed and Undeveloped Reserves [Member]

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]

	2012		2011
	(MMcf)		(MMcf)
Proved developed		—		2,453
Proved developed non-producing		9,126		7,328
Proved undeveloped		8,663		9,108
Total		17,789		18,889

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Note 5 - Debt (Detail) - Maturities of debt obligations (USD $)	Dec. 31, 2012
2013	$ 1,540,000
2014	1,590,000
2015	75,000
January [Member]
2013	565,000
2014	1,150,000
May [Member]
2014	365,000
August [Member]
2013	180,000
October [Member]
2013	795,000
2014	75,000
2015	$ 75,000

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Note 3 - Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Asset Retirement Obligations [Table Text Block]

	December 31,
	2012		2011
Asset retirement obligations, beginning of period	$	75,000	$	71,510
Liabilities incurred		—		698
Accretion expense		—		2,792
Asset retirement obligations, end of period	$	75,000	$	75,000

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

	Years Ended December 31,
	2012		2011
Stock options (Note 8)		3,445,000		2,770,000
Warrants (Note 9)		5,983,265		5,424,044
Convertible preferred stock, Series B		5,423,000		5,423,000