As filed with the Securities and Exchange Commission on June 30, 2006

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM S-1

REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933

GEOPETRO RESOURCES COMPANY

(Exact Name of Registrant as specified in its Charter)

 

One Maritime Plaza, Suite 700
San Francisco, CA  94111
(415) 398-8186
(415) 398-9227-Fax

(Address Including Zip Code and Telephone Number Including Area Code
of Registrant’s Principal Executive Offices)

Stuart J. Doshi
President
GeoPetro Resources Company
One Maritime Plaza, Suite 700
San Francisco, CA 94111
(415) 398-8186

(Name, Address, Including Zip Code, and Telephone Number, Including Area Code, of Agent for Service)

Copies to:

 

Approximate date of proposed sale to the public:  As soon as practicable after this Registration Statement is declared effective.

If any of the securities being registered on this form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, check the following box. x

If this form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, check the following box and list the Securities Act registration number of the earlier effective registration statement for the same offering. o

If this form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If this form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

CALCULATION OF REGISTRATION FEE

 

(1)             Includes (i) 1,890,710 shares of common stock issuable upon conversion of Series AA Preferred Stock, (ii) 2,119,522 shares of common stock issuable upon exercise of warrants, (iii) 4,025,250 shares of common stock issuable upon exercise of options and (iv) 27,348,758 outstanding shares of common stock.

(2)             Estimated solely for the purpose of calculating the registration fee pursuant to Rule 457(c) under the Securities Act of 1933 based on the average of the high and low prices of the Registrant’s common stock, as reported on The Toronto Stock Exchange on June 28, 2006, in U.S. dollars.

The Registrant hereby amends this Registrant Statement on such date or dates as may be necessary to delay its effective date until the Registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in  accordance with Section 8(a) of the Securities Act of 1933 or until the Registration Statement shall become effective on such date as the Commission, acting pursuant to said Section 8(a), may determine.

Information contained in this prospectus is subject to completion or amendment. A registration statement relating to these securities has been filed with the Securities and Exchange Commission. These securities may not be sold nor may offers to buy be accepted prior to the time the registration statement becomes effective. This prospectus shall not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of these securities in any state in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such state.

Subject to completion, dated June 30, 2006.

PROSPECTUS

GEOPETRO RESOURCES COMPANY

35,384,240 shares of Common Stock

(No Par Value)

 

Investing in our common stock involves a high degree of risk. See “Risk Factors” Beginning on Page 5.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities, or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.

GeoPetro is bearing all the expenses of registering these shares. The expenses are estimated at $             .

The date of this prospectus is           , 2006

TABLE OF CONTENTS

 

You should rely only on the information contained in this prospectus. We have not authorized any other person to provide you with different information. If anyone provides you with different or inconsistent information, you should not rely on it. The selling shareholders are not making an offer to sell these securities in any jurisdiction where an offer or sale is not permitted. You should assume that the information appearing in this prospectus is accurate as of the date on the front cover of this prospectus only. Our business, financial condition, results of operations and prospects may have changed since that date.

Unless otherwise specified or the context otherwise requires, all dollar amounts in this prospectus are expressed in U.S. dollars. Canadian dollars, when used, are expressed with the symbol “CDN$”. Unless otherwise specified, where dollars are shown on a converted basis, the conversion is based upon an exchange ratio of CDN$1.00=$0.8897, the exchange rate in effect on June 28, 2006, except for dollars set forth in or derived from the financial statements, where the exchange rate is derived as of the date of the financial statements.

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PROSPECTUS SUMMARY

This summary highlights selected information contained in greater detail elsewhere in this prospectus and does not contain all of the information that you should consider before investing in our common stock. You should read the entire prospectus carefully, especially the risks of investing in our common stock, which we discuss under “Risk Factors” and our consolidated financial statements and related notes. Unless otherwise indicated or required by the context, “we,” “us,” and “our” refer to GeoPetro Resources Company and its subsidiaries and predecessors. All financial data included in this prospectus has been prepared in accordance with generally accepted accounting principles in the United States. We have provided definitions for some of the natural gas and oil industry terms used in this prospectus in the “Glossary of Natural Gas and Oil Terms” on page A-1 of this prospectus. All dollar amounts appearing in this prospectus are stated in U.S. dollars unless specifically noted in Canadian dollars (“CDN$”).

GEOPETRO RESOURCES COMPANY

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THE OFFERING

 

Proposed NASDAQ National Market or American Stock Exchange Symbol:(3)    “            ”

(1)          Includes 27,348,758 shares of common stock, 1,890,710 shares of common stock issuable upon conversion of Series AA Preferred Stock, 2,119,522 shares of common stock issuable upon exercise of warrants and 4,025,250 shares of common stock issuable upon exercise of options.

(2)          Assumes the sale by the selling stockholders of all the shares of common stock available for resale under this prospectus, except for 840,000 shares of common stock which are issuable upon exercise of unvested options.

(3)          There is no assurance that the common stock will be approved for quotation on the NASDAQ National Market or the American Stock Exchange, or that a trading public market on a U.S. exchange or NASDAQ will develop, or, if developed, will be sustained. See “Risk Factors”

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SUMMARY CONSOLIDATED FINANCIAL DATA

The following table sets forth certain of our summary consolidated financial data for the periods indicated. The data presented below has been derived from our financial statements included elsewhere in this prospectus. You should read this information together with the consolidated financial statements and the notes to those statements appearing elsewhere in this prospectus and the information under “Selected Consolidated Financial Data” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

 

 

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RISK FACTORS

An investment in our common stock involves a high degree of risk. You should carefully consider the risks described below together with all of the other information included in this prospectus before making an investment decision. If any of the possible adverse events described below actually occurs, our business, results of operations and financial condition could suffer. Under these circumstances, the market price of our common stock could decline and you could lose all or part of your investment.

Risks Related to Our Business

Since our inception, we have incurred substantial costs and generated only nominal revenues.

Since inception, our activities have been primarily related to acquiring and exploring leasehold interests in oil and natural gas properties in Texas, California, Alaska, Alberta, Indonesia and Australia. We incur 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 March 31, 2006 of $9,455,256. Our significant production activities commenced in May 2003. Since May 2003, substantially all of our revenue has been generated from natural gas sales derived from the Magness #1 well in the Madisonville Field in Texas. There is no guarantee that we will continue to generate revenues from our sales of natural gas from the Magness #1 well, nor is there any guarantee that we will be able to generate revenues from sales of natural gas from any of our other properties. Our proved reserves will decline as reserves are produced from our properties unless we are able to acquire or produce new reserves. 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.

Substantially 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 have a material adverse effect on our operating results.

We derive substantially all of our oil and natural gas revenues from the Madisonville Project. In connection with that project, we have contracted with third parties to provide key services, including:

(a)          Madisonville Gas Processing, LP (“MGP”), which owns and operates gathering pipelines and a dedicated natural gas treatment plant which we utilize to treat impurities in the Madisonville Project natural gas; and

(b)         Gateway Processing Company (“Gateway”), which operates a sales pipeline for such natural gas.

The failure of MGP or Gateway to perform their 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 or MGP, 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 MGP, Gateway or our company.

·       subsurface conditions or formations encountered during the drilling of wells, whether natural or mechanical, including but not limited to blowout, heaving shale, igneous rock, salt, saltwater flow,

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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.

·       the inability to secure raw materials or equipment,

·       transportation accidents, and

·       labor disputes and equipment failures.

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. 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 exploitation and development activities will result in the discovery of any reserves.

Our exploration and development 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;

·       equipment failures or accidents, adverse weather conditions;

·       compliance with governmental requirements; and

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

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.

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 drilling, exploration and development 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 sum, our participation in future drilling activities may not be successful and, if unsuccessful,

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such failure will negatively impact our revenues and have a material adverse effect on our results of operations and financial condition.

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 of our exploration and operations in Alberta, Canada, Indonesia and Australia is limited since we rely on third parties to operate our projects. We are a non-operating interest owner in our Canadian, Indonesian and Australian properties. With respect to our interests outside of the United States, we have entered into joint operating 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.

Drilling and completion equipment, services, supplies and personnel are scarce and may not be available when needed, which could significantly disrupt or delay our operations.

From time to time, there has been a general shortage of drilling rigs, equipment, supplies and oilfield services in North America, Australia and Indonesia, which may intensify with current increased industry activity. In addition, the costs and delivery times of rigs, equipment and supplies have risen. There can be no assurance that sufficient drilling and completion equipment, services and supplies will be available when needed. Shortages could delay our proposed exploration, development, and sales activities, which could have a material adverse effect on our results of operations. The demand for, and wage rates of, qualified rig crews have risen in the drilling industry due to the increasing number of active rigs in service. If the demand for qualified rig crews continues to rise in the drilling industry, then the oil and gas industry may experience shortages of qualified personnel to operate drilling rigs. This could delay our drilling operations and adversely affect our financial condition and results of operations.

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 farmout arrangements with unaffiliated third parties.

We have previously entered into, and may in the future enter into, farmout arrangements with third parties willing to drill natural gas and oil 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 farmout arrangements have been or may be diminished. Our opportunity to realize revenues and profits from properties which are successfully developed under farmout arrangements will be diminished to the extent of our reduced interests.

Competition with other oil and natural gas exploration and development 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:

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

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

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(c)          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.

We cannot assure you that our estimates of oil and natural gas reserves are accurate. 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 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 and exploration activities and prices of oil and natural gas. Actual future production, revenue, taxes, development 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 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

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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 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, transportation costs, the price and availability of alternative fuels and overall economic conditions.

Our current operations are particularly exposed to volatility in natural gas prices because a portion of the fees we pay to process natural gas at the Madisonville gas treatment plant is fixed. The sale price of natural gas must be above a minimum price before we earn any net revenues from the sale of natural gas.

We are subject to a number of operational risks beyond our control against which we may not have, or be able to obtain, insurance. A loss not covered by insurance could result in substantial expenses to us.

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, producing formations, production facilities and equipment;

·       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 invested significant sums.

We do not insure fully against all business risks either because such insurance is not available or because premium costs are prohibitive. This is a common practice in the oil and gas industry. However, a loss not fully covered by insurance could result in a substantial expense to us and could have a material adverse effect on our financial position and results of operations.

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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. 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, 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. These laws and regulations set various standards regulating certain aspects of health and environmental quality, provide for penalties and other liabilities for the violation of such standards and establish in certain circumstances obligations to remediate current and former facilities and locations where operations are or were conducted. In addition, special provisions may be appropriate or required in environmentally sensitive areas of operation. We may incur substantial financial obligations in connection with environmental compliance.

Environmental legislation may require that we, among other things:

·       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 remediating contaminated soil and groundwater;

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

Compliance with such legislation can require significant expenditures and a breach may result in the imposition of fines and penalties. The discharge of oil, natural gas or other pollutants into the air, soil or water may give rise to liabilities to governments and third parties and may require us to incur substantial costs to remedy such discharge. Under these laws and regulations, we could be liable for personal injury, clean-up costs and other environmental and property damages, as well as administrative, civil and criminal penalties. We could be required to cease production on properties if environmental damage occurs. 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 or exploration, any of which could have a material adverse effect on our financial condition and results of operations or prospects.

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Our Australian operations are subject to unique risks relating to Aboriginal land claims and government licenses.

Our Australian operations could be affected by native title claims by Aboriginal groups. Australian law recognizes that in some instances native title, that is the laws and customs of the Aboriginal inhabitants, has survived European settlement. Native title will only survive if it has not been extinguished. Native title may be extinguished by an Act of Government, such as the creation of a title that is inconsistent with native title. This may include a grant of the right to exclusive possession through freehold title or lease. Native title may also be extinguished if the connection between the land and the group of Aboriginal people claiming native title has been lost. Each authority to prospect, and license in areas in which we desire to engage in exploration or production activities must be examined individually in order to determine the validity of any native title claim. We may be required to negotiate with any Aborigines who can make a valid claim to having ancestral ties to the areas in which we desire to engage in exploration or production activities. These negotiations could both delay the timing of our exploration or production activities, as well as add an additional layer of cost or a requirement to share revenues if any Aboriginal claimants are proved to have native title rights in our exploration areas.

Our agreement with MGP on gas deliveries to the Madisonville gas treatment plant may be contested by third parties, and as a result, our access to the plant could be restricted.

We are dependent upon the Madisonville gas treatment plant to treat our natural gas. We have committed all natural gas production from our interest in the Madisonville Project to MGP, which as in turn committed to provide treatment capacity of up to 68 MMcf/d for our natural gas. Third parties may seek access to the 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 filed by Crimson Exploration Inc. with the Texas Railroad Commission described under “Properties—Description of the Properties—Texas—The Madisonville Gas Treatment Plant and Gathering Facilities”. There is no guarantee that we will be able to maintain full access to treatment capacity of up to 68 MMcf/d at the Madisonville Plant at all times against all possible challenges.

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

Our business activities in Indonesia, Australia, 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.

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 Indonesian, Australian, Canadian or American government 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 have increased 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, especially in Indonesia.

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If we do not satisfy the work requirements of our PSCs and exploration permits, the Indonesian and/or the Australian government may terminate all or part of our contracts.

Our Indonesian PSCs and Australian exploration permits require us and our partners to undertake work by specified dates in order to maintain our oil and natural gas rights. See “Properties—Description of the Properties—Indonesia and Australia.”  We may not be able to satisfy our contractual obligations. If we do not otherwise comply with the work requirements of the PSCs and exploration permits, or successfully renegotiate the terms, all or part of one or more of our contracts may be terminated. If these contracts are terminated, we would also lose all of our investment in that overseas prospect. If we forfeit our interest in the contract or permit areas, it will be necessary to record an impairment write-down equal to the net capitalized costs recorded for the area forfeited. This could have a material adverse impact on our financial condition and results of future operations in future periods.

We may not be able to sell our natural gas production in Indonesia, limiting our ability to obtain a return on our investment there.

Our Indonesian operations lack a local market for natural gas, and if we produce natural gas in Indonesia, it will most likely have to be transported to an area where there is a demand. If no market for natural gas develops in Indonesia, we may incur costs for transportation. If we are not able to sell our natural gas production at a commercially acceptable price or at all, we may not be able to obtain a return on our investment in our Indonesian property.

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, may not be successful and 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

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negatively impact our operations and delay or preclude us from achieving our business objectives. Stuart Doshi, David Creel and Chris Steinhauser, the three members of our senior management team, have a combined experience of approximately 100 years in the oil and gas industry. Although we have entered into employment agreements with Messrs. Doshi, Creel and Steinhauser, we could suffer the loss of key individuals for one reason or another at any time in the future. 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.

Nick DeMare, one of our directors, is a director, officer and/or significant shareholder of other natural resource companies and David Anderson, another one of our directors, is a director and officer of Dundee Securities Corporation, 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. Their association with these 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 June 28, 2006, our directors and officers beneficially own 25.7% of our outstanding common stock. See “Security Ownership of Certain Beneficial Owners and Management”. 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.

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 and 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 will be materially adversely affected.

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Risks Related to this Offering and Our Common Stock

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

If any of our outstanding preferred stock, or other instruments convertible into or exercisable for common shares, are converted into or exercised for common shares, purchasers of our common stock will experience immediate and substantial dilution. Investors may be subject to further dilution if we sell additional common shares or issue additional common shares in connection with future acquisitions. In addition, common shares issued upon the exercise of outstanding stock warrants and options will lead to further dilution for purchasers of our common stock.

The selling shareholders will have the opportunity to sell their common shares in the market. As a result, if a significant number of common shares are sold in the public market, the market price of our common shares could be depressed. This could also hamper our ability to raise capital by issuing additional equity securities.

The terms of our preferred stock give holders of preferred stock priorities over holders of our common shares.

Our Series AA preferred shares are, among other things, entitled to receive, prior to, and in preference to our common shares, including the common shares offered hereby, (a) certain dividends and (b) certain assets of our company upon any liquidation, dissolution, or winding up. The ability of the holders of our common shares to obtain a return on their investment will be subject to the preferences afforded to the holders of our preferred stock.

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 plan to expend money in Indonesia, Canada and Australia, where our operating costs will be denominated in local currencies. Fluctuations in exchange rates may increase our relative cost of operating in these countries, and may therefore have a negative effect on our financial results.

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

Unless certain requirements are met, 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 will be required to withhold for the benefit of the IRS 10% of the purchase price since we are a United States real property holding corporation. There is an exemption from U.S. federal income tax for non-U.S. holders of 5% or less of our common shares (and to withholding for all non-U.S. holders) if our common shares are “regularly traded on an established securities market” under the Treasury Regulations of the IRS. Under temporary Treasury Regulations, for so long as 100 or fewer persons own 50% or more of our common shares (which is the case now and which we anticipate will continue to be the case for some time), our common shares will be “regularly traded on an established securities market” for a calendar quarter only if the established securities market is located in the United States and our common shares are regularly quoted by more than one broker or dealer making a market in our common shares; quotes have in fact been published for our common shares on the Pink Sheets market (which constitutes an established securities market for this purpose) by at least two broker-dealers. There can be no assurance, however, that there will be at least two broker-dealers regularly quoting our common shares on the Pink Sheets and making a market in them in any particular calendar quarter so as to avoid U.S. federal income tax on the sale of our common shares by non-U.S. holders of 5% or less of our common shares and the withholding requirement on the purchaser. See “United States Federal Income Tax Considerations.”

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

Although our common shares have been listed on The Toronto Stock Exchange since March 2006, and are traded in the United States over-the-counter market, they are thinly traded. As a result, 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. We intend to apply to list our common shares on the NASDAQ National Market or the American Stock Exchange; however, there is no assurance that the listing will be effected.

Our stock price may fluctuate significantly.

The stock market in general and the market for natural gas and oil 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.

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

Most of the matters discussed within this prospectus include forward-looking statements on our current expectations and projections about future events. Words such as “may,” “should,” “potential,” “continue,” “expect,” “anticipate,” “intend,” “plan,” “believe,” “seek,” “estimate,” and similar expressions are intended to identify such forward looking statements. These statements are based on our current beliefs, expectations, and assumptions and are subject to a number of risks and uncertainties and, therefore, actual results and events may vary significantly from those discussed in the forward-looking statements. These risks and uncertainties include those noted in “Risk Factors” above. Other factors besides those listed here could adversely affect us.

These forward-looking statements may include, among other things, statements relating to the following matters:

·       the level of oil and gas reserves that can be extracted at any of our projects;

·       our ability to extract reserves at commercially attractive prices;

·       our ability to compete against companies with much greater resources than us:

·       identified drilling locations;

·       exploration and development drilling prospects, inventories, projects and programs;

·       financial strategy;

·       production;

·       lease operating expenses, general and administrative costs and finding and development costs;

·       future operating results; and

·       plans, objectives, expectations and intentions.

We undertake no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent we are required to do so by law.

You should not unduly rely on these forward-looking statements in this prospectus as they speak only as of the date of this prospectus. Except as required by law, we undertake no obligation to publicly release any revisions to these forward-looking statements to reflect events or circumstances occurring after the date of this prospectus or to reflect the occurrence of unanticipated events. See the information under the heading “Risk Factors” in this prospectus for some of the important factors that could affect our financial performance or could cause actual results to differ materially from estimates contained in forward-looking statements.

USE OF PROCEEDS

We will not receive any proceeds from the sale of securities by the selling shareholders.

DILUTION

The net tangible book value of our common stock on March 31, 2006 was approximately $29,245,283, or $1.07 per share. Net tangible book value per share represents the amount of our total tangible assets, less our total liabilities and the aggregate liquidation preference of our preferred stock outstanding, divided by the total number of shares of our common stock outstanding. The number of shares of our common stock outstanding may be increased by shares issued upon conversion of our Series AA Preferred Stock, payment of dividends, or exercise of options and warrants, and, to the extent options and warrants are exercised for cash, the net tangible book value of our common stock may increase. If all the options and warrants for which the shares of our common stock that are issuable upon exercise of the options and

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warrants being offered pursuant to this prospectus were exercised for cash, the net tangible book value of our common stock would be $43,891,632, or approximately $1.73 per share, excluding the effect of any other transactions occurring after March 31, 2006. Since we will not receive any of the proceeds from the sale of common stock sold under this prospectus, the net tangible book value of our common stock will not be increased as a result of such sales, nor will the number of shares outstanding be affected by such sales. Consequently, there will be no change in the net tangible book value per share of our common stock as a result of any sales under this prospectus. However, any dilution to new investors will represent the difference between the amount per share paid by purchasers of shares of our common stock from the selling stockholders in this offering and the net tangible book value per share of our common stock at the time of purchase.

MARKET PRICE OF COMMON STOCK

Our common stock is listed on the Toronto Stock Exchange under the symbol “GEP.s”. Our common stock has not been previously registered with the SEC and those shares of our common stock which trade on the Toronto Stock Exchange may not presently be purchased by United States persons or persons in the United States pursuant to SEC Regulation S. Our common stock may also trade in the United States over-the-counter market in the Pink Sheets under the symbol “GPRC”. On June 28, 2006, the last reported sale prices for our common stock on the Toronto Stock Exchange and in the U.S. on the Pink Sheets were $3.50 and $3.65, respectively. The following table sets forth the high and low sale prices of our common shares as reported on The Toronto Stock Exchange and bid prices as quoted in the United States in the “pink sheets” over-the-counter market for the periods presented. Prior to the first quarter of 2006, there was no trading market for our common shares.

(1)          Our common stock is quoted in U.S. dollars on the Toronto Stock Exchange.

As of June 28, 2006, there were 498 holders of record of our common shares.

Over-the-counter market quotations reflect inter-dealer prices and may not necessarily represent actual transactions.

DIVIDENDS

The holders of Series AA preferred stock are entitled to receive ratably such cash dividends, if any, as may be declared from time to time by the board of directors out of funds legally available therefor and, when declared, dividends shall be paid at the rate of $0.28 per share per annum, paid on a calendar quarter basis. Any quarterly dividends not paid when due shall be accrued and shall accumulate until paid. We have declared and paid dividends on a quarterly basis with respect to all outstanding shares of Series AA preferred stock at the rate of $0.28 per share per year since the Series AA stock was issued.

We have never paid any dividends, whether cash or property, on our common stock. No dividend on our common stock may be paid unless, at the time of such payment, all accrued dividends on our Series AA Preferred Stock have been paid. Subject to this preference, and the preferences that may be applicable to the holders of any other class of our preferred stock, if any, the holders of our common stock shall be entitled to receive ratably such lawful dividends as may be declared by the Board of Directors. For the foreseeable future it is anticipated that any earnings which may be generated from our operations will be used to finance our growth and that dividends will not be paid to shareholders.

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SELECTED CONSOLIDATED FINANCIAL DATA

The following selected consolidated financial data should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and the related notes to those statements included elsewhere in this prospectus. The consolidated statements of operations data for the years ended December 31, 2003, 2004 and 2005 and the balance sheet data as of December 31, 2004 and 2005 are derived from our audited consolidated financial statements included elsewhere in this prospectus. The consolidated statements of operations data for the years ended December 31, 2001 and 2002 and the balance sheet data as of December 31, 2001, 2002 and 2003 are derived from our audited consolidated financial statements not included in this prospectus. The selected consolidated statements of operations data for the three months ended March 31, 2005 and 2006 and the selected consolidated balance sheet data as of March 31, 2006 have been derived from our unaudited consolidated financial statements included elsewhere in this prospectus. The unaudited consolidated financial statements include, in the opinion of management, all adjustments that management considers necessary for the fair presentation of the financial information set forth in those statements. Historical results are not necessarily indicative of the results to be expected in the future, and the results for the three months ended March 31, 2006 should not be considered indicative of results expected for the full year.

 

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with accompanying financial statements and related notes included elsewhere in this prospectus. It 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. Our actual results could differ materially from those discussed in these forward looking statements. Factors that could cause or contribute to such differences include, but are not limited to, market prices for natural gas and oil, economic and competitive conditions, regulatory changes, estimates of proved reserves, potential failure to achieve production from development projects, capital expenditures and other uncertainties, as well as those factors discussed below and elsewhere in this prospectus, particularly in “Risk Factors” and “Cautionary Notes Regarding Forward Looking Statements”, all of which are difficult to predict and which expressly qualify all subsequent oral and written forward-looking statements attributable to us or persons acting on our behalf. In light of these risks, uncertainties and assumptions, the forward looking events discussed may not occur. We do not have any intention or obligation to update forward-looking statements included in this prospectus after the date of this prospectus, except as required by law.

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 1.56 million gross (645,115 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 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.

Since 2003, substantially all of our revenue has been generated from natural gas sales derived from the Magness #1 well in 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 the remainder of 2006 and for the year 2007. We expect the majority of our capital expenditures in 2006 and 2007 to be the costs of drilling and completing wells in the Madisonville Field.

 

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Comparison of Results of Operations for the three months ended March 31, 2006 and 2005

During the three months ended March 31, 2006, the Company had oil and natural gas revenues of $1,498,453. The Company’s net production was 468,578 thousand cubic feet (Mcf) of natural gas at an average price of $3.19 per Mcf. During the three months ended March 31, 2005, the Company had oil and natural gas revenues of $1,588,204. The Company’s net production for the three months ended March 31, 2005 was 566,686 Mcf at an average price of $2.80 per Mcf. Revenues decreased in the three months ended March 31, 2006 as compared to the prior period due to lower production volume. Production was approximately 17% lower for the three months ended March 31, 2006 versus the same period in 2005. Production volumes were lower in the first quarter 2006 due to production downtime associated with: (i) a significant workover on the Magness #1 well in January, (ii) hook-up and production start-up of the Fannin #1 well and (iii) maintenance work on the Madisonville gas treatment plant.

During the three months ended March 31, 2006, the Company incurred lease operating expenses of $266,223. The Company’s average lifting cost for this period was $0.57 per Mcf. During the three months ended March 31, 2005, the Company incurred lease operating expenses of $210,171. The Company’s average lifting cost for this period was $0.37 per Mcf. The primary reasons for the increase in average lifting cost per Mcf were increases in production costs and lower net production. The increase in production costs was due primarily to the addition of a producing well, the Fannin #1 well, which commenced production in March 2006.

During the three months ended March 31, 2006, the Company incurred net profits interest expense of $158,603 associated with the Magness and Fannin Wells compared to $177,288 during the three months ended March 31, 2005. The decrease resulted from lower net revenues associated with the Magness Well due to its workover in January of 2006.

General and administrative expenses for the three months ended March 31, 2006 were $548,864 compared to $442,968 for the three months ended March 31, 2005. This represents a $105,896 increase over the prior year period due to approximately:

1.                $16,000 of stock based compensation,

2.                $80,000 increase in salary expense; and

3.                $14,000 in filing fees related to our public listing.

Depreciation, depletion and amortization expense for the three months ended March 31, 2006 was $405,197 compared to $517,754 in the same periods of 2005, which amounts represent amortization of the U.S. full cost pool for the three months ended March 31, 2006 and 2005, respectively. The decrease was due to lower net production in the three months period of 2006 as well as an upward revision in net proved reserve estimates at year-end 2005.

Earnings from operations totaled $119,566 for the three months ended March 31, 2006 compared to $240,023 for the three months ended March 31, 2005. The decrease in the earnings from operations was due primarily to lower revenues associated with the Magness Well.

Other income for the three months ended March 31, 2006 and 2005 consisted of interest income in the amount of $434 and $208, respectively. The reason for the increase was higher average cash and cash equivalents balances for the 2006 period as compared to 2005.

During the three months ended March 31, 2006 and 2005, the Company incurred interest expense of $48,549 and $97,155, respectively. The lower interest expense in the current year period was due to lower average debt levels in the first quarter of 2006 compared to first quarter 2005.

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Net income before taxes for the three months ended March 31, 2006 was $71,451 compared to $143,076 for the three months ended March 31, 2005. The decrease in net income was primarily due to lower revenues associated with the Magness Well.

Revenue and Production for 2006

As noted above, we experienced production downtime in the first quarter of 2006 due to a workover of the Magness #1 well, plant maintenance and the hook-up of a second producing well in the Madisonville Field. However, those activities have contributed to an increase in gas sales volumes in the second quarter as the following table illustrates:

 

Industry Overview for the Year Ended December 31, 2005

The year 2005 saw continued strong natural gas prices as a result of hurricane related supply disruptions and generally tight supplies of natural gas in the United States. 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, 2005, was $7.80 versus $5.82 as of December 31, 2004. Availability of capital, particularly equity capital for junior oil and natural gas companies, continued to show improvement in 2005, and in 2005, we raised $4,727,824 net of issuance costs through equity financing transactions. As a result, and through the sale of one of our Indonesian property interests, we were able to repay our indebtedness of $1.7 million to various creditors and improve our capital position during 2005.

Company Overview in 2005

Our net income for the year ended December 31, 2005 was $2,640,471. From our inception to 2003, we only received nominal revenues from our oil and natural gas activities, while incurring substantial acquisition and exploration costs and overhead expenses which resulted in our sustaining an accumulated deficit through December 31, 2005 of $9,382,179. We placed our Madisonville Project into production in May 2003. Substantially all of our oil and natural gas sales for the year ended December 31, 2005 were derived from our Madisonville Project, from one producing well, the Magness #1 well.

Comparison of Results of Operations for the twelve months ended December 31, 2005 and 2004

During the year ended December 31, 2005, we had oil and natural gas revenues of $7,975,990. Our net production was 1,991,105 thousand cubic feet (Mcf) of natural gas at an average price of $4.01 per Mcf. During the year ended December 31, 2004, we had oil and natural gas revenues of $5,825,072. Our net production for the year ended December 31, 2004 was 2,316,895 Mcf at an average price of $2.51 per Mcf. Revenues increased in the year ended December 31, 2005 as compared to the prior period due to higher gas prices. Average prices in 2005 were 60% higher than 2004, more than offsetting the 14% drop in production from 2004 to 2005. Production was lower due to normal declines associated with the production of reserves from the Magness #1 well.

During the year ended December 31, 2005, we incurred lease operating expenses of $878,176. Our average lifting cost for this period was $0.44 per Mcf. During the year ended December 31, 2004, we incurred lease operating expenses of $780,237. Our average lifting cost for this period was $0.34 per Mcf. The primary reasons for the increase in average lifting cost per Mcf were increases in costs and lower net production. The increase in lease operating costs was due primarily to higher insurance premiums,

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approximately $40,000, and higher costs of chemical treatments, approximately $60,000 associated with the Magness #1 well.

During the year ended December 31, 2005, we incurred net profits interest expense of $856,837 associated with the Magness Well compared to $579,590 during the year ended December 31, 2004. The increase resulted from higher revenues associated with the Magness Well in 2005 versus 2004.

General and administrative expenses for the year ended December 31, 2005 were $1,551,747 compared to $1,963,649 for the year ended December 31, 2004. This represents a $411,902 decrease over the prior year period due to stock based compensation incurred in 2004. During 2004 we issued 500,000 shares of our common stock for cash proceeds of $500,000 in connection with the exercise of stock options by an officer and director. Concurrent with the exercise of stock options, the officer sold 117,647 shares of common stock to us at the estimated fair market value price prevailing at that time of $4.25 per share. We recorded compensation expense of $500,000 in connection with the purchase of stock.

Depreciation, depletion and amortization expense for the year ended December 31, 2005 was $1,832,693 compared to $2,077,004 in the year ended December 31, 2004, which amounts represent amortization of the U.S. full cost pool for the year ended December 31, 2005 and 2004, respectively. The decrease was due to lower net production in 2005 as well as an upward revision in net proved reserve estimates during the year.

For the year ended December 31, 2005, no impairment expense was incurred as compared to $2,038,422 for the year ended December 31, 2004. The 2004 impairment write-downs were associated with the Canadian and Australian cost pools. We expensed the costs of drilling dry holes in those areas during 2004 while no such costs associated with unsuccessful wells were incurred in 2005.

Earnings from operations totaled $2,856,537 for the year ended December 31, 2005 compared to a loss of $1,613,830 for the year ended December 31, 2004. The increase in the earnings from operations was due primarily to higher revenues associated with the Magness Well.

Other income for the year ended December 31, 2005 and 2004 consisted of interest income in the amount of $18,969 and $6,548, respectively. The reason for the increase was higher average cash and cash equivalents balances for the 2005 period as compared to 2004.

During the year ended December 31, 2005 and 2004, we incurred interest expense of $217,768 and $402,958, respectively. The lower interest expense in the current year period was due to lower average debt levels. In March 2004, we incurred a cash finders fee of $67,375 to a director associated with the negotiation of a reduction in debt through the conversion of $1,347,500 of long-term debt to equity.

Net income after taxes for the year ended December 31, 2005 was $2,640,471 compared to net loss of $2,077,615 for the year ended December 31, 2004. The increase in net income was primarily due to higher revenues associated with the Magness Well and the impairments expense recorded in the previous period.

Industry Overview for the Year Ended December 31, 2004

The year 2004 saw continued strong natural gas prices as a result of tight supplies of natural gas in the United States. The Houston Ship Channel price, the index price prevailing in the locale of the Madisonville Project, as quoted in Gas Daily as of December 30, 2004, was $5.82 versus $5.76 as of December 31, 2003. Availability of capital, particularly equity capital for junior oil and natural gas companies, continued to show improvement in 2004 and in 2004, we raised $3,479,899 net of issuance costs through equity financing transactions.

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Revenue Trend in 2004

The results of operations for the year ended 2004 reflected a full year of production revenues from the Madisonville Project where we had one well on production. Substantially all of our oil and natural gas sales for the year ended December 31, 2004 were derived from our Madisonville Project in Madison County, Texas.

Comparison of Results of Operations for the Years ended December 31, 2004 and 2003

During the year ended December 31, 2004, we had oil and natural gas revenues of $5,825,072. Our net production was 2,316,895 Mcf at an average price of $2.51 per Mcf. During the year ended December 31, 2003, we had oil and natural gas revenues of $2,452,648. Our net production was 1,217,327 Mcf at an average price of $2.01 per Mcf for 2003.

During the year ended December 31, 2004, we incurred lease operating expenses of $780,237. Our average lifting cost for this period was $0.34 per Mcf. During the year ended December 31, 2003, we incurred lease operating expenses of $582,889. Our average lifting cost for this period was $0.48 per Mcf. The reason for the significant decrease in average lifting cost per Mcf was that the Magness Well experienced significantly higher production volumes in 2004 versus 2003.

During the year ended December 31, 2004, we incurred net profits interest expense of $579,590 associated with the Magness Well compared to $225,869 in 2003. This was due to higher revenues associated with the Magness Well in 2004 versus 2003.

General and administrative expenses for the year ended December 31, 2004 were $1,963,649 compared to $1,259,269 for 2003. This represents a $704,380 or a 56% increase over the prior year period. The primary reason for the increase was a $500,000 non-cash charge associated with stock-based compensation. During 2004 we issued 500,000 shares of our common stock for cash proceeds of $500,000 in connection with the exercise of stock options by an officer and director. Concurrent with the exercise of stock options, the officer sold 117,647 shares of common stock to us at the estimated fair market value price at that time of $4.25 per share. We recorded compensation expense of $500,000 in connection with the purchase of stock. The balance of the increase was due to additional employees and salary increases.

Depreciation, depletion and amortization expense for the year ended December 31, 2004 was $2,077,004 compared to $798,555 for 2003, substantially all of which represents amortization of the U.S. full cost pool for the respective periods. The increase was due to higher depletion expense associated with the Magness Well due to higher production in 2004 versus 2003.

For the years ended December 31, 2004 and 2003, we incurred impairment expense of $2,038,422 and $473,496, respectively. The 2004 impairment write-downs were associated with the Canadian and Australian cost pools while the 2003 impairment write-down was due to the expiration of Permit #386 in Australia. We expensed the costs of drilling dry holes in Canada and Australia during 2004. The impairment charge in 2003 relates to the costs capitalized in connection with an exploration permit which expired during 2003.

Loss from operations totaled $1,613,830 for the year ended December 31, 2004 compared to a loss of $887,430 for 2003. The increase in the loss from operations was due to higher impairments and depletion expenses.

Other income for the year ended December 31, 2004 and 2003 consisted of interest income in the amount of $6,548 and $4,769, respectively. The reason for the increase was higher average cash and cash equivalents balances for the 2004 period as compared to 2003.

During the years ended December 31, 2004 and 2003, we incurred interest expense of $402,958 and $802,031, respectively. The higher interest expense in the prior year period was due to short-term

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borrowings which were incurred to drill and complete the injection well and equipment for production of the Magness Well. In 2004, we incurred debt conversion expense of $67,375 associated with the conversion of $1,347,500 of long-term debt to equity.

Net loss for the year ended December 31, 2004 was $2,077,615 compared to a loss of $1,684,692  for the year ended December 31, 2003. The increase in net loss was primarily due to higher impairments and depletion.

Industry Overview for the Year Ended December 31, 2003

The year 2003 saw a continued recovery in natural gas prices as a result of a general economic recovery and increasingly tight supplies of natural gas in the United States. The Houston Ship Channel price, the index price prevailing in the locale of the Madisonville Project, as quoted in Gas Daily as of December 31, 2003 was $5.76 versus $4.76 as of December 31, 2002, a 21% increase. Availability of capital, particularly equity capital for junior oil and natural gas companies, continued to show improvement in 2003. As a result, in 2003, we raised $7,573,691 through equity financing transactions, which we used to significantly reduce our short-term debt and improve our cash and net working capital position.

Revenue Trend in 2003

Commencing in May 2003, we placed our Madisonville Project into production. Substantially all of our oil and natural gas sales for the year ended December 31, 2003 were derived from our Madisonville Project in Madison County, Texas.

Comparison of Results of Operations for the Years Ended December 31, 2003 and 2002

During the years ended December 31, 2003 and 2002, we had natural gas revenues of $2,452,648 and $21,659, respectively. Our net production was 1,217,327 Mcf at an average price of $2.01 per Mcf for 2003 and 14,737 Mcf at an average price of $1.47 per Mcf for 2002.

General and administrative expenses for the year ended December 31, 2003 were $1,259,269 compared to $856,491 for the year ended December 31, 2002. This represents a $402,778 or a 47% increase in 2003 compared to 2002. The primary reasons for the increase in 2003 were (a) an audit expense increase of approximately $100,000; (b) an increase in insurance expense of approximately $32,000; (c) an increase in salary expense of approximately $134,000 related to the addition of two new employees and salary increases for existing employees; (d) an increase in legal and professional services of approximately $60,000; and (e) an increase in travel expenses of $21,000.

During the year ended December 31, 2003, we incurred net profits interest expense of $225,869 associated with the Magness Well compared to $0 in 2002. This was due to the fact that the Magness Well did not commence production until May 2003.

Depreciation and depletion expense for the years ended December 31, 2003 and 2002 were $798,555 and $5,138, respectively. The primary reasons for the $793,417 increase were the expenses related to the Magness Well which commenced production in May 2003.

For the years ended December 31, 2003 and 2002, we incurred impairment expense of $473,496 in 2003, but no impairment expense was incurred in 2002. The 2003 impairment write-downs related to the costs capitalized in connection with the expiration of Permit #386, an exploration permit in Australia, which expired during 2003.

Loss from operations totaled $887,430 for the year ended December 31, 2003 compared to $859,925 for the year ended December 31, 2002. The primary reasons for the increase in the loss were the increases

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in general and administrative expenses and impairment expense experienced in 2003 which offset the revenues from the Magness Well.

Other income for the year ended December 31, 2003 consisted of interest income in the amount of $4,769 compared to $953 for the year ended December 31, 2002. The reason for the increase in 2003 was higher average cash balances in 2003 versus 2002.

During the year ended December 31, 2003, we incurred interest expense of $802,031 ($425,508 in 2002), most of which in both years related to short and long-term indebtedness incurred in connection with activities in the Madisonville Project. We had a higher average level of indebtedness in 2003 as compared to 2002 resulting in higher interest expense for 2003.

Net loss for the year ended December 31, 2003 was $1,684,692 compared to $1,284,480 for the year ended December 31, 2002. The increase in net loss in 2003 was primarily due to significantly higher interest expense in 2003 compared to 2002, as well as the impairment write-down in 2003.

Recent Developments

On June 7, 2006, we loaned $1,000,000 to G. Carter Sedanoui, a shareholder, evidenced by an 8% short term promissory note with a maturity date on March 31, 2007. The note may be repaid at any time without penalty. In the event the note is not repaid by the maturity date, we have full recourse against Mr. Sednaoui. In addition, Mr. Sednaoui has granted us a security interest in 564,120 shares of our common stock which he owns. See “Certain Relationships and Related Party Transactions.”

On June 1, 2006, we, through our subsidiary Redwood LP, entered into a binding preliminary settlement agreement with respect to two lawsuits to which we were a party—the Miller Lawsuit and the Mejlaender Lawsuit. See “Legal Proceedings.”  Under the terms of the settlement, Redwood LP shall pay the plaintiffs $1,100,000 in cash upon the closing of the settlement, execute a 6% promissory note in the amount of $900,000 secured by Redwood LP’s interest in the Magness Well, and assign the Miller Plaintiffs overriding royalty interests of 2% in the Magness Well, 2% in the Fannin Well, 0.75% in the Wilson Well, and 0.5%, 0.3% and 0.2% in the first, second and third wells, respectively, in the event these wells are drilled and completed by Redwood LP below the Rodessa-Sligo Interval. The plaintiffs shall assign to Redwood LP any and all ownership interests they may have had in the Madisonville Prospect below the top of the Rodessa-Sligo Interval and convey all of their overriding royalty interests in the Madisonville Prospect in the Rodessa-Sligo Interval and below.

Liquidity and Capital Resources

We had a working capital surplus of $7,587,193 at March 31, 2006, as compared to capital deficit of $1,855,573 and $6,002,989 at December 31, 2005 and December 31, 2004, respectively. The Company’s working capital increased during three months ended March 31, 2006 due primarily to GeoPetro’s equity financings in the first quarter of 2006.

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We have financed our business activities through March 31, 2006 principally through issuances of common shares, promissory notes and common share purchase warrants in private placements and a public offering in Canada. These financings are summarized as follows:

 

The net proceeds of the private placements have been primarily invested in oil and natural gas properties totaling $6,423,659, $5,602,741, $9,171,589, and $4,228,884 for the three months ended March 31, 2006 and for the years ended December 31, 2005, 2004, and 2003, respectively.

On May 31, 2005, we paid the remaining balance of $962,780 plus accrued but unpaid interest of $4,431 on a note to G. Carter Sednaoui dated July 19, 2004. See “Certain Relationships and Related Party Transactions.”

In October 2005, we sold our 40% interest in Continental-GeoPetro (Yapen ) Ltd. for cash proceeds of $2.4 million. Our cost basis in Continental-GeoPetro (Yapen ) Ltd. was $698,000. The sale of the interest was recorded as a reduction of the capitalized cost pool for the Indonesian properties. We utilized the cash proceeds to repay indebtedness during the fourth quarter of 2005. On October 27, 2005, we repaid the remaining principal balance of $1,260,292 plus accrued but unpaid interest of $8,287 on the Rolling Hill Promissory Note dated October 18, 2002, as well as the unsecured promissory note dated September 30, 2004 with a remaining principal balance of $475,000 and accrued but unpaid interest of $9,058 to Patricia S. Cayce. See “Certain Relationships and Related Party Transactions.”

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Our cash balance at March 31, 2006 was $1,191,534 compared to a cash balance of $914,826 at December 31, 2005. The change in our cash balance is summarized as follows:

 

The cash balance of $1,191,534 at March 31, 2006 does not include: (i) deposits in trust of $10,867,849 which were received into the Company’s cash accounts on April 3, 2006 pursuant to the initial public offering described below, and (ii) restricted cash of $2,000,075 that represents proceeds from the issuance of flow-through shares which must be expended toward Canadian exploration expense as defined in subsection 66.1(6) of the Tax Act of Canada.

During January and February 2006, we conducted a private placement of common shares to accredited investors. We issued 927,314 common shares at $3.50 per share for gross cash proceeds of $3,245,600 (net of $3,123,408).

On January 31, 2006, we borrowed $1,000,000 from Pinehill Capital Inc. pursuant to an 8% promissory note with a maturity date of January 31, 2007. We issued 150,000 shares at $3.50 per share of no par voting common stock warrants with an expiration date on January 31, 2009 to Pinehill Capital Inc., as well as a $30,000 loan origination fee. The fair market value of the warrants on the date of issuance, $182,390, as well as the $30,000 loan origination fee, was recorded as a debt discount and is being amortized over the life of the promissory note. As of March 31, 2006, the unamortized debt discount was $176,992. In the event this note is not repaid by the maturity date, and unless an extension thereof is mutually agreed to, then we have agreed that we shall dedicate 5% of our net cash flow from the Madisonville Field toward the unpaid principal amount and all accrued and unpaid interest thereon, until such amounts are paid in full. Net cash flow for purposes of this provision means gross revenues received by us less royalties, production taxes and net profits interest expense.

On March 30, 2006, we completed an initial public offering pursuant to a final prospectus under the securities laws of each of the provinces of Canada, which consisted of 3,730,021 common shares from our treasury at an issue price of $3.50 per common share and 519,500 common shares issued on a “flow-through” basis under the Income Tax Act of Canada at an issue price of $3.85 per common share for aggregate gross proceeds of $15,055,149. We intend to use the net proceeds of the offering to fund development drilling of proven and probable natural gas reserves associated with the Madisonville Project and to conduct exploration and appraisal activities on our other projects in the United States, Canada and Indonesia.

It is required that we expend $2,000,075 of the proceeds realized from the Canadian offering from the issuance of 519,500 “flow-through” shares toward Canadian exploration expense pursuant to Canadian tax law. Canadian exploration expense generally means, but is not limited to, the drilling of exploratory wells in Canada. Pursuant to the terms of our agreement with the subscribers of the “flow-through” shares, we must renounce the tax deductions which would result from these expenditures and pass the deductions

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through to the holders of these shares. We must incur these expenditures by the end of our fiscal year ended December 31, 2007.

We believe that our current cash and cash equivalents, the net proceeds received from our Canadian initial public offering which closed in March 2006, and anticipated cash flow from operations will be sufficient to meet our working capital, capital expenditures and growth strategy requirements for the 2006 and 2007 periods.

Contractual Obligations

A summary of our contractual obligations as of December 31, 2005  is provided in the following table.

(1)          Lease for our principal executive office located at One Maritime Plaza, Suite 700, San Francisco, CA 94111.

(2)          We have work program commitments associated with our participation net to our 40% working interest in the Bengara II PSC (production sharing contract) in Indonesia. These work program commitments must be met in order to maintain the production sharing contract in effect.

(3)          We have committed to a three well drilling program to facilitate the expansion of the gas treatment plant. The commitment, subject to events of force majeure, including, but not limited to rig availability, requires us to commence the drilling of a well sufficient to test the Rodessa Formation and complete the well if commercial on or before March 1, 2006 and the drilling and completion, if commercial, of a second Rodessa Formation well on or before August 1, 2006. Due to lack of rig availability, we did not commence drilling the first required Rodessa Formation well, the Wilson Well, until March 2006. We did not incur any penalty by invoking force majeure. The Wilson Well has been drilled to a total depth of 12,300 feet in the Rodessa Formation. We commenced drilling its second required well, the Mitchell Well, in April 2006. The commitment further requires us to commence the drilling of a third well sufficient to test the Smackover Formation (estimated to be encountered at approximately 18,000 feet) on or before September 30, 2008. We have granted MGP a security interest in the Madisonville Field properties to secure the three well commitment. The security interest shall be subordinated to any third party lender in the event we secure future debt against the property. MGP granted us a security interest in the Madisonville Field Gas Treatment Plant to secure their obligation to expand the capacity of the facilities.

(4)          Within three years from the date of receipt of assignment of the 100% working interest in the leases in our Cook Inlet Alaska CBM Project, we have the option to conduct a $2.5 million work program consisting of, but not limited to, a multiple test well drilling program on the leases over a three-year period, and, after completion of the work program and an evaluation of the results, to remit the final additional acreage consideration of $10 per acre for the leases estimated at approximately $1,068,000. The Cook Inlet Option provides that if we fail to pay the lease consideration when due, fail to perform

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the work program or otherwise default under the Cook Inlet Option, we shall forfeit our interest and reassign the leases to Pioneer with no further liability to us.

(5)          It is required that we expend $2,000,075 of the proceeds realized from the Canadian offering from the issuance of 519,500 “flow-through” shares toward Canadian exploration expense pursuant to Canadian tax law. Canadian exploration expense generally means, but is not limited to, the drilling of exploratory wells in Canada. Pursuant to the terms of our agreement with the subscribers of the “flow-through” shares, we must renounce the tax deductions which would result from these expenditures and pass the deductions through to the holders of these shares. We must incur these expenditures by the end of our fiscal year ended December 31, 2007.

(6)          This table does not include the liability for dismantlement, abandonment and restoration costs of oil and gas properties. Effective with the adoption of SFAS No. 143, “Accounting for Asset Retirement Obligations,” we recorded a separate liability for the fair value of this asset retirement obligation. See Note 2 of the Notes to Consolidated Financial Statements for further discussion.

In addition to the above commitments, we are subject to prior work commitments, for the eight-year period ended December 3, 2005, requiring total expenditures of $9,200,000 net to our 40% working interest in the Indonesian contract area. As of December 31, 2005, we had met approximately $2,100,000 of the $9,200,000 required expenditures, leaving an approximate $7.1 million shortfall. BP Migas, the applicable governing authority has granted a deferral of the prior years’ commitments until December 2006. We plan to farm out a portion of our interest in the Bengara II PSC to third parties so that the work program commitments, or a portion thereof, will be borne by such third parties. Although we are in discussions with several parties regarding potential farmouts of the Bengara II PSC, no definitive farmout agreements have been reached and there is no assurance that such agreements will be secured. If we do not satisfy the above work expenditure commitments, and provided the applicable governing authority does not grant any further deferrals of those commitments, we may be compelled to relinquish our interest in the contract area. In the event we relinquish our interest, we will record an impairment expense equal to the costs which have been capitalized in connection with the contract area. As of March 31, 2006, we have capitalized costs totaling approximately $375,000 with respect to the contract area.

The above amounts do not include program commitments for our Exploration Permit (EP) 408. The program commitments for EP 408 have been substantially met and require no further significant expenditures.

Other than the above commitments, the timing of most of our capital expenditures is discretionary. We have no material long-term commitments associated with our capital expenditure plans or operating agreements. Consequently, we have a significant degree of flexibility to adjust the level of such expenditures as circumstances warrant. The level of capital expenditures will vary in future periods depending on the success we experience on planned exploratory and appraisal drilling activities, natural gas and oil price conditions and other related economic and political factors. Accordingly, we have not yet prepared an estimate of capital expenditures for periods beyond 2006.

On January 31, 2006 we borrowed $1,000,000 from Pinehill Capital Inc. pursuant to an 8% promissory note with a maturity date of January 31, 2007. In the event this note is not repaid by the maturity date, and unless an extension thereof is mutually agreed to, then we have agreed that we shall dedicate 5% of our net cash flow from the Madisonville Field toward the unpaid principal amount and all accrued and unpaid interest thereon, until such amounts are paid in full. Net cash flow for purposes of this provision means gross revenues received by us less royalties, production taxes and net profits interest expense.

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Income Taxes

As of December 31, 2005, we had net operating loss (NOL) carryforwards of approximately $15,900,000 for federal income tax purposes beginning to expire in 2010 and $8,400,000 for state income tax purposes which began to expire in 2005.

A significant change in our ownership may limit our ability to use these NOL carryforwards. Statement of Financial Accounting Standards No. 109, Accounting for Income Taxes, requires that the tax benefit of such net operating loss be recorded as an asset. At December 31, 2005, we had net deferred tax assets of approximately $4.06 million related to the NOL and other temporary differences. We have recorded a full valuation allowance of $4.06 million at December 31, 2005, due to uncertainties surrounding the realizability of the deferred tax asset.

Off Balance Sheet Arrangements

We do not have any off-balance sheet arrangements.

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 2006.

Outlook for 2006 and 2007

Depending on capital availability, we are forecasting capital spending of up to approximately $22.0 million in 2006 and 2007, allocated as follows:

1.                Madisonville Project, Madison County, Texas. Approximately $14.0 million will be expended in the Madisonville Field area as follows: $13,000,000 to drill and complete two Rodessa Formation development well locations, and $1,000,000 to be utilized for land acquisition, engineering and permitting.

2.                Alaska Cook Inlet Project, up to approximately $3.0 million will be expended for the drilling of pilot program wells.

3.                Bengara Block, East Kalimantan, Indonesia. Up to approximately $3.0 million will be expended towards a drilling program in the Bengara Block.

4.                Central Alberta Reef Project. Up to approximately $2.0 million will be expended to drill exploratory wells and acquire 3-D seismic data.

Management may, in its 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 expect commodity prices to be volatile, reflecting the current tight supply and demand fundamentals for North American natural gas and world crude oil. Political events around the world, which are difficult to predict, will continue to influence both oil and gas prices. Higher prices for oil and gas often lead to higher levels of activity which in turn lead to higher costs to explore, develop and acquire oil and gas reserves. These higher costs could affect the returns on our capital expenditures. Higher crude prices could also help keep natural gas prices high by keeping alternative fuels, such as heating oil and residual fuel, expensive.

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