EGPI FIRECREEK, INC. - Annual Report: 2008 (Form 10-K)

Unassociated Document

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

ý ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended: December 31, 2008

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

For the transition period from: _____________ to _____________

EGPI FIRECREEK, INC.

(Name of small business issuer in its charter)

Nevada	000-32507	88-0345961
(State or Other Jurisdiction	(Commission	(I.R.S. Employer
of Incorporation)	File Number)	Identification No.)

6564 Smoke Tree Lane Scottsdale, AZ 85253

(Address of Principal Executive Office) (Zip Code)

(480) 948-6581

(Registrant’s telephone number, including area code)

N/A

(Former name or former address, if changed since last report)

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

None

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

Common Stock (Par Value $0.001 Per Share)

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

Indicate by check mark if there is no disclosure of delinquent filers in response to Item 405 of Regulation S-B contained in this form, and no disclosures will be contained, to the best of registrant’s knowledge, in definitive proxy information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. o

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

The issuer’s revenues for its most recent fiscal year were $1,437,437, which are included in the discontinued component.

The aggregate market value on March 31, 2009 of common stock held by non-affiliates was approximately $332,877 based on the average of the closing bid and asked prices of the registrant’s common stock on such date, as quoted by the National Quotation Bureau.

As of March 31, 2009, the registrant had 9,547,207 shares of its $0.20 par value common stock issued and outstanding. There are no shares of Series A, B or C preferred stock, issued and outstanding, at $0.001 par value for each of the Series of Preferred, and no shares of non-voting common stock issued and outstanding.

Transitional Small Business (Check One). Yes o No ý

EGPI FIRECREEK, INC.

FORM 10-K

FOR THE FISCAL YEAR ENDED DECEMBER 31, 2008

INDEX

PART I

Item 1.	Description of Business	3
Item 1A.	Risk Factors	8
Item 2.	Description of Property	15
Item 3.	Legal Proceedings	18
Item 4.	Submission of Matters to a Vote of Security Holders	18

PART II

Item 5.	Market for Common Equity and Related Stockholder Matters	18
Item 6.	Selected Financial Data	22
Item 7.	Management’s Discussion and Analysis or Plan of Operation	23
Item 8.	Financial Statements and Supplementary Data	F-1-17
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	28
Item 9AT.	Controls and Procedures	28
Item 9B.	Other Information	28

PART III

Item 10.	Directors, Executive Officers, Corporate Governance	30
Item 11.	Executive Compensation	32
Item 12.	Security Ownership of Certain Beneficial Owners and Management	34
Item 13.	Certain Relationships And Related Transactions, And Director Independence	35
Item 14.	Principal Accountant Fees and Services	40

PART IV

Item 15.	Exhibits, Financial Statement Schedules	40

	SIGNATURES	43

This Annual Report on Form 10-K includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The Company has based these forward-looking statements on the Company’s current expectations and projections about future events. These forward-looking statements are subject to known and unknown risks, uncertainties and assumptions about us and the Company’s subsidiaries that may cause the Company’s actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by such forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “will,” “should,” “could,” “would,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “continue” or the negative of such terms or other similar expressions. Factors that might cause or contribute to such a material difference include, but are not limited to, those discussed elsewhere in this Annual Report, including the section entitled “Risks Particular to the Company’s Business” and the risks discussed in the Company’s other Securities and Exchange Commission filings. The following discussion should be read in conjunction with the Company’s audited Consolidated Financial Statements and related Notes thereto included elsewhere in this report.

PART I

ITEM 1 - DESCRIPTION OF BUSINESS

HISTORY

EGPI Firecreek, Inc. (the “Company”, “EGPI”, “we”, “us” or “our” ) was incorporated in the state of Nevada on October 4, 1995 as Sterling Market Positions, Inc. with 10,000,000 shares of $.001 par value common stock authorized. Effective June 24, 1999, the Company changed its name to Energy Producers, Inc. and increased its authorized common shares to 50,000,000 with a par value of $0.001. The Company’s principal place of business is 6564 Smoke Tree Lane, Scottsdale, AZ 85253.

On August 25, 1999, the Company was acquired by Energy Producers Group, Inc., and its wholly owned subsidiary, Producers Supply, Inc. The purpose of the acquisition and reverse merger was to become an oil and gas company, and later diversify. The Company focused its business on oil and gas exploration and acquiring existing production with proven reserves.

On December 31, 2005 the board of directors of the Company authorized the disposal of the Company’s wholly owned subsidiary marine sales segment assets and operations International Yacht Sales Group, Ltd. located in Torquay Devon, United Kingdom.

In March 2006 the Company through its wholly owned subsidiary Firecreek Petroleum, Inc, (“Firecreek”), began production and sale of natural gas from completed wells located in Sweetwater County, Wyoming.

On December 13, 2006, the Company increased its total authorized capital stock from 980,000,000 shares to 1,300,000,000.

On July 1, 2007 the Company through its wholly owned subsidiary Firecreek began production and sale of oil from the Fant Ranch Unit located in Knox County, Texas.

On July 3, 2008 the Company through its wholly owned subsidiary Firecreek began production and sale of oil and gas from the J.B. Tubb leasehold estate located in Ward County, Texas.

Effective on October 8, 2008 the Company affected a one (1) for two hundred (200) reverse stock split whereby, as of the Record Date, for every two hundred shares of common stock then owned, each shareholder received one share of common stock.

On October 30, 2008 the Company’s wholly owned subsidiary Firecreek sold its 50% undivided interest in the Ten Mile Draw natural gas leases in Sweetwater County, Wyoming.

On December 2, 2008 as a result of a default notice received October 24, 3008 on Promissory Notes and Debentures held by Dutchess Private Equities Fund, Ltd (“Dutchess”), all of the assets were transferred or disposed of.

Overview

The Company, through its wholly-owned subsidiary Firecreek, has been building and integrating a line segment of operations facilitating plans for the Company’s oil and gas operations.

In 2007 the Company began focusing its efforts on development of domestically based oil and gas acquisition and production located in Texas and Wyoming.

In 2008 the Company expanded its oil and gas operations in Texas with the acquisition and development of majority interests held in the J.B. Tubb leasehold estate.

RECENT DEVELOPMENTS

On December 3, 2008, the Company received resignations from each of Douglas Leighton, Michael Novielli, Theodore Smith, and Douglas D’Agata as members of the Company’s board of directors. Further, on December 3, 2008, Mr. Douglas D’Agata resigned as the Company’s authorized officer.

On December 3, 2008, Mr. Dennis Alexander was re-appointed to the Board of Directors of the Company and as the Chief Executive Officer and Chief Financial Officer. Further, on December 3, 2008, Larry W. Trapp, and Mike Trapp were appointed to the Board of Directors. Further, Larry W. Trapp was appointed as Executive Vice President and Co-Treasurer, and Melvena Alexander was appointed Secretary, Comptroller, and Co-Treasurer.

On December 2, 2008 based upon completion of the disposal by Dutchess of all EGPI assets, all the debt to Dutchess claimed in the Notice of Default and all obligations of EGPI to Dutchess under the Loan Agreements were deemed fully satisfied. Further the Company issued a promissory note in favor of Dutchess in the principal face amount of $47,564.78 in consideration of certain Oil and Gas Property Participation and Rights Agreement. For additional information please see our Current Report on Form 8-K filed December 3, 2008, incorporated herein by reference, and Exhibits 10.32 (Oil and Gas Property Participation and Rights Agreement), and Exhibit 10.34 (Promissory Note Agreement) filed with this report.

The Company throughout its first quarter of operations for 2009 has been pursuing projects, seeking financing, and in negotiations for acquisition and development of select targeted oil and gas proved producing properties with revenues, having upside potential and prospects for enhancement, rehabilitation, and future development. These prospects are primarily located in Eastern Texas, and in other core areas of the Permian Basin.

THE BUSINESS

The Company has been building and integrating a line segment of operations facilitating plans for the Company’s continuation of its oil and gas infrastructure and domestically focused oil and gas operations.

In 2007, the Company commenced with oil production related to the acquisition of the Fant Ranch Unit in Knox County, Texas (“Fant Unit or Fant”). The Company’s production of oil was initiated from 17 producing oil wells and 1 injection well in the Fant system. In September of 2007 two more wells were brought online, one well for oil production, and one for water stimulation.

Throughout most of fiscal 2008 we deployed enhancement and rehabilitation programs on several wells in the Fant Ranch Unit system increasing its overall performance. Further we acquired a 75% working interests in the J.B. Tubb leasehold estate located in the Amoco Crawar Field, Ward County Texas, and began a turn key re-entry and development program for oil and gas. The Company successfully completed two wells, and added a third stripper well for production of oil and gas.

The Company was seeking to continue its expansion and growth for oil and gas development, but due to economic circumstances which led to downturn factors, we received an untimely default notice which resulted in forced disposition of our assets.

We have been pursuing a re-build of our basic infrastructure and negotiating for new acquisitions.

Firecreek Oil and Gas - Shift of Focus to Domestic Operations

Our goal is to become an independent oil and gas company engaged in the exploration, development and exploitation of crude oil and natural gas primarily in the United States.

In 2007 due to the rising costs related to the pursuit of overseas activities relative to the cost of financing for our Company, we elected to curtail foreign expenditures and concentrate on domestic projects (see historical information in previous reports filed on Form 10-KSB).

Firecreek’s 2008 Oil and Gas Operations

Ten Mile Draw Project, Sweetwater County, Wyoming

Effective November 15, 2005, Firecreek purchased a 50% undivided non-operating interest in certain leases, wells, equipment, mineral interests including oil and gas reserves, and other rights, (the “Assets”) located in Sweetwater County, Wyoming from Newport Oil Corporation (“Newport”), under the prospect named “Ten Mile Draw” (“TMD”). An Operating Agreement was entered into at the time of the purchase, whereas Newport became operator for Firecreek’s non-operated 50% interests, and Newport’s operated 50% interests.

Sale of TMD

On October 30, 2008, the Company and NOC entered into an Agreement for Sale of Mineral Rights and an Assignment and Bill of Sale (collectively, the “Agreements”) relating to the Company’s sale, and NOC’s purchase, of the Company’s fifty percent (50%) undivided interest in the mineral rights created by oil and gas leases on the TMD real property, as described in the Agreements (“Mineral Rights”). Moreover, included in the sale was all of the Company’s interest in a lawsuit currently pending in the Third Judicial District Court of Sweetwater County, Wyoming (case Number Civil C-07-821-R, and styled Newport Oil Corp. v. Inter-Mountain Pipe and Threading Co.) (the “Suit”).The purchase price for these Mineral Rights and Suit was $125,000, payable in cash at closing.

A copy of the Agreement for Sale of Mineral Rights and Assignment and Bill of Sale are filed as Exhibits 10.1 and 10.2, respectively in a Current Report on Form 8-K filed on October 31, 2008, incorporated herein by reference.

Fant Ranch Unit Project, Knox County, Texas

Effective July 1, 2007, Firecreek purchased a 100% working interest and corresponding 75% net revenue interest in certain leases, wells, equipment, mineral interests, oil and gas reserves (the “Assets”), known as the Fant Ranch Unit (“Fant”) located in Knox County, Texas from Ward Energy LP (“Ward”). We entered into a standard operating agreement at the time of the purchase with Success Oil Co. Inc., (“Success”) whereas Success became operator on behalf of the interests in Fant held by the Company through Firecreek, and subsequently taking over operations in transition from Wards then Operating unit. In September and October 2007, Firecreek engaged Success to initiate a Phase 1 workover and restoration program for two additional wells, the no.’s 7-1 and 1-4, to restore their production to bring on line for sales of oil. In January 2008, Firecreek commenced with a phase 2 enhancements /rehabilitation program for the Fant. The program included cleaning out casing perforations, maintenance, paraffin removal, repair and acid stimulation for a majority of the oil wells in the unit. The purpose of the program authorized was to maintain the existing wells regularly, and to increase the overall well efficiency and production for the field. The Company spent approximately $325,000 in its phase 2 program.

Disposition of Fant Ranch Unit Interests

On December 2, 2008, in connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., the Fant Ranch Unit was disposed of and is no longer owned by the Company.

J.B. Tubb Leasehold Estate, AMOCO CRAWAR FIELD, Ward County, Texas

In January, 2008, Firecreek entered into an Assignment and Bill of Sale (the “Assignment”) with Success Oil Co., Inc. (“SOC”) relating to the purchase and sale of 75% working interests along with 56.25% corresponding net revenue in certain 40 acre tract of land and leases (the “North 40”), with and including a first right for an additional 40 acre lease (the “South 40”), located in Ward County, Texas, more commonly known as the J.B. Tubb leasehold estate (the “Tubb Lease”). The Company participated in a workover, drilling and development program, and brought three wells online as a result. The Company paid $1,400,000 for the lease, equipment and a Participation Agreement which provided for turnkey drilling, re-entry, and included multiple wells on the North 40 Acres. Firecreek subsequently acquired assignment of one Lower Clearfork formation in the Crawar Highland 2 Wellbore which is located on the South 40 of the J.B. Tubb Leasehold Estate (also see information contained in Current Report on Form 8-K/A filed on April 30, 2008). The Tubb Lease workover, drilling and development programs brought three wells online resulting in two of the three wells effectively producing and selling oil and gas through the disposition of the leases on December 2, 2008. For further information please see our Current Report on Form 8-K, as amended, originally filed on January 9, 2008, and amended and filed on April 30, 2008, incorporated herein by reference.

Disposition of J.B. Tubb Interests

On December 2, 2008, in connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., the 75% Working Interests held in the J.B. Tubb Leasehold Estate was disposed of and is no longer owned by the Company.

Competition

The oil and gas industry is highly competitive. As a new independent domestic producer entering the oil and gas business, the Company will not initially own and may never own any refining or retail outlets and may have little control over the price it will receive for planned crude oil production. Although management has established relationships in its proposed acquisition activities, significant competition by individual producers and operators or major oil companies exists. Integrated and independent companies and individual producers and operators are active bidders for desirable oil and gas properties. Many of these competitors have greater financial resources than the Company currently has now or may have in the near future.

Sales and Marketability

TMD Project, Wyoming

Through its Disposition, October 30, 2008

The Company through its Firecreek unit commenced selling natural gas during 2006 through the interests it held in the leases, wells, and equipment in the TMD. A Gas Purchase Agreement was entered into November 11, 2005 by Emerald Operating Company (“Emerald”) as “Producer”, and Western Gas Resources, Inc. (“Western”). Effective January 1, 2006, Newport, the Company’s Operator for its interests in the TMD Project and Western, signed a Ratification Agreement, adopting the Gas Purchase Agreement as the agreement between them covering gas purchases, pursuant to which Newport became the “Producer”. Newport is the operating partner for our non operated interests owned in the TMD. The Gas Purchase Agreement had a term of three years, continuing thereafter until either party gives written notice of termination at least thirty days prior to the expiration of the primary term or any extension of the primary term. Payments relative to the Company’s receipt from Newport, based on Gas received to the pipeline were estimated to be a standard 45-60 days following monthly settlement and calculation by Western. The British Thermal Unit (BTU) content of our gas produced in the TMD workover wells tested above standard. Through Newport we were entitled to receive bonus payment adjustment increase for sales of gas, less gathering fees, as applicable, in accordance with the then terms and calculations of the Gas Purchase Agreement. Prices paid by Western accordingly were adjusted for a BTU content of each zone as well as the liquids revenue received. The Company believes it had no commitment that obligated us to produce any set amount of natural gas.

Fant Ranch Unit, Texas

The Company received, through December 2, 2008, its monthly payment for the Fant Units production of oil in Knox County, Texas by division order with BML Inc. to Success Oil Co., Inc. BML purchases all of the Company’s crude oil pertaining to its interests owned based on a month-to-month contract, which could then be terminated upon thirty (30) day’s notice by either party. A division order is a contract for the sale of oil, by the holder of a revenue interest in well or property, to the purchaser. It lists the names of revenue interest owners of a producible oil well or wells, along with the respective share of production revenues, and directs the purchaser to distribute the proceeds of production sales, accordingly. The Company received according to its interests for the oil sold to BML, through December 2, 2008, the average of the Plains price for the oil in for the month sold, adjusted by Platt pricing, less a transportation cost for the oil of $1.75 per barrel. The Company had no commitment that obligated us to produce any set amount of oil (see also “Management’s Discussion and Analysis of Financial Condition, and Plan of Operation", and "Description of properties").

Historically the marketability of the Company's crude oil has not posed a problem for us. Crude oil can be easily sold wherever it is produced in the state(s) that the Company operates subject to the transportation cost. For example, the crude oil produced by the Company via certain of its oil and gas interests which were disposed of on December 2, 2008 had been transported by truck. On the other hand, natural gas can be considered more difficult to sell since transportation requires a pipeline. In some of the areas that the Company has pursued new drilling activity for natural gas, other companies have been delayed up to a year because of the unavailability of a pipeline. No assurance can be given that natural gas wells drilled by the Company, if any, will be placed on line within a year after the well is drilled and completed.

Future Development Contemplated,

J.B. Tubb Leasehold Estate, AMOCO CRAWAR FIELD, Ward County, Texas

As part of the disposition of its assets the Company and Dutchess entered into an Oil and Gas Property Participation and Rights Agreement (“Participation Agreement”), filed on Exhibit 10.32 with this report, whereby Dutchess granted EGPI, under certain circumstances listed therein the participation agreement, a right of first refusal, as provided in Section VIII of that certain participation agreement between Success Oil Co. and EGPI and its wholly-owned subsidiary, Firecreek Petroleum, Inc., dated January 3, 2008.

Wyoming Regulations

Any oil undertaking within the State of Wyoming requires obtaining the necessary permits and approvals from the Wyoming Oil and Gas Conservation Commission (“WOGCC”). Once a lease is obtained, an operator’s agreement must be on file with the WOGCC. In addition, federal regulations including those governed by the Environmental Protection Agency must be strictly followed (see additional discussion addressing the regulatory environment governing oil & gas drilling and production found under “Business Risks” “Governmental Regulation”). We believe our operator Newport has obtained all necessary permits to operate the two workover wells associated with the Company’s interests in TMD project held by Firecreek prior to October 30, 2008.

Texas Regulations

Any oil undertaking with the State of Texas requires obtaining necessary permits and approvals from the Railroad Commission of Texas (“RRC”). Once a lease is obtained an operator’s agreement must be on file with the RRC. Federal regulations including those governed by the Environmental Protection Agency must also be strictly followed (see additional discussion addressing the regulatory environment governing oil & gas drilling and production found under “Business Risks” “Governmental Regulation”). We believe our operator Success has obtained and or filed all necessary permits and reports to operate the wells and maintain compliance associated with the Company’s interests in Fant Ranch Unit held by Firecreek prior to December 3, 2008.

Entry and Eventual Stability In The Oil And Gas Business Will Be Dependent Largely On Our Ability To Acquire Significant Financing Amounts

The Company’s entry and eventual stability in the oil and gas business will be dependent largely on our ability to continuously acquire significant financing amounts, and other potential financing providers, to carry out and implement its plans (see “Management Discussion and Analysis”, “Business Risks”, and “Liquidity and Capital Resources” sections).

The Company and its Firecreek unit are presently in different stages of review and discussion, gathering data and information, and any available reports on other potential field acquisitions, work over programs, and new drilling projects, located in Texas, New Mexico, and other productive regions and areas in the U.S. However, no assurances can be given by the Company that will be successful in pursuing these other prospects.

Successful negotiations for acquisitions, confidentiality, timing and the Company’s financial capabilities will continue to play a significant role in any success of both current and future operations for the Company activities, including its subsidiary operations, and or any future planned subsidiary or special purpose entity (SPE) operations which in the future may exist.

From time to time Management will examine oil and gas operations in other geographical areas for potential acquisition and joint venture development.

Firecreek’s Overseas Project Activity Development in Central Asian and European Countries

Strategic Alliance with Sahara Group

For historical information regarding the Sahara Group please see the section titled “The Business” and other information contained in Form 10-KSB, as amended, filed April 14, 2006, and in Form 10-KSB/A (Amendment No. 3), as amended filed April 11, 2008.

In 2007 and 2008, the Company focused on its domestic US oil and gas operations. There was no further activity with the Sahara group in Russia, Kazakhstan, Ukraine and Turkey, with the exception of the sale of certain opportunity rights to access of projects in Ukraine (for further information please see Item 6, Management Discussion and Analysis or Plan of Operation presented further this Report). It is the Company’s intention to wind down the Sahara entity. The Company may re enter negotiations at a future date predicated on the contacts and business relationships previously established in these countries.

Firecreek’s Future Planned Oil and Gas Operations

Status of Firecreek’s Overseas Project Activity

For current status of Firecreek please see information in this section “The Business” under above sub heading “Firecreek Oil and Gas Segment”. For historical information please also see “The Business” and other information contained in Form 10-KSB, Amendment No. 1, filed on July 24, 2008, and in Form 10-KSB/A (Amendment No. 3), as amended filed April 11, 2008,

In 2007 and 2008 the Company focused on its’ domestic US oil and gas operations. There was no further activity for Firecreek’s Overseas project activity in Romania and Libya. The Company may re enter negotiations at a future date predicated on the contacts and business relationships previously established in these countries.

ITEM 1A.

RISK FACTORS

RISKS RELATED TO OUR BUSINESS

We incurred historical losses and have a working capital deficit. As a result, we may not be able to generate profits, support our operations, or establish a return on invested capital.

We had a net loss on continuing operations in the fiscal year ended December 31, 2008 of $578,717 and a net loss on continuing operation in fiscal year ended December 31, 2007 of $359,182. We incurred a net income in fiscal year ended December 31, 2008 of $3,264,439 and a net loss in fiscal year ended December 31, 2007 of $1,474,050. As of December 31, 2008, we had a working capital deficit of $594,702. In addition, we expect to increase our infrastructure and operating expenses to fund our anticipated growth. As a result, we may not be able to generate profits in 2009 or thereafter and may not be able to support our operations or otherwise establish a return on invested capital. We cannot assure you that any of our business strategies will be successful or that significant revenues or profitability will ever be achieved or, if they are achieved, that they can be consistently sustained or increased on a quarterly or annual basis.

We Expect Our Operating Losses To Continue

The Company expects to incur increased operating expenses during fiscal year 2009. The amount of net losses and the time required for the Company to reach and sustain profitability are uncertain. The likelihood of the Company’s success must be considered in light of the problems, expenses, difficulties, and delays frequently encountered in connection with a new business, including, but not limited to, uncertainty as to development and acquisitions and the time required for the Company’s planned production to become available in the marketplace. There can be no assurance that the Company will ever generate increased product revenue or achieve profitability at all or on any substantial basis.

Our Level Of Indebtedness May Affect Our Business.

Our level of indebtedness could have important consequences for our operations, including:

We may need to use a large portion of our cash flow to repay principal and pay interest on our current and anticipated debt, which will reduce the amount of funds available to finance our operations and other business activities;

Our debt level may make us vulnerable to economic downturns and adverse developments in our businesses and markets; and

Our debt level may limit our ability to pursue other business opportunities, borrow money for operations or capital expenditures in the future or implement our business strategy.

We expect to obtain the funds to pay our expenses and to pay principal and interest on our debt by utilizing cash flow from operations. Our ability to meet these payment obligations will depend on our future financial performance, which will be affected by financial, business, economic and other factors. We will not be able to control many of these factors, such as economic conditions in the markets in which we operate. We cannot be certain that our future cash flow from operations will be sufficient to allow us to pay principal and interest on our debt and meet our other obligations. If cash flow from operations is insufficient, we may be required to refinance all or part of our existing debt, sell assets, and borrow more money or issue additional equity.

We have a limited amount of cash and are likely to require additional capital to continue our operations.

We have a limited amount of available cash and will likely require additional capital to successfully implement our business plan; There can be no assurance that we will be able to obtain additional funding when needed, or that such funding, if available, will be obtainable on terms acceptable to us. In the event that our operations do not generate sufficient cash flow, or we cannot obtain additional funds if and when needed, we may be forced to curtail or cease our activities, which would likely result in the loss to investors of all or a substantial portion of their investment.

Production Risks

All of the Company’s current and proposed oil and gas activities would be subject to the risks normally incident to the exploration for, and development and production of, natural gas and crude oil. These include, but are not limited to, blowouts, cratering and fires, each of which could result in damage to life and property. In accordance with customary industry practices, the Company plans to maintain future insurance for its proposed operations against some, but not all, of the risks. Losses and liabilities arising from such events could reduce revenues and increase costs to the Company to the extent not covered by insurance.

Risks And Uncertainties Can Impact Our Growth

There are several risks and uncertainties, including those relating to the Company’s ability to raise money and grow its business and potential difficulties in integrating new acquisitions for the oil and gas sector of operations, especially as they pertain to foreign markets and market conditions. These risks and uncertainties can materially affect the results predicted. Other risks include the Company’s limited operating history, the limited financial resources, domestic or global economic conditions, activities of competitors and the presence of new or additional competition, and changes in federal or state laws and conditions of equity markets.

The Company’s future operating results over both the short and long term will be subject to annual and quarterly fluctuations due to several factors, some of which are outside the control of the Company. These factors include but are not limited to fluctuating market demand for our services, and general economic conditions.

Governmental Regulation

Effect of Probable Governmental Regulation on the Business Domestically and in Foreign Countries

As we expand our efforts to develop our business, we will have to remain attentive to relevant federal and state regulations. We intend to comply fully with all laws and regulations, and the constraints of federal and state restrictions could impact the success of our efforts.

Our oil and gas business and services may become established in multiple states and foreign countries. These jurisdictions may claim that we are required to qualify to do business as a foreign corporation in each such state and foreign country. New legislation or the application of laws and regulations from jurisdictions in this area could have a detrimental effect upon our business. We cannot predict the impact, if any, that future regulatory changes or developments may have on our business, financial condition, or results of operation.

The Company and its current and future operations are subject to federal, state and local laws, and regulations and ordinances relating to the production and sale of oil and gas. Some of the laws that the Company is subject to include the Clean Air Act, the Clean Water Act, and the Endangered Species Act. Other laws and regulations include laws governing allowable rates of production, well spacing, air emissions, water discharges, marketing, pricing, taxes, and use restrictions and other laws relating to the petroleum industry. For example, coal bed methane wells are being highly regulated for disposing of produced fresh water on the surface. The EPA is requiring that the fresh water meet more stringent standards than before, and can require the water be injected underground making drilling these wells potentially uneconomical. As another example, Governmental regulation may delay drilling in areas that have endangered species. Therefore, if the Company were to undertake a drilling program in such an area by a proposed development project in the future, no assurance could be given that such delays would not become more expensive. Regulations may have a negative financial impact on us depending on the compliance costs.

Any failure to obtain, or delays in obtaining regulatory approvals by the Company or its operators, could delay or adversely affect the Company’s ability to generate revenues. These laws and regulations could impose substantial liabilities for the Company if it fails to comply. Further, there can be no assurance that the Company through its contract operators will be able to obtain necessary regulatory approvals for any of its future activities including those which may be proposed for the further development of oil and gas. Although the Company does not anticipate problems satisfying any of the regulations involved, the Company cannot foresee the possibility of new regulations, which could adversely affect the business of the Company.

Environmental regulations and taxes imposed by state governments in a jurisdiction wherein oil and gas properties are located impose a burden on the cost of production. Of the gross production revenues, severance and ad valorem taxes in Wyoming for oil and gas amount to approximately 12%.

Environmental requirements do have a substantial impact upon the energy industry. Generally, these requirements do not appear to affect the proposed Company operations any differently, or to any greater or lesser extent, than other companies in the domestic industry as a whole. The Company will establish policies and procedures for compliance with environmental laws and regulations affecting its proposed operations. The Company believes that compliance with environmental laws and regulations will not have a material adverse effect on the Company’s operations or financial condition. There can be no assurances, however, that changes in or additions to laws or regulations regarding the protection of the environment will not have such an impact in the future.

At this time no regulatory or additional regulatory approvals are necessary and, to the best knowledge of the officers, we have complied with all laws, rules and regulations.

Cost And Effects Of Compliance With Environmental Laws

Our business will be subject to regulation under the state and federal laws regarding environmental protection and hazardous substances control with respect to its current and future oil and gas operations. We are unaware of any bills currently pending in Congress that could change the application of such laws so that they would affect us.

Risk Factors Affecting Our Future Results Of Operations For The Company

Due to the Company’s limited operating history, it is difficult to predict future revenues accurately. This may result in one or more future quarters where the Company’s financial results may fall below the expectation of management and investors. However firmly management may believe in its prospects, the Company could fail. Operating results may vary, depending upon a number of factors, many of which are outside the Company’s control. Material factors expected to impact the Company’s operating results include, legal costs associated with registration of options and other filing requirements, expansion activities, increased interest and expenses for borrowings and possible hiring of additional full time employees. Every investor should evaluate the risks, uncertainties, expenses and difficulties frequently encountered by companies in the early stage of development. The past performance of the Company cannot be used to predict the future performance.

Lack Of Experience

Certain of our management may only devote a small percentage of their time to Company business. This lack of specific training, and experience for integration of the oil and gas sector coupled with working in the regulatory environment and less than full time effort in certain cases will probably cause management to miss opportunities that more experienced managers would recognize and take advantage of. Management’s decisions and choices may not be well thought out and operations and earnings and ultimate financial success may suffer irreparable harm. Additionally, these individuals have not previously worked together. If senior executives and managers are unable to work effectively as a team, business operations could be considerably disrupted.

Oil And Gas Prices Fluctuate Widely, And Low Prices For An Extended Period Of Time Are Likely To Have A Material Adverse Impact On Our Business

Our revenues, operating results, financial condition and ability to borrow funds or obtain additional capital depend substantially on prevailing prices for natural gas and, to a lesser extent, oil. Declines in oil and natural gas prices may materially adversely affect our financial condition, liquidity, ability to obtain financing and operating results. Lower oil and gas prices also may reduce the amount of oil and gas that we can produce economically. Historically, oil and gas prices and markets have been volatile, with prices fluctuating widely, and they are likely to continue to be volatile.

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 gas, market uncertainty and a variety of additional factors that are beyond our control. These factors include:

The domestic and foreign supply of oil and natural gas.

The level of consumer product demand.

Weather conditions.

Political conditions in oil producing regions, including the Middle East.

The ability of the members of the Organization of Petroleum Exporting Countries to agree to and maintain oil price and production controls.

The price of foreign imports.

Actions of governmental authorities.

Domestic and foreign governmental regulations.

The price, availability and acceptance of alternative fuels.

Overall economic conditions.

These factors make it impossible to predict with any certainty the future prices of oil and gas.

Drilling natural gas and oil wells is a high-risk activity.

Our growth is materially dependent upon the success of our drilling program. Drilling for natural gas and oil involves numerous risks, including the risk that no commercially productive natural gas or oil reservoirs will be encountered. The cost of drilling, completing and operating wells is substantial and uncertain, and drilling operations may be curtailed, delayed or cancelled as a result of a variety of factors beyond our control, 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 or crews and the delivery of equipment.

Our future drilling activities may not be successful and, if unsuccessful, such failure will have an adverse affect on our future results of operations and financial condition. Our overall drilling success rate or our drilling success rate for activity within a particular geographic area may decline. We may ultimately not be able to lease or drill identified or budgeted prospects within our expected time frame, or at all. We may not be able to lease or drill a particular prospect because, in some cases, we identify a prospect or drilling location before seeking an option or lease rights in the prospect or location. Similarly, our drilling schedule may vary from our capital budget. The final determination with respect to the drilling of any scheduled or budgeted wells will be dependent on a number of factors, including:

·	the results of exploration efforts and the acquisition, review and analysis of the seismic data

·	the availability of sufficient capital resources to us and the other participants for the drilling of the prospects

·	the approval of the prospects by other participants after additional data has been compiled

·	economic and industry conditions at the time of drilling, including prevailing and anticipated prices for natural gas and oil and the availability of drilling rigs and crews

·	our financial resources and results; and

·	the availability of leases and permits on reasonable terms for the prospects.

These projects may not be successfully developed and the wells, if drilled, may not encounter reservoirs of commercially productive natural gas or oil.

Reserve estimates depend on many assumptions that may prove to be inaccurate. Any material inaccuracies in our reserve estimates or underlying assumptions could cause the quantities and net present value of our reserves to be overstated.

Reserve engineering is a subjective process of estimating underground accumulations of natural gas and crude oil that cannot be measured in an exact manner. The process of estimating quantities of proved reserves is complex and inherently uncertain, and the reserve data included in this document are only estimates. The process relies on interpretations of available geologic, geophysic, engineering and production data. As a result, estimates of different engineers may vary. In addition, the extent, quality and reliability of this technical data can vary. The differences in the reserve estimation process are substantially due to the geological conditions in which the wells are drilled. The process also requires certain economic assumptions, some of which are mandated by the Securities and Exchange Commission, such as natural gas and oil prices. Additional assumptions include drilling and operating expenses, capital expenditures, taxes and availability of funds. The accuracy of a reserve estimate is a function of:

the quality and quantity of available data;

the interpretation of that data;

the accuracy of various mandated economic assumptions; and

the judgment of the persons preparing the estimate.

Results of drilling, testing and production subsequent to the date of an estimate may justify revising the original estimate. Accordingly, initial reserve estimates often vary from the quantities of natural gas and crude oil that are ultimately recovered, and such variances may be material. Any significant variance could reduce the estimated quantities and present value of our reserves.

Our future performance depends on our ability to find or acquire additional natural gas and oil reserves that are economically recoverable.

In general, the production rate of natural gas and oil properties declines as reserves are depleted, with the rate of decline depending on reservoir characteristics. Unless we successfully replace the reserves that we produce, our reserves will decline, eventually resulting in a decrease in natural gas and oil production and lower revenues and cash flow from operations. Our future natural gas and oil production is, therefore, highly dependent on our level of success in finding or acquiring additional reserves. We may not be able to replace reserves through our exploration, development and exploitation activities or by acquiring properties at acceptable costs. Low natural gas and oil prices may further limit the kinds of reserves that we can develop economically. Lower prices also decrease our cash flow and may cause us to decrease capital expenditures.

Exploration, development and exploitation activities involve numerous risks that may result in dry holes, the failure to produce natural gas and oil in commercial quantities and the inability to produce discovered reserves fully. We are continually identifying and evaluating opportunities to acquire natural gas and oil properties. We may not be able to consummate any acquisition successfully, to acquire producing natural gas and oil properties that contain economically recoverable reserves, or to integrate the properties into our operations profitably.

Seasonality

Demand for natural gas has historically been seasonal, with peak demand and typically higher prices occurring during the colder winter months.

Regulation of Oil and Natural Gas Exploration and Production

Exploration and production operations are subject to various types of regulation at the federal, state and local levels. This regulation includes requiring permits to drill wells, maintaining bonding requirements to drill or operate wells, and regulating the location of wells, the method of drilling and casing wells, the surface use and restoration of properties on which wells are drilled, and the plugging and abandoning of wells. Our operations are also subject to various conservation laws and regulations. These include the regulation of the size of drilling and spacing units or proration units, the density of wells that may be drilled in a given field and the unitization or pooling of oil and natural gas properties. Some states allow the forced pooling or integration of tracts to facilitate exploration while other states rely on voluntary pooling of lands and leases. In addition, state conservation laws establish maximum rates of production from oil and natural gas wells, generally prohibiting the venting or flaring of natural gas and impose certain requirements regarding the ratability of production. The effect of these regulations is to limit the amounts of oil and natural gas we can produce from our wells, and to limit the number of wells or the locations where we can drill. Because these statutes, rules and regulations undergo constant review and often are amended, expanded and reinterpreted, we are unable to predict the future cost or impact of regulatory compliance. The regulatory burden on the oil and gas industry increases the cost of doing business and, consequently, affects profitability. We do not believe, however, that we are affected differently by these regulations than others in the industry.

We have limited control over the activities on properties we do not operate.

Other companies operate some of the properties in which we have an interest. We have limited ability to influence or control the operation or future development of these non-operated properties or the amount of capital expenditures that we are required to fund with respect to them. The failure of an operator of our wells to perform operations adequately, an operator’s breach of the applicable agreements or an operator’s failure to act in ways that are in our best interest could reduce our production and revenues. Our dependence on the operator and other working interest owners for these projects and our limited ability to influence or control the operation and future development of these properties could materially adversely affect the realization of our targeted returns on capital in drilling or acquisition activities and lead to unexpected future costs.

Requirement For Additional Capital

The Company believes that additional debt or equity financing will be necessary to develop its planned activities through the next twelve to twenty four months. However, no assurance can be given that all or a significant portion of any debt or equity financing will be consummated, or that any changes in the Company’s operations and expansion plans would not consume available resources more rapidly than anticipated. The Company will need substantial funding to support the long-term expansion, development, and marketing of its business and subsidiary operations.

To the extent that the Company’s capital resources, including the proceeds of any offering, are insufficient to meet current or planned requirements, the Company will continue to seek additional funds through equity or debt financing, collaborative, or other arrangements with corporate partners, and from other sources, which may have the effect of diluting the holdings of existing shareholders. The Company has no effective or approved current arrangement with respect to such additional financing that is either secured or finalized at this time. Even though the Company has existing prospects for general or project financing, the outcome may change, be delayed, or may not be conclusive, therefore financing is not assured or guaranteed. Financing to be potentially obtained from prospects is not assured or guaranteed until actually consummated and financing actually provided.

Need For Expansion

The Company expects expansion will be required to address potential growth. This need for expansion will continue to place a significant strain on the management and financial resources of the Company. Failure to manage growth could disrupt the operations and ultimately prevent the Company from generating expected revenues. The Company’s business strategy includes entering into business partnerships and may include acquiring future businesses, such as, existing production or products, technology and acquisitions related to oil and gas or other resources, oil and gas field operations, and engineering. Other areas of future operations may include real estate, land and commercial development, technology and facilities, and fuel cell technology. The Company may be unable to complete suitable business partnerships and acquisitions on commercially reasonable terms, if at all. Competition could impair the Company’s ability to pursue these aspects successfully of this business strategy.

Business partnerships or acquisitions could disrupt ongoing business, distract management and employees and increase expenses. If the Company makes an acquisition, it could face difficulties assimilating that company’s personnel and operations. Key personnel of the acquired company may decide not to work for the Company. Acquisition of additional services or technologies also involves risk of incompatibility and lack of integration into existing operations. If the Company finances the acquisitions by issuing equity securities, this could dilute existing stockholders positions. Additionally, funding instruments may have rights, preferences or privileges senior to, or more favorably than, those of the Company’s stockholders.

Limited Financial Data

As a result of its limited operating history, the Company has limited historical financial data upon which to forecast revenues and results of operation. The actual effect of these factors on the price of stock will be difficult to assess. Results of operation may fall well below the expectations of securities analysts and investors, and the trading price of the Company’s common stock may drop.

Estimating Inaccuracies

There are numerous uncertainties inherent in estimating quantities of proven reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the control of the Company. Reserve engineering is a subjective process of estimating underground accumulations of crude oil, condensate and natural gas liquids that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the amount and quality of data and of engineering and geological interpretation. Estimates by different engineers may vary. Results of drilling, testing and production after the date of an estimate may justify revision of such estimates. Reserve estimates are often different from the quantities ultimately recovered including the continual possibility of failure to find oil or gas and the drilling of a dry hole, and concentrations of oil in unexpected differing amounts on certain holes or targets drilled.

Declining Reserves

Volumes of proposed oil and gas reserves acquired by the Company will decline as reserves are depleted. Reserve volumes generated from future activities of the Company are highly dependent upon the level of success in acquiring or finding additional reserves.

Key Officers Management Services Were Provided By Outside Consulting Firms, And Individuals Contributing Additional Key Officers Management Services, During Fiscal Year Ended December 31, 2008

Individual outside consulting firms owned by key Officers and/or current Directors, Dennis R. Alexander, Chairman, President and CFO, Rupert C. Johnson, Director until June 9, 2008, Dermot McAtamney, Co-Treasurer and Director until June 9, 2008, Larry W. Trapp, Executive Vice President, Co-Treasurer and current Director beginning December 3, 2008, Mike Trapp, current Director beginning December 3, 2008, and Melvena Alexander, Co-Treasurer, Secretary and Comptroller, managed the business of the Company. Accordingly, the loss of the services of any key individual could have an effect on the development of the Company’s business. The Company may hire future employees and additional employees not provided through outside consulting firms, and depend on their services, the loss of which may effect the development of the Company’s business and could adversely affect the conduct of our business. While it intends to do so, the Company has not yet applied for key-man life insurance and the Company has not obtained insurance covering the possibility that any of its key officers and management personnel might become disabled or otherwise unable to render services to the Company. The success of the Company is also dependent upon its ability to attract, contract with and retain highly qualified technical, managerial and marketing personnel. The Company faces competition for such personnel from other companies, many of which have significantly greater resources than the Company. There can be no assurance that the Company will be able to recruit and retain such personnel.

Officers And Directors Beneficially Own And Represent Approximately 41.60 % Of the Company’s Issued and Outstanding Common Stock

The executive officers and directors of the Company currently beneficially own and represent approximately 41.60% of the issued and outstanding Common Stock. Accordingly, such persons may be able to maintain control of the Board of Directors of the Company and direct the affairs of the Company.

Penny Stock As A Risk

Definition And Rule Reference: The Securities and Exchange Commission has adopted Rule 3a51-1 of General Rules and Regulations, Promulgated under the Securities and Exchange Act of 1934, which established the definition of a “penny stock”, for the purposes relevant to the Company, as any equity security that has a market price of less than $5.00 per share, or with an exercise price of less than $5.00 per share, subject to certain exceptions. For any transaction involving a penny stock, unless exempt, the rules require: (i) that broker or dealer approve a person’s account for transactions in penny stocks; and, (ii) the broker or dealer receive from the investor a written agreement to the transaction, setting forth the identity and quantity of the penny stock to be purchased.

Future sales of our Shares of Common Stocks in the public market could lower our share price.

We may sell additional Shares of Common Stock in subsequent offerings. We may also issue additional Shares of Common Stock to finance future acquisitions, including acquisitions larger than those we have done in the past. We cannot predict the size of future issuances of our Shares of Common Stock or the effect, if any, that future issuances and sales of our Shares of Common Stock will have on the market price of our Shares of Common Stock. Sales of substantial amounts of Shares of Common Stock, or the perception that such sales could occur, may adversely affect prevailing market prices for our Shares of Common Stock.

Obligations And Contingencies

The Company is liable for future restoration and abandonment costs associated with its oil and gas properties. These costs include future site restoration and plugging costs of wells. The cost of future abandonment of producing wells has not been determined the date of this report. Management believes that these costs will not have a material adverse effect upon its financial position or results of operations.

Other

The Company’s corporate parent operations during fiscal year ended 2008 did not retain any employees. Individual consulting firms owned by two key officers/directors along with three additional key officers/directors contributing time and effort managed the day-to-day operations of our Company. We have accounting consultants, legal consultants, oil and gas technical team consultants and engineers available for project purposes on a part time basis; one advisor assists us with project evaluations and business development, information and research, technical writing and presentation. The Company will consider full time employees upon sufficient capitalization and cash flow which may include accounting systems and data processing coordinator, oil and gas staff analyst and coordinator, financing officer; assistant to executive officers, and other. Future performance will be substantially dependent on the continued services of management and the ability to retain and motivate them. The loss of the services of any officers or senior managers could affect activities of our business and its operations until additional personnel can be retained and trained to perform some of the management tasks. At the present time the Company does not have long-term employment agreements with any key personnel and does not maintain any life insurance policies.

ITEM 2.

DESCRIPTION OF PROPERTY

Glossary of Oil and Gas Terms.

Barrel: Equal to 42 U.S. gallons.

Basin: A depressed sediment-filled area, roughly circular or elliptical in shape, sometimes very elongated. Regarded as a good area to explore for oil and gas.

British thermal unit, (BTU): A measure of the heating value of a fuel.

Completion: The installation of permanent equipment for the production of oil or gas.

Field: A geographic region situated over one or more subsurface oil and gas reservoirs encompassing at least the outermost boundaries of all oil and gas accumulations known to be within those reservoirs vertically projected to the land surface.

Fracturing: The application of hydraulic pressure to the reservoir formation to create fractures through which oil or gas may move to the wellbore.

Improved Oil Recovery (“IOR”): Effort to improve or enhance oil recovery that does not include secondary or tertiary basic recovery methods. In most oil fields, only a fraction of the oil can be produced by natural reservoir pressure and by conventional methods such as pumping. The remaining, or residual, oil can be recovered only by using recovery methods that restore pressure and fluid flow in underground formations through the introduction of water, gas, chemicals, or heat into the reservoir.

License: Formal or legal permission to explore for oil and gas in a specified area.

Log: Io conduct a survey inside a borehole to gather information about the subsurface formations; the results of such a survey. Logs typically consist of several curves on a long grid that describe properties within the wellbore or surrounding formations that can be interpreted to provide information about the location of oil, gas, and water. Also called well logs, borehole logs, wireline logs.

Mcf: Is a thousand cubic feet of natural gas.

Mineral interest: The ownership of rights to gas, oil, or other minerals as they naturally occur in place, at or below the surface of a tract of land. Ownership of the minerals carries with it the right to make such reasonable use of the surface as may be necessary to explore for and produce the minerals. Only the mineral owner (or fee owner) may execute an oil or gas lease conveying his interest in a tract of land.

Oil: Crude oil or condensate.

Operator: An individual, company, trust, or foundation responsible for the exploration, development, and production of an oil or gas well or lease.

Productive: Able to produce oil and/or gas.

Proved reserves: Estimated quantities of crude oil, condensate, natural gas, and natural gas liquids that geological and engineering data demonstrate with reasonable certainty to be commercially recoverable in the future from known reservoirs under existing conditions using established operating procedures and under current governmental regulations.

Proved undeveloped reserves: Economically recoverable reserves estimated to exist in proved reservoirs, which will be recovered from wells, drilled in the future.

Reserves: The estimated value of oil, gas and/or condensate, which is economically recoverable.

Tons: A ton of oil is equal to 7.29 barrels of oil.

Working interest: The percentage of the operating, drilling, completing and reworking costs that the Company is required to pay. The net revenue interest is the percentage of the revenues that the Company receives from the sale of oil that is produced from the wells.

Working interest on a “Third for Quarter Basis”: The non-operator usually will pay all costs attributable to restoring the well or wells to production and will own 75% of the working interest in the well or wells; The operator receives the remaining 25% working interest as a free carried working interest.

Recompletion: The completion for production of an existing well bore in another formation from that in which the well has been previously completed.

Severance: The owner of all rights to a tract of land (vertically or horizontally). In horizontal severance, for example, if he chooses to sell all or part of the mineral rights, two distinct estates are created: the surface rights to the tract of land and the mineral rights to the same tract. The two estates may change hands independently of each other. Severed mineral rights may be restricted as to mineral type, or limited by depth, in which case the landowner retains the rights to minerals other than those severed, and to depth intervals other than those severed.

Workover: Operations on a producing well to restore or increase production. A workover may be performed to stimulate the well, remove sand or wax from the wellbore, to mechanically repair the well, or for other reasons.

The Company may participate in the drilling of a well or wells if it is able to successfully acquire attractive oil and gas leases with substantially proven undeveloped reserves, a preferred majority or suitable working interest being available, and can obtain or provide financing or market an interest on terms acceptable to the Company.

Oil and Gas Properties, Leases, and Interests

Knox County, Texas

Disposition as of December 2, 2008

In connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., the 100% Working Interests held in the Fant Ranch Unit was disposed of and is no longer owned by the Company.

Ward County, Texas

Disposition as of December 2, 2008

In connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., the 75% Working Interests held in the J.B. Tubb Leasehold Estate was disposed of and is no longer owned by the Company.

Sweetwater County, Wyoming

Sale of TMD

Wells And Acreage

On December 2, 2008, in connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., all oil and gas properties/leasehold interests were foreclosed and no longer owned by the Company.

Set fourth below is information respecting the developed and undeveloped acreage owned by the Company in Knox and Ward Counties, Texas, and Sweetwater County, Wyoming. The Company sold its Wyoming interests included in the table below on October 30, 2008 and on December 2, 2008 all of its Texas interests were disposed of:

	Developed Acreage			Undeveloped Acreage
	Gross		Net	Gross		Net

Sweetwater County, Wyoming, owned through October 30, 2008		320	160		960	360
Knox County, Texas, owned through December 2, 2008		2520	1890		-0-	-0-
Ward County, Texas, owned through December 2, 2008		40	22.5		-0-	-0-

Total		2880	2067.5		960	360

Production And Sale Of Oil And Gas

The following table summarizes certain information relating to the Company's net Natural oil and natural gas produced and from the Company’s property interests held, after royalties, during the periods indicated.

	Year Ended December 31,
		*2008	2007

Average net daily production of oil (Bbl)		30.71		22.56
Average net daily production of gas (Mcf)		129.05		73.79
Average sales price of oil ($ per Bbl)	$	103.74	$	81.73
Average sales price of gas ($ per Mcf)	$	8.00	$	5.02
Average lifting cost per bbl oil equiv.	$	36.96	$	26.52

*Calculations for 2008 Average net daily production of oil and gas (Mcf) was based on partial year start up activity averages for the Tubb leasehold estate beginning February 2008 and ending 12/2/2008; for TMD, from January 1, 2008 through October 30, 2008, the sale date for the Company’s 50% Working Interests in the leases and equipment; for Fant Ranch Unit, from January 1, 2008 through December 2, 2008 the date of final disposition for the Company’s 100% Working Interests in the leases and equipment.

Out Corporate offices are located in Scottsdale, Arizona, and our wholly-owned subsidiary Firecreek Petroleum, maintained an office in Fort Worth, Texas, but moved its operations primarily to Scottsdale, Arizona during second quarter of operations in 2006. Please see also “Certain Relationships and Related Transactions” for further discussion.

The Chief Executive Officer of the Company provided corporate office space through 2007 and 2008 at no charge. There is no further agreement in place to pay for the premises. At December 31, 2008 through March 31, 2009 the premises continue to be provided free of charge. Please see “Certain Relationships and Related Transactions”.

ITEM 3.

LEGAL PROCEEDINGS

None

ITEM 4.

SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

No matters were submitted to a vote of our security holders during the fourth quarter of 2008.

PART II

ITEM 5.

MARKET FOR COMMON EQUITY AND RELATED STOCKHOLDER MATTERS

MARKET PRICE AND DIVIDENDS OF COMPANY

The Company became available for quotation on the over-the-counter, NASDAQ NQB Pink Sheets initially January 20, 2000. As of March 14, 2003, the Company moved to the over-the-counter market, NASDAQ OTC Electronic Bulletin Board quotation medium system, and is presently dually quoted on both Pink Sheets and Bulletin Board. The range of high and low bid information for the shares of the Company’s stock for the last two complete fiscal years, as reported by the OTC Bulletin Board National Quotation Bureau, is set forth below. Such quotations represent prices between dealers, do not include retail markup, markdown or commission, and do not represent actual transactions.

2009	High		Low

First Quarter	$	0.1600	$	0.0300

Year Ended December 31, 2008	High		Low

First Quarter	$	0.0057	$	0.0009
Second Quarter		0.0050		0.0006
Third Quarter		0.0025		0.0005
Fourth Quarter (October 1 through October 7, 2008)		0.0070		0.0050
*Fourth Quarter (October 8 through December 31, 2008)		0.2000		0.0500

*Reflects Prices For the Period After a One for Two Hundred (1:200) Reverse Stock Split Effective October 8, 2008.

Year Ended December 31, 2007	High		Low

First Quarter	$	0.0870	$	0.0061
Second Quarter		0.0760		0.0031
Third Quarter		0.0064		0.0025
Fourth Quarter		0.0031		0.0007

As of March 31, 2009, the Company had issued and outstanding 9,547,207 shares of its common stock held by 611 holders of record, and no shares of Series A, B or C preferred stock, issued and outstanding.

There have been no cash dividends declared by the Company since its inception. Further, there are no restrictions that would limit the Company’s ability to pay dividends on its common equity or that would be likely to do so in the future.

SECURITIES AUTHORIZED FOR ISSUANCE UNDER EQUITY COMPENSATION PLANS.

The following information is provided for the fiscal year ended December 31, 2008, with respect to compensation plans (including individual compensation arrangements) under which equity securities of the issuer are authorized for issuance, aggregated as follows:

(i)	All compensation plans previously approved by security holders; and

(ii)	All compensation plans not previously approved by security holders.

Equity Compensation Plan Information

Plan category	Number of securities to be issued upon exercise of outstanding options, warrants and rights (a)(1a.)	Weighted average exercise price of outstanding options, warrants and rights (see footnotes) (b)(*)(1.a)			Number of securities remaining available for future issuance (c)(1.a)
(i) Equity compensation plans approved by security holders (Form S-8)
2004 Stock Incentive Plan	12,500	$	n/a		-0-
2004 Stock Incentive Plan 2	7,000	$	n/a		-0-
2005 Stock Incentive Plan (1)	13,000	$	8.00	*	6,500

Total for Plans Filed On Form S-8	32,500	$			6,500
Equity compensation plans approved by security holders
Tirion Group, Inc. -Warrant (2)(5)	10,000		n/a (5	)	-0-
DLM Asset Management,-Warrant (2)(7)	16,750	$	12.00		16,750
Tirion Group, Inc.-Warrant (7)	16,750		12.00		16,750
John R Taylor-Option (4)	10,000	$	140.00		10,000
William E. Merritt-Option (4)	10,000	$	140.00		10,000
George B. Faulder-Option (4)	10,000	$	140.00		10,000
Dr. Mousa Hawamdah-Option (4)	10,000	$	140.00		10,000
James Barker-Option (4)	5,000	$	140.00		5,000
Charles Alliban-Option (4)	10,000	$	140.00		10,000
Dennis R. Alexander-Option (4)	10,000	$	140.00		10,000
Gregg Fryett-Option (4)	10,000	$	140.00		10,000
Peter Fryett-Option (4)	10,000	$	140.00		10,000
Equity compensation plans approved by security holders
M. Herzog-Option (3)	3,000	$	n/a		-0-
(Mel Herzog and Charlotte Herzog TTEE UA DTD Jan 31, 1994 Herzog Revocable Living Trust JT Grantors)			n/a		-0-
D. Alexander-Option (3)	3,000	$	n/a		-0-
M. Alexander-Option (3)	2,500	$	n/a		-0-
D. Kronenburg-Option (3)	2,500	$	n/a		-0-
(David J. Kronenberg Assigned to D.J. and S.M. Kronenberg Family LLLP)			n/a
L. Trapp-Option (3)	3,000	$	n/a		-0-
T. Richards-Option (3)	2,500	$	n/a		-0-
Bradley Ray-Option (3)	2,500	$	n/a		-0-
Steven Antebi-Warrant (2)	20,000	$	5.00		-0-
Sapphire Consultants-Warrant (2)(6)	12,500	$	4.00		12,500
Confin International Inv.-Warrant (2)(6)	18,750	$	4.00		18,750
John Brigandi-Warrant (2)	3,125	$	4.00		1,560
Steven Antebi-Warrant (8)	20,000	$	10.00		20,000
Joseph M. Vasquez (9)	2,500	$	4.00		2,500
Joseph M. Vasquez (9)	2,500	$	12.00		2,500
Joseph M. Vasquez (9)	2,500	$	24.00		2,500
Total (1)	229,375	$	71.81	**	178,810

(1a.) Information listed under column (a), (b) and (c) reflects adjustment for 1:200 post reverse split (one (1) share for two hundred (200)) share basis which was effective at October 8, 2008.

(*) Information listed for column (b) in the table above represents the exercise or strike price for each option or warrant, excluding those noted (1) and (5). The calculation for Column (b) note (1) is the estimated average of the closing bid prices on the effective date of issuances under the plan prior to February 9, 2005.

(**) The final Total listed for column (b) in the table above represents the weighted average exercise price for all 2005 options and warrants listed and noted (2), through (9) in the table only (please see additional information listed in this Report, under Item 9. “Issuance of Warrants” located in the “Notes to the Consolidated Financial Statements For the Years Ended December 31, 2007 and December 31, 2006”).

(1) The balance of shares available under the 2005 Stock Incentive Plan registered on Form S-8 are not available for further issuance after February 9, 2005 unless authorized, pursuant to terms of various agreements with our lenders during the year ended December 31, 2007, December 31, 2006, and December 31, 2005, and information has been excluded from the final total calculations listed above for columns (a), (b), and (c) accordingly.

(2) The Company provided warrants to a lender and various consultants during 2005. For further information regarding terms of these warrants to purchase underlying shares of the Company’s common stock issued, please see our Registration Statement on Form SB-2, as amended, and incorporated herein by reference.

(3) Represents historical options issued by the Company. For further information regarding terms for these options, please see information furnished in our Form 10-KSB, Amendment No. 3, filed on October 4, 2002, and incorporated herein by reference. As of November 30, 2007 these options have expired.

(4) Represents options issued by the Company as part of the Firecreek Petroleum, Inc. acquisition which vested, becoming available for exercise February 9, 2005. For terms of these options, please see information furnished in a Current Report on Form 8-K/A (Amendment No. 2), filed on September 16, 2004, and incorporated herein by reference.

(5) The strike price for the Tirion Warrant is 80% of the average of the then lowest three closing bids for the previous 30 days from the date the warrants are exercised. For further information regarding terms of the Warrant please see our Registration Statement on Form SB-2, as amended, and incorporated herein by reference. As of May 19, 2007 these options have expired.

(6) On March 14, 2006 the Company notified the holders of the Warrants that they must exercise their Warrants for cash or the Warrants will be cancelled without further notice, 30 days following such notice thereof.

(7) Represents an assignment of 3,350,000 shares underlying Warrants held by DLM Asset Management, Inc. to Tirion Group, Inc. on February 14, 2006.

(8) Represents options issued by the Company in behalf of an extension and amendment of a Corporate Advisory Agreement with Steven Antebi, dated January 30, 2006. For further information regarding the terms of the extension and amendment of a Corporate Advisory Agreement, and corresponding option agreement please see a Current Report on Form 8-K/A, filed on February 3, 2006, incorporated herein by reference.

(9) Represents options issued by the Company on behalf of an Advisory Service Agreement with Joseph M. Vasquez dated March 1, 2006. For further information regarding the terms of the option agreements please see an amended Current Report on Form 8-K/A, filed on March 17, 2006, incorporated herein by reference.

RECENT SALES OF UNREGISTERED SECURITIES

I. On February 8, 2009, by majority consent of the Board of Directors, the Company approved the following issuances of its restricted common stock, par value $0.001 per share, to the following persons for services rendered.

Name	Date	Share Amount(***)		Type of Consideration	Fair Market Value of Consideration
Jeffrey M. Proper c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09		250,000	For services rendered to the Company or FPI	$	15,000

Thomas J. Richards c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09		390,000	For services rendered to the Company or FPI	$	23,400

Larry W. Trapp c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09		300,000	For services rendered to the Company or FPI	$	18,000

Melvena Alexander c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09		180,000	For services rendered to the Company or FPI	$	10,800

Joanne M. Sylvanus c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09		275,000	For services rendered to the Company or FPI	$	16,500

Clifton Onolfo c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09		150,000	For services rendered to the Company or FPI	$	9,000

(*) Issuances are approved, subject to such persons being entirely responsible for their own personal, Federal, State, and or relevant single or multi jurisdictional income taxes, as applicable.

(**) $92,700 of the financing proceeds in the immediately preceding table was used primarily in consideration of services rendered to the Company and/or Firecreek Petroleum, Inc. (“FPI”).

(1)	Mr. Jeffrey M. Proper, Esq., for legal advisory and consulting services; Mr. Proper is a shareholder.

(2)	Mr. Thomas J. Richards, for business and consulting and advisory services; Mr. Richards is a shareholder and an advisor of the Company.

(3)	Mr. Larry W. Trapp, for business and consulting and advisory services; He is a shareholder, an officer, (Executive Vice President, and Co-Treasurer) and director of the Company and Firecreek Petroleum, Inc.

(4)	Melvena Alexander, for day to day operational services and business provisions; Mrs. Alexander is a shareholder, and an officer (Secretary, Comptroller, and Co Treasurer) of the Company.

(5)	Joanne M. Sylvanus provides accounting and advisory services to the Company and FPI, and is a shareholder of the Company.

(6)

Mr. Cliff Onolfo, Miami Florida, for business and financial advisory services; He is a shareholder and advisor of the Company. The shares are to be held at the Company offices to be released as additional financial success fee compensation. The shares to be returned to Company Treasury if there is no performance completed within 90 days of the date of this Resolution.

(***) The shares of common stock were issued pursuant to an exemption from registration as provided by Section 4(2) of the Securities Act of 1933, as amended (the “1933 Act”). All such certificates representing the shares issued by the Company shall bear the standard 1933 Act restrictive legend restricting resale.

II. On February 5, 2009, by majority consent of the Board of Directors, the Company approved the following issuances of its restricted common stock, par value $0.001 per share, to the following persons for services rendered.

Name	Date	Share Amount(***)		Type of Consideration	Fair Market Value of Consideration
Joseph M. Vazquez III 5324 Pine Tree Drive Miami Beach, FL. 33140	2/5/09		340,000	For services rendered	$	20,400

David M. Rees 175 E. 400 South, Suite 2000 Salt Lake City, Utah 84111	2/5/09		300,000	For services rendered	$	18,000

Callie Tempest Jones 175 E. 400 South, Suite 2000 Salt Lake City, Utah 84111	2/5/09		25,000	For services rendered	$	1,500

Chase Chandler 175 E. 400 South, Suite 2000 Salt Lake City, Utah 84111	2/5/09		15,000	For services rendered	$	900

(*) Issuances are approved, subject to such persons being entirely responsible for their own personal, Federal, State, and or relevant single or multi jurisdictional income taxes, as applicable.

(**) $40,800 of the financing proceeds in the immediately preceding table was used primarily in consideration of services rendered to the Company and/or Firecreek Petroleum, Inc. (“FPI”).

(1)	(****) Mr. Joseph M. Vazquez for legal advisory and consulting services, and is a shareholder of the Company.

(2)	Mr. David M. Rees for legal engagement and advisory services with the firm Vincent & Rees. Mr. Rees is a shareholder of the Company.

(3)	Mrs. Callie Tempest Jones for legal engagement and advisory services with the firm Vincent & Rees, Mrs. Jones is a shareholder of the company.

(4)	Mr. Chase Chandler for legal engagement and advisory services with the firm Vincent & Rees. Mr. Chandler is a shareholder of the Company.

(****) See also Item 8B Other Information which can be found further listed in this Report.

On March 27 and December 26 of 2007, the Company issued to Dutchess two convertible debentures one with a face value of $140,000 and the other with a face amount $500,000, to pay an incentive fee to the holder of the equity credit line. The debentures became convertible at the date of the issuances and mature in March 27, 2012 and December 26, 2014, respectively. The Company claims an exemption from the registration requirements of the Securities Act of 1933, as amended (the “Act”) for the private placement of these securities pursuant to Section 4(2) of the Act and/or Rule 506 of Regulation D promulgated thereunder since, among other things, the transaction does not involve a public offering, the Investor is an “accredited investor” and/or qualified institutional buyer, the Investor has access to information about the Company and its investment, the Investor will take the securities for investment and not resale, and the Company is taking appropriate measures to restrict the transfer of the securities. For terms of the debentures please see information furnished in our Current Reports and Exhibits thereto on Form 8-K filed on March 29, 2007 and January 7, 2008, respectively, incorporated herein by reference.

On June 11, 2007 the Company issued to Dutchess a debenture in the face amount of $2,000,000 for acquisitions and working capital. The Debenture bears interest at 12% per annum and matures on June 11, 2014. For terms of the debenture please see information furnished in our Current Report on Form 8-K, and Exhibits thereto filed on Jun 11, 2007, incorporated herein by reference.

On December 26, 2007, EGPI Firecreek, Inc. the Company issued to Dutchess a debenture in the face amount of $2,100,000. The Debenture bears interest at 12% per annum and matures on December 26, 2014. The Company claims an exemption from the registration requirements of the Act for the private placement of these securities pursuant to Section 4(2) of the Act and/or Rule 506 of Regulation D promulgated thereunder since, among other things, the transaction does not involve a public offering, the Investor is an “accredited investor” and/or qualified institutional buyer, the Investor has access to information about the Company and its investment, the Investor will take the securities for investment and not resale, and the Company is taking appropriate measures to restrict the transfer of the securities. For terms of the debenture please see information furnished in our Current Report on Form 8-K, and Exhibits thereto filed on January 7, 2008, incorporated herein by reference.

On April 21 and June 29 of 2006, the Company issued to Dutchess convertible debentures with a face value of $171,875 and $300,000 respectively, to pay an incentive fee to the holder of the equity credit line. The debentures became convertible at the date of the issuances and mature in April and June of 2011. The Company claims an exemption from the registration requirements of the Act for the private placement of these securities pursuant to Section 4(2) of the Act and/or Rule 506 of Regulation D promulgated thereunder since, among other things, the transaction does not involve a public offering, the Investor is an “accredited investor” and/or qualified institutional buyer, the Investor has access to information about the Company and its investment, the Investor will take the securities for investment and not resale, and the Company is taking appropriate measures to restrict the transfer of the securities. For terms of the debentures please see information furnished in Exhibit “A” to each of Exhibits 99.1 and 99.2 to our Current Reports on Form 8-K filed on April 27, 2006 and June 7, 2006, respectively, incorporated herein by reference.

On November 14 and December 15 of 2005, the Company issued to Dutchess convertible debentures with a face value of $375,000 and $82,500, respectively, to pay an incentive fee to the holder of the equity credit line. The debentures became convertible at the date of the issuances and mature in November and December 2010. The Company claims an exemption from the registration requirements of the Act for the private placement of these securities pursuant to Section 4(2) of the Act and/or Rule 506 of Regulation D promulgated thereunder since, among other things, the transaction does not involve a public offering, the Investor is an “accredited investor” and/or qualified institutional buyer, the Investor has access to information about the Company and its investment, the Investor will take the securities for investment and not resale, and the Company is taking appropriate measures to restrict the transfer of the securities. For terms of the debentures please see information furnished in Exhibit “A” to each of Exhibits 10.3, and 99.1 to our Current Reports on Form 8-K filed on November and December 16, 2005, respectively, incorporated herein by reference.

ITEM 6.

SELECTED FINANCIAL DATA

Not Applicable

ITEM 7.

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

Summary Results Of Operations

Overview

You should read the following discussion and analysis in conjunction with the audited Consolidated Financial Statements and Notes thereto, and the other financial data appearing elsewhere in this Annual Report.

The information set forth in Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) contains certain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995, including, among others (i) expected changes in the Company’s revenues and profitability, (ii) prospective business opportunities and (iii) the Company’s strategy for financing its business. Forward-looking statements are statements other than historical information or statements of current condition. Some forward-looking statements may be identified by use of terms such as “believes”, “anticipates”, “intends” or “expects”. These forward-looking statements relate to the plans, objectives and expectations of the Company for future operations. Although the Company believes that its expectations with respect to the forward-looking statements are based upon reasonable assumptions within the bounds of its knowledge of its business and operations, in light of the risks and uncertainties inherent in all future projections, the inclusion of forward-looking statements in this report should not be regarded as a representation by the Company or any other person that the objectives or plans of the Company will be achieved. In light of these risks and uncertainties, there can be no assurance that actual results, performance or achievements of the Company will not differ materially from any future results, performance or achievements expressed or implied by such forward-looking statements. The foregoing review of important factors should not be construed as exhaustive. The Company undertakes no obligation to release publicly the results of any future revisions it may make to forward-looking statements to reflect events or circumstances after the date hereof or to reflect the occurrence of unanticipated events.

The Company has been focused on oil and gas activities for development of interests held that were acquired in Texas and Wyoming for the production of oil and natural gas through December 2, 2008. The Company throughout 2008 was seeking to continue expansion and growth for oil and gas development in its core projects. A downturn in economic circumstances leading to a default notice received from our hedge fund lenders which in combination with lack of timely credit availability resulted in forced disposition of our assets. In 2009 we are once again pursuing a re-build of our basic projects infrastructure, negotiating for new acquisitions. Through 2008 we continued to limit and wind down the pursuit of projects overseas in Central Asian and European countries, but reserve the right to re enter these activities at a future date.

The Company has been making presentations to asset-based lenders and other financial institutions for the purpose of expanding and supporting our growth potential by development of new oil and gas operations in 2009 with a goal to re build our revenue base and cash flow; however, the Company makes no guarantees and can provide no assurances that it will be successful in these endeavors.

One of the ways our plans for growth could be altered if current opportunities now available become unavailable:

The Company would need to identify, locate, or address replacing current potential acquisitions or strategic alliances with new prospects or initiate other existing available projects that may have been planned for later stages of growth and the Company may therefore not be ready to activate. This process can place a strain on the Company. New acquisitions, business opportunities, and alliances, take time for review, analysis, inspections and negotiations. The time taken in the review activities, is an unknown factor, including the business structuring of the project and related specific due diligence factors.

General

The Company historically derived its revenues primarily from retail sales of oil and gas field inventory equipment, service, and supply items primarily in the southern Arkansas area, and from acquired interests owned in revenue producing oil wells, leases, and equipment located in Olney, Young County, Texas. The Company disposed of these two segments of operations in 2003. The Company acquired a marine vessel sales brokerage and charter business, International Yacht Sales Group, Ltd. of Great Britain in December 2003 later disposing of its operations in late 2005. We accounted for the segments as discontinued operations in the consolidated statements of operations for the related fiscal year.

Effective July 1, 2004, we acquired Firecreek Petroleum, Inc., and its subsidiary Firecreek Romania, SRL. Firecreek was focused on exploration and development specializing in the niche market of rehabilitation and enhancement of existing oilfields through modern management and state of the art technological applications internationally. Throughout 2004 and 2005, the Firecreek unit developed relationships, pursued and prepared for potential acquisitions in Romania and Libya, and through its strategic alliances developed other potential projects for acquisition located in Russia, Romania, Kazakhstan, Ukraine, and Turkey. Firecreek’s business was subsequently restructured in the first quarter of 2006. This process undertook closing our Firecreek subsidiary Ft. Worth Texas offices, eliminating or lowering many expenses including employees, consultants, telephones, long distance, cellular fees, travel, office supplies, data fees, and other. Books, accounting records and data were transferred to the Parent offices located in Scottsdale Arizona. The restructuring helped to decrease overall operating losses for the year 2006, and also to a lesser extent conserved existing cash flows. In 2007 and 2008 Firecreek focused primarily on development of U.S. based domestic oil and gas operations, the Fant Ranch Unit (acquired effective July 1, 2007), and Tubb Leasehold estate (acquired effective January 1, 2008) which were located in Knox and Ward Counties, Texas, respectively, and the Ten Mile Draw (TMD) project located in Sweetwater County Wyoming,.

Effective November 15, 2005, Firecreek purchased a 50% undivided working interest in leases, wells, equipment, gas and to a lesser extent oil reserves, and other rights, located in Green River Basin, Sweetwater County, Wyoming. The project is listed under the prospect name “Ten Mile Draw” (“TMD”). Through our operator Newport Oil Corporation (“Newport” or “NOC”) having completed a successful workover program we commenced with gas production from two wells, the 16-1 and 7-16, in the first and second quarters of 2006, subsequently began a workover program for a third well, the 13-9, in July of 2006. The Company encountered and reported several technical issues with the 13-9 well, and in bringing the well online to satisfactory commercial production levels. During the second quarter of operations the Company reported that it may ultimately elect to shut the well if reasonable commercial production levels were not achieved in a reasonable amount of time. Due not achieving commercial levels of production, during September and October 2008 the Company and NOC elected to shut in the 13-9, and the Company thereafter elected to sell all of its remaining interests and rights held in the TMD to NOC (for further information please see our Current Report on Form 8-K filed October 31, 2008, incorporated herein by reference).

Effective July 1, 2007, Firecreek purchased a 100% working interest and related 75% net revenue interest in leases, wells, equipment, and oil reserves located in Knox County, Texas. The project is listed as the Fant Ranch Unit. Through our operator Success Oil Co. Inc., we took over operations, commenced with oil production in the third and fourth quarter of 2007, and implemented a phase one program to rehabilitate and bring two additional wells on line in the Fant Unit. For additional information related to acquisition of Fant Ranch Unit please see our Report on Form 8-K filed on July 16, 2007 incorporated herein by reference. In January, 2008, Firecreek commenced with an enhancement/rehabilitation phase 2 program for the Fant Ranch Unit located in Knox County, Texas. The program included cleaning out casing perforations, maintenance, paraffin removal, repair and acid stimulation for a majority of the oil wells in the unit. The purpose of the program was to maintain the existing wells regularly, and to increase the overall well efficiency and production for the field. Disposition as of December 2, 2008: In connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., the 100% Working Interests held in the Fant Ranch Unit was disposed of as of December 2, 2008, and is no longer owned by the Company.

On August 3, 2007, the Company through its Firecreek unit concluded a transaction for the sale of rights and opportunities for development works and projects located in the Ukraine. Through the agreement the purchaser acquired the rights to acquire licenses, permits and permissions to explore for and extract oil, natural gas or other natural resources on the territories referenced in the agreement. For additional information please see information and exhibits to a Report on Form 8-K filed on August 13, 2007, incorporated herein by reference. For updated status please also see Item 1, Legal Proceedings in a report on Form 10-Q, filed on November 21, 2008, incorporated herein by reference.

In January, 2008, Firecreek entered into an Assignment and Bill of Sale (the “Assignment”) with Success Oil Co., Inc. (“SOC”) relating to the purchase and sale of 75% working interests along with 56.25% corresponding net revenue in certain 40 acre tract of land and leases (the “North 40”), with and including a first right for an additional 40 acre lease (the “South 40”), located in Ward County, Texas, more commonly known as the J.B. Tubb leasehold estate (the “Tubb Lease”). The Company participated in a workover, drilling and development program, and has recently brought three wells online as a result. The Company paid $1,400,000 for the lease, equipment and a Participation Agreement which provided for turnkey drilling, re-entry, and included multiple wells on the North 40 Acres. Firecreek has subsequently acquired assignment of one Lower Clearfork formation in the Highland 2 Wellbore which is located on the South 40 of the J.B. Tubb Leasehold Estate (also see information contained in Current Report on Form 8-K/A filed on April 30, 2008). The Tubb Lease workover, drilling and development programs brought three wells online resulting in two of the three wells effectively producing and selling oil and gas. For further information please see our Current Report on Form 8-K, as amended, originally filed on January 9, 2008, and amended and filed on April 30, 2008, incorporated herein by reference. Disposition as of December 2, 2008: In connection with the Default notice received October 24, 2008, and actions of Dutchess Private Equities Fund, Ltd., the 75% Working Interests held in the J.B. Tubb Leasehold Estate was disposed of as of December 2, 2008, and is no longer owned by the Company.

The Company expects to incur an increase in operating expenses during the next year from commencing activities related to its plans for the Company’s oil and gas operations. The amount of net losses and the time required for the Company to reach and maintain profitability are uncertain at this time. There is a likelihood that the Company will encounter difficulties and delays encountered with business subsidiary operations, including, but not limited to uncertainty as to development and the time and timing required for the Company’s plans to be fully implemented, governmental regulatory responses to the Company’s plans, fluctuating markets and corresponding spikes, or dips in our products demand, currency exchange rates between countries, acquisition and development pricing, related costs, expenses, offsets, increases, and adjustments. There can be no assurance that the Company will ever generate significant revenues or achieve profitability at all or on any substantial basis.

RESULTS OF OPERATIONS – December 31, 2008 Compared to December 31, 2007

General administrative expenses were $558,579 in 2008 compared to $1,008,982 in 2007. The Company has treated the following oil and gas leases, properties and interests, and equipment as a discontinued component of operations: i) the undivided 50% Working Interests held in the Ten Mile Draw Prospect area natural gas wells located in Sweetwater County, Wyoming, ii), the 100% oil and gas Working Interests held in the leases, reserves, and equipment in the Fant Ranch Unit located in Knox County, Benjamin Texas, and iii) the 75% oil and gas Working Interests held in the leases, reserves, and equipment located in the J.B. Tubb leasehold estate located in the AMOCO CRAWAR Field, Ward County, Texas.

Following is a breakdown of general and administrative costs for this period versus a year ago:

Detail of general & administrative expenses:

	31-Dec-08		31-Dec-07

Advertising & promotion	$	1,639	$	3,159
Administration		41,627		32,482
Consulting		56,399		327,255
Impairment expense		47,565		0
Investor incentives/commissions		42,376		289,439
Professional fees		300,952		266,647
Salaries		63,000		90,000
Travel costs		5,021		0

Total	$	558,579	$	1,008,982

Advertising and Promotion costs of $1,639 were used for investor relations and market awareness.

Administration Costs of $41,627 was used for office and general operating expenses of which $26,362 was used for the costs related to the reverse stock split.

Consulting Fees of $56,399 were incurred for consulting and advisory fees for business management activities.

Impairment expense of $47,565 was used to expense an acquired oil and gas participation rights.

Investor Incentives/commissions of $42,376 include costs related to obtaining financing and credit lines.

Professional Fees of $300,952 were incurred in regards to legal costs, audit costs, securing financing, and the acquisition of leads and contacts with regard to possible new business ventures and includes data acquisition costs, technical work, and engineering reports.

Salaries and Benefits of $63,000 were used to pay employees in 2008.

Travel costs used $5,021 for business trips, two to Boston MA, and one to Dallas, Fort Worth Texas during 2008.

After deducting general and administrative expense, and interest expenses, the Company experienced a loss from continuing operations of $578,717 in 2008 as compared to a loss from continuing operations of $359,182 in fiscal 2007.

Interest expense for fiscal year 2008 was $24,328 compared to $26,546 in fiscal year 2007.

After accounting for Loss from operations of discontinued component (net of tax), and Gain on disposal of discontinued component (net of tax), the Company incurred a net income of $3,264,439 in fiscal year 2008 compared to a loss of $1,474,050, in fiscal year 2007.

Fully diluted income (loss) per share was $0.54 income per share in fiscal year 2008 compared to a loss of ($0.68) per share in fiscal 2007.

LIQUIDITY AND CAPITAL RESOURCES

Cash on hand at December 31, 2008 was $2,230 compared to $2,009,734 at the beginning of the year. The Company had working capital deficit of $594,702 at December 31, 2008 compared to a working capital deficit of $3,467,364 at December 31, 2007.

Cash used in operating activities was $282,504 for the year ended December 31, 2008, compared with $784,190 for the year ended December 31, 2007.

The Company paid $1,400,000 for J.B. Tubb leasehold interests and equipment, and $1,626,031in fiscal year 2007 of leases and equipment related to the acquisition of the Fant Ranch Unit. The Company received no new loans in fiscal year 2008 compared to $4,405,000 in fiscal year 2007 by issuing convertible debentures and promissory notes on its equity credit line.

The Company paid $325,000 to Dutchess during 2008 to pay down the Equity Line Loan.

Total assets decreased to $2,230 at December 31, 2008 compared to $4,833,885 at the beginning of the year mainly as a result of the loss of assets in default on debt.

Shareholders deficit decreased to $901,798 at December 31, 2008 from a deficit of $3,784,037 at December 31, 2007. During fiscal year 2007, the Company issued 50,714 shares to consultants valued at $58,786 for services rendered. In addition, the Company issued 393,737 shares to pay the equity line of $260,378. During fiscal year 2007, the Company issued convertible debentures with a face amount of $4,100,000 and 3,500,000 shares of common stock and 20,000,000 of preferred stock and received net proceeds of $3,970,000. The issuances of the common stock and the preferred stock were valued at fair market of $700,000 and $200,000 respectively. The fair value associated with the issuance of the debentures using the Black Sholes Options pricing model was $1,853,360.

Finally, we recorded a net income during 2008 of $3,264,439 compared with a net loss during 2007 of $1,474,050, and which results in an ending shareholder deficit at December 31, 2008 of $901,798, reduced from $3,784,037 at December 31, 2007 the previous year.

The Company must generally undertake certain ongoing expenditures in connection re building, expanding and developing its oil and gas business, and for various past and present legal, accounting, consulting, and technical review, and to perform due diligence for activating one or more of its acquisition and development programs; furthering research for new and ongoing business prospects, and in pursuing capital financing for its existing available rights and proposed operations.

As previously reported, during 2007, the equity line financing company that provided the Equity Line cancelled the Equity Line. As part of additional financing on December 26, 2007 for $2.1 million dollars, the terms of that loan included the issuance of two debentures, 40% of the revenues generated by the Company which is applied to previously existing notes, and 85% of the stock of the Company as an inducement (for further information please see Current Report on form 8-K filed on January 7, 2008, incorporated herein by reference). In addition, certain members of the financing Company became members of the Company’s Board of Directors. It was further reported that although unlikely, there could be no assurance that the finance company issuing the notes would continue to refrain from noticing or acting on a formal default, however the Company believed that its present members were working uniformly to assist growth of the Company. Thus a change from a favorable circumstance with our finance company, encountering a formal default, could, in lieu of positive negotiations occurring, anticipate potentially detrimental conditions including but not limited to one or more of the following: i) rapid conversion of debentures to shares of the Company’s up to 85% of the common stock in accordance with the terms and provisions of the note agreements, ii) acceleration and foreclosure on one or all of the assets of the Company and its subsidiaries, iii) imposing financial duress creating difficulty or inability to run the Company or its business affairs, iv) create pressure on the Company’s stock by increased supply, and v) increased dilution to shareholders. Although the terms of the notes were stringent, the Company believed that it would continue to secure needed financing for its growth plans.

In January 2008, members of the financing company joined the Company’s Board of Directors, as a condition of the financing received in December 2007. The Equity Line was canceled with the financing that occurred on December 26, 2007. The Company was working to secure up to $10,000,000 or more in asset based, and or other debt or equity finance projected to assist its 2008 plans. There could be no guarantee or assurance that the Company would receive or be successful in obtaining additional financing. In addition, the Company had a covenant with its equity line finance company, which managing members were directors, affiliates, and shareholders of the Company, not to enter into any additional financing agreements, debt or equity, without prior expressed written consent, which shall not be unreasonably withheld.

Historically noted, as previously disclosed in EGPI Firecreek, Inc.’s (“EGPI” or the “Company”) filings with the U.S. Securities and Exchange Commission, the Company has entered into, and issued, various debenture and note agreements (the “Loan Documents”) with Dutchess Private Equities Fund Ltd, (“Dutchess”), successor in interest to Dutchess Private Equities Fund LP and Dutchess Private Equities Fund II, LP. The Company and Dutchess have also entered into that certain Security Agreement, dated March 27, 2007, as amended, providing for, among other things, Dutchess’ rights and remedies with respect to certain of the Company’s assets. On October 24, 2008, the Company then did receive a default notice (“Default Notice”) pursuant to the Loan Documents previously disclosed stating that the Company was in default of their obligations to Dutchess, including, but not limited to, failure to pay interest and principal when due. Further, pursuant to the Default Notice, Dutchess gave notice that it is exercising its right to increase the aggregate face amount of the obligations owing under the Loan Documents by ten percent (10%) for each instance of default. Accordingly, Dutchess accelerated and declared outstanding all unpaid principal, accrued interest, liquidated damages, and any other costs and expenses to be immediately due and payable in full. The aggregate amount owed to Dutchess, as provided in the Default Notice, is $9,304,962; such amount is to be paid within five (5) days of the Default Notice. Moreover, as stated in the Default Notice, Dutchess reserved the right to pursue any and all available legal remedies for any failure to pay any amount due to Dutchess. On December 2, 2008 as a result of a default notice received October 24, 3008 on Promissory Notes and Debentures, all of the assets were transferred or foreclosed on and transferred to Dutchess Private Equities Fund, Ltd (“Dutchess”).

In summary, the Company obtained $435,000 in March 2007, $2,000,000 in June 2007, and $2,100,000 in December 2007 from Promissory Notes and Debentures as previously reported. There were no funds obtained from financing activities in 2008. Cash provided for operations was provided primarily from its oil and gas operations through December 2, 2008. Going forward for 2009, management has estimated that such cost for initially paying down certain of the Company’s recent debt, providing necessary working capital, and activating development of its current plans for domestic oil and gas segment operations, will initially require a very minimum of $500,000 to $750,000 to a maximum of $5 to $10 million during the first six to twelve months of fiscal 2009.

Financing our full expansion and development plans for our oil and gas operations could require up to $50,000,000 or more. The Company may elect to reduce or increase its requirement as circumstances dictate. We may elect to revise these plans and requirements for funds depending on factors including; changes in acquisition and development estimates; interim corporate and project finance requirements; unexpected timing of markets as to cyclical aspects as a whole; currency and exchange rates; project availability with respect to interest and timing factors indicated from parties representing potential sources of capital; structure and status of our strategic alliances, potential joint venture partners, and or our targeted acquisitions and or interests.

The Company cannot predict that it will be successful in obtaining funding for its plans or that it will achieve profitability in fiscal 2009.

ITEM 8.

FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

EGPI FIRECREEK, INC.

(formerly Energy Producers, Inc.)

CONSOLIDATED

FINANCIAL STATEMENTS

DECEMBER 31, 2006 AND DECEMBER 31, 2005

Index to Financial Statements

Independent Auditor’s Report			F-2

Consolidated Balance Sheets			F-3

Consolidated Statement of Operations			F-4

Consolidated Statement of Cash Flows			F-5

Consolidated Statement of Changes in Shareholders Deficit			F-6

Notes to the Consolidated Financial Statements			F-7 – F-16

F-1

DONAHUE ASSOCIATES, LLC

Certified Public Accountants

27 Beach Road Suite CO5A

Monmouth Beach, NJ 07750

Tel. 732-229-7723

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of EGPI Firecreek, Inc.

We have completed the audits of the consolidated financial statements of EGPI Firecreek, Inc. (the “Company”) and its internal control over financial reporting as of December 31, 2008 and December 31, 2007 in accordance with the standards of the Public Company Accounting Oversight Board (United States).

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

In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of EGPI Firecreek, Inc. (the “Company”) at December 31, 2008 and December 31, 2007, and the results of its operations, cash flows, and changes in shareholders’ equity for the years then ended in conformity with accounting principles generally accepted in the United States of America. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has suffered recurring losses and negative cash flows from operations that raise substantial doubt about its ability to continue as a going concern. Management’s plans in regard to these matters are also discussed in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty

By:
	Donahue Associates, LLC.
	Monmouth Beach, New Jersey
	April 14, 2009

F-2

EGPI Firecreek, Inc.

Consolidated Balance Sheets

As of December 31, 2008 and December 31, 2007

	31-Dec-08			31-Dec-07
ASSETS

Current assets:
Cash	$	2,230		$	2,009,734
Accounts receivable		0			76,348
Deferred charges		0			13,739
Total current assets	$	2,230		$	2,099,821

Other assets:
Investment in Star Energy, fair value		0			382,200
Deferred charges		0			116,934
Fixed assets- net		0			2,234,930

Total assets	$	2,230		$	4,833,885

LIABILITIES AND SHAREHOLDERS' DEFICIT

Current liabilities:
Accounts payable & accrued expenses	$	549,367		$	815,836
Note payable		47,565			0
Notes payable- net of discount		0			4,753,349
Total current liabilities	$	596,932		$	5,569,185

Advances & notes payable to shareholders		307,096			269,200
Convertible debentures- net of discount		0			632,563
Derivative liability		0			2,146,974
Total liabilities	$	904,028		$	8,617,922

Shareholders' deficit:
Series A preferred stock, 20 million authorized, par value $0.001,one share convertible to one common share, no stated dividend, none outstanding	$	0		$	0
Series B preferred stock, 20 million authorized, par value $0.001,one share convertible to one common share, no stated dividend, none outstanding		0			0
Series C preferred stock, 20 million authorized, stated value $.001,one share convertible to ten common shares, no stated dividend. 20 million shares outstanding		0			200,000
Common stock- $0.20 par value, authorized 1,300,000,000 shares, issued and outstanding, 5,921,288 at December 31, 2007 and 6,921,288 at December 31, 2008	$	1,384,257		$	1,184,257
Additional paid in capital		20,970,812			20,970,812
Other comprehensive loss		(567,000	)		(184,800	)
Accumulated deficit		(22,689,867	)		(25,954,306	)
Total shareholders' deficit		(901,798	)		(3,784,037	)

Total Liabilities & Shareholders' Deficit	$	2,230		$	4,833,885

See the notes to the consolidated financial statements.

F-3

EGPI Firecreek, Inc.

Consolidated Statements of Operations

For the Years Ended December 31, 2008 and December 31, 2007

	31-Dec-08			31-Dec-07

General and administrative expenses:
General administration	$	558,579		$	1,008,982
Total general & administrative expenses		558,579			1,008,982

Net loss from operations	$	(558,579	)	$	(1,008,982	)

Other revenues and expenses:
Gain on asset disposal		0			667,000
Interest income		4,190			9,346
Interest expense		(24,328	)		(26,546	)

Net income (loss) before provision for income taxes	$	(578,717	)	$	(359,182	)

Provision for income taxes		0			0

Loss from continuing operations		(578,717	)	$	(359,182	)

Discontinued operations:
Loss from operations of discontinued component (net of tax)		(1,960,323	)		(1,114,868	)
Gain on disposal of discontinued component (net of tax)		5,803,479			0

Net income (loss)	$	3,264,439		$	(1,474,050	)

Basic & fully diluted net income (loss) per common share:
Basic income (loss) per share- continuing operations	$	(0.10	)	$	(0.17	)
Basic income (loss) per share- discontinued component	$	0.64		$	(0.51	)
Basic income (loss) per share	$	0.54		$	(0.68	)

Fully diluted income (loss) per share- continuing operations	$	(0.10	)	$	(0.17	)
Fully diluted income (loss) per share- discontinued component	$	0.64		$	(0.51	)
Fully diluted income (loss) per share	$	0.54		$	(0.68	)

Weighted average of common shares outstanding:
Basic		6,088,411			2,158,841
Fully diluted		6,088,411			2,158,841

See the notes to the consolidated financial statements.

F-4

EGPI Firecreek, Inc.

Consolidated Statements of Cash Flows

For the Years Ended December 31, 2008 and December 31, 2007

		31-Dec-08			31-Dec-07
Operating Activities:
Net income (loss)		$	3,264,439		$	(1,474,050	)
Adjustments to reconcile net loss items not requiring the use of cash:
Impairment expense			47,565			135,786
Interest expense			24,328			26,546
Consulting expense			0			58,786
Gain (loss) on asset disposal			0			(567,000	)
Depreciation & depletion expense	Discontinued component		150,498			124,184
Interest expense	Discontinued component		2,503,277			1,134,606
Amortization of deferred charges	Discontinued component		36,376			188,517
Gain (loss) on asset disposal	Discontinued component		(5,690,284	)		0
Gain on derivative liability	Discontinued component		(428,582	)		(361,964	)
Changes in other operating assets and liabilities :
Accounts receivable	Discontinued component		76,348			(76,338	)
Accounts payable and accrued expenses			(266,469	)		26,737
Net cash used by operations		$	(282,504	)	$	(784,190	)

Investing activities:
Purchase of lease & equipment	Discontinued component	$	(1,400,000	)	$	(1,626,031	)
Net cash used for investing activities			(1,400,000	)		(1,626,031	)

Financing Activities:
Credit equity line paid	Discontinued component	$	(325,000	)	$	435,000
Convertible debentures issued	Discontinued component		0			3,970,000
Net cash provided (used) by financing activities			(325,000	)		4,405,000

Net increase (decrease) in cash during the period		$	(2,007,504	)	$	1,994,779

Cash balance at January 1st			2,009,734			14,955

Cash balance at December 31st		$	2,230		$	2,009,734

Supplemental disclosures of cash flow information:
Interest paid during the year- discontinued component		$	82,624		$	105,000
Income taxes paid during the year		$	0		$	0

See the notes to the consolidated financial statements.

F-5

EGPI Firecreek, Inc.

Consolidated Statement of Changes in Shareholders’ Deficit

For the Years Ended December 31, 2008 and December 31, 2007

																Other
	Preferred			Preferred			Common		Par		Paid in		Accumulated			Comprehensive
	Shares			Value			Shares		Value		Capital		Deficit			Loss			Total

Balance at December 31, 2006		0		$	0			1,976,837	$	395,367	$	18,887,178	$	(24,480,256	)	$	0		$	(5,197,711	)

Issued shares to pay equity line								393,737		78,747		181,631								260,378
Issued shares to consultants								50,714		10,143		48,643								58,786
Issuance of preferred stock		20,000,000		$	200,000															200,000
Issuance of common stock								3,500,000		700,000										700,000
Issuance of debenture- derivative value												1,853,360								1,853,360
Loss on investment (Star Energy)																	(184,800	)		(184,800	)
Net loss for the fiscal year														(1,474,050	)					(1,474,050	)

Balance at December 31, 2007		20,000,000		$	200,000			5,921,288	$	1,184,257	$	20,970,812	$	(25,954,306	)	$	(184,800	)	$	(3,784,037	)

Loss on investment (Star Energy)																	(382,200	)		(382,200	)
Convert preferred stock		(20,000,000	)	$	(200,000	)		1,000,000		200,000										0
Net income for the fiscal year														3,264,439						3,264,439

Balance at December 31, 2008		0		$	0			6,921,288	$	1,384,257	$	20,970,812	$	(22,689,867	)	$	(567,000	)	$	(901,798	)

Please see the notes to the consolidated financial statements.

F-6

EGPI Firecreek, Inc.

Notes to the Consolidated Financial Statements

For the Years Ended December 31, 2007 and December 31, 2006

1. Organization of the Company and Significant Accounting Principles

The Company was incorporated in the State of Nevada October 1995. Effective October 13, 2004 the Company, previously known as Energy Producers Inc., changed its name to EGPI Firecreek, Inc.

Prior to December 2008, the Company had interests in various gas & oil wells located in the Wyoming and Texas area. In December 2008, the Company’s major creditor, Duchess Private Equities Ltd. (Duchess), foreclosed on the assets of the Company. As a result, all of the Company’s oil and gas properties were transferred to Duchess in satisfaction of debt owed. See financial statement Note 9 for further discussion.

In October 2008, the Company effected a 1 share for 200 shares reverse split of its common stock. See financial statement note 5 for a further discussion.

Consolidation- the accompanying consolidated financial statements include the accounts of the Company and its wholly owned subsidiary. All significant inter-company balances have been eliminated.

Use of Estimates- The preparation of the financial statements in conformity with generally accepted accounting principles requires management to make reasonable estimates and assumptions that affect the reported amounts of the assets and liabilities and disclosure of contingent assets and liabilities and the reported amounts of revenues and expenses at the date of the consolidated financial statements and for the period they include. Actual results may differ from these estimates.

Revenue and Cost Recognition- Revenue is recognized from oil &gas sales at such time as the oil & gas is delivered to the buyer. For its producing activities, the Company uses successful efforts costing.

Properties and Equipment-The Company uses the successful efforts method of accounting for oil and gas producing activities. Under this method, acquisition costs for proved and unproved properties are capitalized when incurred. Exploration costs, including geological and geophysical costs, the costs of carrying and retaining unproved properties and exploratory dry hole drilling costs, are expensed. Development costs, including the costs to drill and equip development wells, and successful exploratory drilling costs to locate proved reserves are capitalized.

Exploratory drilling costs are capitalized when incurred pending the determination of whether a well has found proved reserves. A determination of whether a well has found proved reserves is made shortly after drilling is completed. The determination is based on a process which relies on interpretations of available geologic, geophysic, and engineering data. If a well is determined to be successful, the capitalized drilling costs will be reclassified as part of the cost of the well. If a well is determined to be unsuccessful, the capitalized drilling costs will be charged to expense in the period the determination is made. If an exploratory well requires a major capital expenditure before production can begin, the cost of drilling the exploratory well will continue to be carried as an asset pending determination of whether proved reserves have been found only as long as: i) the well has found a sufficient quantity of reserves to justify its completion as a producing well if the required capital expenditure is made and ii) drilling of the additional exploratory wells is under way or firmly planned for the near future. If drilling in the area is not under way or firmly planned, or if the well has not found a commercially producible quantity of reserves, the exploratory well is assumed to be impaired, and its costs are charged to expense.

In the absence of a determination as to whether the reserves that have been found can be classified as proved, the costs of drilling such an exploratory well is not carried as an asset for more than one year following completion of drilling. If, after that year has passed, a determination that proved reserves exist cannot be made, the well is assumed to be impaired, and its costs are charged to expense. Its costs can, however, continue to be capitalized if a sufficient quantity of reserves is discovered in the well to justify its completion as a producing well and sufficient progress is made in assessing the reserves and the well’s economic and operating feasibility.

The impairment of unamortized capital costs is measured at a lease level and is reduced to fair value if it is determined that the sum of expected future net cash flows is less than the net book value. The Company determines if impairment has occurred through either adverse changes or as a result of the annual review of all fields. During 2006 and 2005, the Company did not record any impairment.

F-7

Development costs of proved oil and gas properties, including estimated dismantlement, restoration and abandonment costs and acquisition costs, are depreciated and depleted on a field basis by the units-of-production method using proved developed and proved reserves, respectively. The costs of unproved oil and gas properties are generally combined and impaired over a period that is based on the average holding period for such properties and the Company's experience of successful drilling.

Costs of retired, sold or abandoned properties that make up a part of an amortization base (partial field) are charged to accumulated depreciation, depletion and amortization if the units-of-production rate is not significantly affected. Accordingly, a gain or loss, if any, is recognized only when a group of proved properties (entire field) that make up the amortization base has been retired, abandoned or sold.

Cash- For the purpose of compiling the statement of changes in cash flows, cash includes all cash balances and highly liquid short-term investments with original maturity dates of three months or less.

Investment in Star Energy, fair value- The Company accounts for its investments in Star Energy as per SFAS 115, Accounting for Certain Investments in Debt and Equity Securities. Management has designated its investments in Star Energy as “available for sale”. Accordingly, investment is recorded at market value and earnings and losses on investments are recognized in the consolidated balance sheets as other comprehensive income.

The Company has also adopted Statement of Financial Accounting Standards (“SFAS”) No. 157, Fair Value Measurements (“SFAS No. 157”), to account for its investment, which among other things, requires enhanced disclosures about financial instruments carried at fair value.

After adoption of SFAS No.157, investments measured and reported at fair value are classified and disclosed in one of the following categories:

	•		Level I—Quoted prices are available in active markets for identical investments as of the reporting date. The type of investments in Level I include listed equities and listed derivatives.
	•		Level II—Pricing inputs are other than quoted prices in active markets, which are either directly or indirectly observable as of the reporting date, and fair value is determined through the use of models or other valuation methodologies. Investments which are generally included in this category include corporate bonds and loans, less liquid and restricted equity securities and certain over-the-counter derivatives.
	•		Level III—Pricing inputs are unobservable for the investment and includes situations where there is little, if any, market activity for the investment. The inputs into the determination of fair value require significant management judgment or estimation. Investments that are included in this category generally include general and limited partnership interests in corporate private equity and real estate funds, funds of hedge funds, distressed debt and non-investment grade residual interests in securitizations and collateralized debt obligations.

The investment in Star Energy is a Level I investment at December 31, 2007.

Deferred costs- Deferred costs are the costs of obtaining the equity line of credit discussed in Note 9 and are amortized over the life of the loan.

Fixed Assets- Fixed assets are stated at cost. Depreciation expense is computed using the straight-line method over the estimated useful life of the asset. The following is a summary of the estimated useful lives used in computing depreciation expense:

Office equipment	3 years
Computer hardware & software	3 years
Improvements & furniture	5 years
Well equipment	7 years

Expenditures for major repairs and renewals that extend the useful life of the asset are capitalized. Minor repair expenditures are charged to expense as incurred.

Long Lived Assets- The Company reviews for the impairment of long-lived assets whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. An impairment loss would be recognized when estimated future cash flows expected to result from the use of the asset and its eventual disposition is less than its carrying amount.

F-8

The Company applied SFAS No. 144, Accounting for the Impairment or Disposal of Long Lived Assets, to account for the sale of the oil & gas properties in December 2008 as more fully discussed in financial statement note 9. Accordingly, the results of operations and cash flows from these assets for both 2008 and 2007 are separately recorded in the consolidated statements of operations and cash flows as a discontinued component.

Income taxes- The Company accounts for income taxes in accordance with the Statement of Accounting Standards No. 109 (SFAS No. 109), "Accounting for Income Taxes". SFAS No. 109 requires an asset and liability approach to financial accounting and reporting for income taxes. Deferred income tax assets and liabilities are computed annually for differences between financial statement and income tax bases of assets and liabilities that will result in taxable income or deductible expenses in the future based on enacted tax laws and rates applicable to the periods in which the differences are expected to affect taxable income. Valuation allowances are established when necessary to reduce deferred tax assets and liabilities to the amount expected to be realized. Income tax expense is the tax payable or refundable for the period adjusted for the change during the period in deferred tax assets and liabilities.

Recent accounting pronouncements:

In September 2006, the FASB issued SFAS No. 157, “Fair Value Measurements” (“SFAS 157”). SFAS 157 provides guidance for using fair value to measure assets and liabilities. It also responds to investors’ requests for expanded information about the extent to which companies measure assets and liabilities at fair value, the information used to measure fair value and the effect of fair value measurements on earnings. SFAS 157 applies whenever other standards require (or permit) assets or liabilities to be measured at fair value. The standard does not expand the use of fair value in any new circumstances, but provides clarification on acceptable fair valuation methods and applications. SFAS 157 was effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. The adoption of SFAS 157 will not have a material affect on the Company’s consolidated financial statements.

In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities” (“SFAS 159”). SFAS 159 permits entities to choose to measure many financial assets and financial liabilities at fair value. Unrealized gains and losses on items for which the fair value option has been elected are reported in earnings. SFAS 159 is effective for fiscal years beginning after November 15, 2007. The adoption of SFAS 159 will not have a material affect on the Fund’s financial statements.

In December 2007, the FASB issued SFAS No. 141(R), “Business Combinations” (“SFAS 141(R)”). SFAS 141(R) establishes principles and requirements for how the acquirer of a business recognizes and measures in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree. The statement also provides guidance for recognizing and measuring the goodwill acquired in the business combination or a gain from a bargain purchase and determines what information to disclose to enable users of financial statements to evaluate the nature and financial effects of the business combination. SFAS 141(R) is effective for financial statements issued for fiscal years beginning after December 15, 2008. The adoption of SFAS 141(R) will not have a material affect on the Company’s consolidated financial statements.

In March 2008, the FASB issued SFAS No. 161, “Disclosures about Derivative Instruments and Hedging Activities-an amendment of FASB Statement No. 133” (“SFAS 161”). SFAS 161 updates guidance regarding disclosure requirements for derivative instruments and hedging activities. It responds to constituents’ concerns that FASB Statement No. 133 does not provide adequate information about how derivative and hedging activities affect an entity’s financial position, financial performance, and cash flows. SFAS 161 is effective for financial statements issued for fiscal years and interim period beginning after November 15, 2008. The adoption of SFAS 161 will not have a material affect on the Company’s consolidated financial statements.

2. Going Concern

The accompanying consolidated financial statements have been presented in accordance with generally accepted accounting principals, which assume the continuity of the Company as a going concern. However, in December 2008 all of the producing assets of the Company were foreclosed on by Duchess to pay down loans owed. This situation raises the doubt of the Company’s ability to continue as a going concern.

Management’s plans with regard to this matter are as follows:

-Raise interim and long term finance to assist new oil and gas acquisitions, with good potential for rehabilitation to increase production, and upside potential initially for principally targeted shallow drilling development.

F-9

-Raise 6-12 months working capital for corporate operations.

-Pursue to obtain asset based project finance or develop joint ventures to fund work programs for oil and gas domestically.

-Pursue formation of strategic alliances with more firmly established peer groups to assist acquisition activities.

-Initiate search for experienced oil and gas personnel to add to our staff.

3. Fair Values of Financial Instruments

The carrying amounts of the cash, accounts receivable, deferred charges, investment in Star Energy, accounts payable and accrued expenses, note payable, equity line notes payable, advances & notes payable to shareholders, convertible debentures payable and derivative liability payable reported in the balance sheets are estimated by management to approximate fair value at December 31, 2008 and December 31, 2007.

4. Net Income (Loss) per Share

The Company applies SFAS No. 128, Earnings per Share to compute net loss per share. In accordance with SFAS No. 128, basic net loss per share has been computed based on the weighted average of common shares outstanding during the years. Diluted net loss per share gives the effect of outstanding common stock equivalents in the form of warrants, convertible preferred stock, and convertible debentures.

Net income (loss) per common share has been computed as follows:

	31-Dec-08			31-Dec-07

Net income (loss) from continuing operations	$	(578,717	)	$	(359,182	)
Net income (loss) from discontinued operations		3,843,156			(1,114,868	)
Net income (loss)	$	3,264,439		$	(1,474,050	)

Total shares outstanding		6,922,206			5,921,288

Basic weighted average of shares outstanding		6,088,411			2,158,841
Add effects of options outstanding		0			0
Fully diluted weighted average of shares outstanding		6,088,411			2,158,841

Basic income (loss) per share- continuing operations	$	(0.10	)	$	(0.17	)
Basic income (loss) per share- discontinued operations	$	0.64		$	(0.51	)
Basic income (loss) per share	$	0.54		$	(0.68	)

Fully diluted income (loss) per share- continuing operations	$	(0.10	)	$	(0.17	)
Fully diluted income (loss) per share- discontinued operations	$	0.64		$	(0.51	)
Fully diluted income (loss) per share	$	0.54		$	(0.68	)

All amounts for fiscal year 2007 have been adjusted for the 1 for 200 reverse stock split more fully discussed Note 5.

F-10

5. Common and Preferred Stock Transactions and Reverse Stock Split

During the year ended December 31, 2007, the Company issued 50,714 shares of common stock to pay consulting fees.

During the year ended December 31, 2007, the Company issued 393,737 shares of common stock to pay down the equity line.

During the year ended December 31, 2007, the Company issued 3,500,000 shares of common stock and received proceeds of $700,000.

During the year ended December 31, 2007, the Company issued 20,000,000 shares of Preferred C stock to Duchess and received proceeds of $200,000.

In October 2008 Duchess converted their shares into 1,000,000 shares of common stock.

In October 2008, the Company effected a 1 share for 200 shares reverse split of its common stock. As a result, the issued and outstanding shares at December 31, 2007 were decreased from 1,184,257,619 shares to 5,921,288 shares and basic and fully diluted loss per share for fiscal year 2007 was decreased from $0.00 to $0.68. In addition, the par value of the common stock was increased from $0.001 to $0.20.

6. Preferred Stock Series

Series A preferred stock: Series A preferred stock has a par value of $0.001 per share and no stated dividend preference. The Series A is convertible into common stock at a conversion ratio of one preferred share for one common share. Preferred A has liquidation preference over Preferred B stock and common stock.

Series B preferred stock: Series B preferred stock has a par value of $0.001 per share and no stated dividend preference. The Series B is convertible into common stock at a conversion ratio of one preferred share for one common share. The Series B has liquidation preference over Preferred C stock and common stock.

Series C preferred stock: The Preferred C stock has a stated value of $.001 and no stated dividend rate and is non-participatory. One share of preferred is convertible into 10 shares of common stock. The Series C has liquidation preference over common stock.

7. Fixed Assets- Net

The following is a detailed list of fixed assets:

	31-Dec-08		31-Dec-07

Well leases	$	0	$	1,068,650
Well equipment		0		1,316,710
Accumulated depreciation & depletion		0		(150,430	)

Fixed assets- net	$	0	$	2,234,930

In fiscal year 2007, the Company closed its former Firecreek offices in Fort Worth, Texas as part of its restructuring efforts. Management elected to impair the value of the fixed assets associated with this office and recorded the impairment expense in the statement of operations for 2007.

F-11

8. Options Outstanding

The Company applies SFAS No. 123, “Accounting for Stock-Based Compensation” to account for option issues. Accordingly, all options granted are recorded at fair value using a generally accepted option pricing model at the date of the grant. There is no formal stock option plan for employees.

A listing of options outstanding at December 31, 2008 is as follows. Options outstanding and their attendant exercise prices have been adjusted for the 1 for 200 reverse split of the common stock discussed in Note 5.

				Weighted Average		Weighted Average
	Amount			Exercise Price		Years to Maturity

Outstanding at December 31, 2006		207,810		$	80.00000		2.72

Issued		0
Exercised		0
Expired		(29,000	)

Outstanding at December 31, 2007		178,810		$	72.00000		1.61

Issued		0
Exercised		0
Expired		0

Outstanding at December 31, 2008		178,810		$	71.77026		0.61

9. Disposal of Tubb, Ten-Mile Draw, and Fant Ranch Properties

In fiscal year 2005, the Company entered into an equity line credit agreement with Duchess, a financing company, and a shareholder. Under the terms of the equity line agreement, the Company was obligated to pay the face value of the equity line notes in cash or an equivalent amount in common stock. All of the assets of the Company secured the equity line notes. The notes had an effective interest rate of approximately 20%. As an incentive to enter the equity line of credit, the Company also issued convertible debentures, see reference footnote 10, the fair market value of which had been discounted against the face of the equity line notes and was being amortized to interest expense over the life of the equity line notes.

The following is the schedule of the equity line notes payable at December 31, 2008 and December 31, 2007:

	31-Dec-08		31-Dec-07

Matured in September 2006, effective interest of 18.55%	$	0	$	1,086,803
Matured in November 2006, effective interest of 22.12%		0		1,488,215
Matured in December 2006, effective interest of 22.12%		0		129,885
Matured in April 2007, effective interest of 22.12%		0		581,603
Matured in December 2007, effective interest of 17.34%		0		1,042,651
Matured in March 2008, effective interest of 25.68%		0		474,623
Less discount		0		(50,431	)

Total equity line of credit	$	0	$	4,753,349

F-12

At December 2, 2008, the Dutchess foreclosed on all of the assets of the Company. As a result of the foreclosure by Duchess, the Company transferred all of its assets in its Tubb and Fant Ranch oil & gas properties and $50,000 to retire all the debt owed to Duchess. As a result of the foreclosure the Company recognized a gain on the disposal of these assets of $6,385,133 in its consolidated statement of operations at December 31, 2008. The Ten-Mile Draw property had been earlier sold in October 2008 for $125,000. The Company recognized a loss on this asset disposal of $581,654 in the consolidated statement of operations.

Gain of disposal of discontinued component

Cash received	$	75.000
Deb; retired		9,201,166
Assets transferred- net		(3,472,687	)
Gain of disposal of discontinued component	$	5,803,479

loss from operations of discontinued component

Revenues from sales of oil & gas	$	1,437,437
Cost of revenues		(921,6900
Net revenues	$	515,747

Operating costs		356,647

Income from operations	$	159,100

Other income/(expense)
interest costs		(2,548.005	)
Gain on derivative		428,582

Loss from Operations of discontinued component	$	(1,960,323	)

10. Issuance of Incentive Convertible Debentures

During the fiscal year ended December 31, 2007, the Company issued a 12% incentive debenture with a face value of $500,000 to pay an incentive fee to Duchess issued on December 26, 2007 (reference footnote 11). The incentive debenture was recorded as a discount to convertible debenture at fair market value at the date of issuance to debt discount and will be amortized over the life of the equity credit line issuance. The debenture is convertible into common stock at 75% of the lowest bid price of the common stock for the fifteen days preceding conversion. The incentive debenture was to mature in December 2014. At issuance, the incentive debenture was valued using a Black Scholes Option Pricing Model utilizing the following assumptions: volatility: 20%, straight bond yield: 5.0%, risk-free rate: 4.0%, and dividend growth rate: 0%. The fair market value will be assessed each balance sheet date over the maturity of the debenture and will be marked to market with the gain or loss recorded in the Company’s statement of operations.

During the fiscal year ended December 31, 2007, the Company issued a non-interest bearing incentive debenture with a face value of $140,000 to pay an incentive fee to Duchess. The incentive debenture was recorded as a discount to the equity credit line at fair market value at the date of issuance to debt discount and will be amortized over the life of the equity credit line issuance. The debenture is convertible into common stock at 75% of the lowest bid price of the common stock for the fifteen days preceding conversion. The incentive debenture was to mature in March 2012. At issuance, the incentive debenture was valued using a Black Scholes Option Pricing Model utilizing the following assumptions: volatility: 20%, straight bond yield: 5.0%, risk-free rate: 4.0%, and dividend growth rate: 0. The fair market value will be assessed each balance sheet date over the maturity of the debenture and will be marked to market with the gain or loss recorded in the Company’s statement of operations.

11. Issuance of Convertible Debentures

On December 26, 2007, the Company issued a convertible debenture in the face amount of $2,100,000. The debenture beared interest at 12% per annum and originally matured on December 26, 2014. The note holder had the right to convert any and all amounts owed into shares of the Company’s common stock at any time following the closing date. The conversion price of the debenture was equal to the lesser of 75% of the lowest closing bid price of the common stock during the twenty trading days immediately prior to the notice of conversion, or $0.005. As an inducement to the holder, the Company issued 3,500,000 shares of the Company’s common stock and 20,000,000 shares of the Company’s Series C Preferred Stock. In addition, the Company also issued a $500,000 incentive debenture to Duchess (reference footnote 10). Both the shares of the Company’s securities and the incentive debenture were recorded as a discount to the debt issuance and are amortized over the life of the convertible note. At issuance, the conversion feature was accounted for under EITF 00-27, “Application of Issue No. 98-5 to Certain Convertible Instruments”. Although the conversion feature is convertible into an indeterminate number of shares, the noteholder holds a controlling interest in the Company. Net share settlement can occur. The conversion feature was calculated using the intrinsic value method and recorded as a debt discount.

On June 11, 2007, the Company issued a convertible debenture in the face amount of $2,000,000. The debenture beared interest at 12% per annum and was to mature on June 11, 2014. The note-holder had the right to convert any and all amounts owed into share of the Company’s common stock at any time following the closing date. The conversion price of the debenture was equal to the lesser of 75% of the lowest closing bid price of the common stock during the twenty trading days immediately prior to the notice of conversion, or $0.015. At issuance, the conversion feature was accounted for as a derivative liability in accordance with EITF 00-19 “Accounting For Derivative Instruments Indexed To, and Potentially Settled, In the Company’s Own Stock,” due to the conversion feature permitting conversion into an indeterminate number of shares. At issuance, the conversion feature was valued using a Black Scholes Option Pricing Model utilizing the following assumptions: volatility: 20%, straight bond yield: 5.0%, risk-free rate: 2.0%, and dividend growth rate: 0%. The conversion option will be assessed each balance sheet date over the maturity of the debentures and will be marked to market with the gain or loss recorded in the Company’s statement of operations.

As of December 26, 2007, the conversion feature was no longer accounted for as a derivative liability. The noteholder owns a controlling interest in the Company, and has control to authorize additional shares as warranted. The conversion liability was reclassified to additional paid in capital.

F-13

12. Income Tax Provision

Provision for income taxes is comprised of the following:	31-Dec-08			31-Dec-07

Net loss before provision for income taxes	$	(578,717	)	$	(359,182	)

Current tax expense:
Federal		0			0
State		0			0
Total	$	0		$	0

Less deferred tax benefit:
Timing differences		(1,203,124	)		(2,750,468	)
Allowance for recoverability		1,203,124			2,750,468
Provision for income taxes	$	0		$	0

A reconciliation of provision for income taxes at the statutory rate to provision for income taxes at the Company's effective tax rate is as follows:

Statutory U.S. federal rate		34	%		34	%
Statutory state and local income tax		10	%		10	%
Less allowance for tax recoverability		-44	%		-44	%
Effective rate		0	%		0	%

Deferred income taxes are comprised of the following:

Timing differences	$	1,203,124		$	2,750,468
Allowance for recoverability		(1,203,124	)		(2,750,468	)
Deferred tax benefit	$	0		$	0

Note: The deferred tax benefits arising from the timing differences begin to expire in fiscal years 2027 and 2028 and may not be recoverable upon the purchase of the Company under current IRS statutes.

13. Gain on Sale of Asset

In August 2007, the Company sold all of its rights to certain projects in the Ukraine that had been developed through its subsidiary, Firecreek Petroleum Inc., to Star Energy Corp. for $100,000 cash and 2.1 million shares of Star’s stock. The rights to these projects had previously been 100% impaired by the Company in 2005 and therefore all the proceeds received from the transaction have been recorded as a “gain on asset sale” in the consolidated statement of operations in 2007. Management has classified the Star stock as “available for sale” as per SFAS 115, “Accounting for Certain Investments in Debt and Equity Securities” and, accordingly, has recorded the loss in the market value of the stock in other comprehensive income at December 31, 2007 and at December 31, 2008. The stock was sold in December 2008.

14. Non Cash Transactions

Certain transactions during the years ended December 31, 2007 did not involve the use of cash and therefore have been excluded from the consolidated statements of cash flows.

During the year ended December 31, 2007, the Company issued 393,737 shares of common stock to pay $280,378 of the equity credit line discussed in Note 9.

F-14

15. Supplemental Information on Oil & Gas Operations and Property Acquisitions and Sales

In November 2005, the Company purchased a 50% working interest in The Ten Mile Draw Field (TMD), a natural gas field located in Sweetwater County, Wyoming for $1,089,130. Of the total acquisition costs $475,000 was used to acquire the lease, $126,000 was used for well equipment costs, and $488,130 for development costs. In October 2008, the TMD property was sold f0r $125,000. The Company recognized a loss on the disposal of the asset in its consolidated statement of operations of $581,654.

On July 9, 2007, the Company acquired certain tracts of land and leases located in Knox County, Texas, known as the Fant Ranch Unit for $1,538,705 which included wells, leases and equipment and the oil in the tanks owned by the seller at that time.

In January 2008, the Company, through it’s wholly owned subsidiary, Firecreek Petroleum, Inc, purchased a certain 40 acre tract of land and leases with first right for an additional 40 acre lease located in Ward County, Texas, more commonly known as the J.B. Tubb Leasehold Estate. The Company paid $1,400,000 for the lease, equipment and a Participation Agreement which provides for turnkey drilling, re-entry and includes multiple wells. At December 2, 2008, the Company was in default of the equity line notes and Duchess foreclosed on all of the assets of the Company. As a result of the foreclosure by Duchess, the Company transferred all of its assets in its Tubb and Fant Ranch oil & gas properties and $50,000 to retire all the debt to Duchess that was outstanding at December 2, 2008. As a result of the foreclosure the Company recognized a gain on the disposal of these assets of $6,385,123 in its consolidated statement of operations at December 31, 2008.

The following is a summary of the Company’s oil & gas production activities for the years ending December 31, 2008 and December 31, 2007 representing the Company’s net revenue interests.

Reserve Quantity Information

Proved Developed and Undeveloped Reserves:

(All United States Based)

	2008						2007
	Oil			Gas			Oil		Gas
	(Barrels)			(Mcf)			(Barrels)		(Mcf)
Beginning of Year		64,709			1,029,200			0		1,050,022
Revisions		0			0			-3,004		14,216
Improvements		0			0			0		0
Purchases		785,220			0			71,774		0
Disposal		(840,708	)		(1,012,732	)		0		0
Production		(9,221	)		(16,468	)		-4,061		-25,238
End of Year		0			0			64,709		1,029,200

Proved Developed Reserves:

	2008				2007
	Oil		Gas		Oil		Gas
	(Barrels)		(Mcf)		(Barrels)		(Mcf)
Beginning of Year		64,709		312,189		0		344,739
End of Year		0		0		64,709		312,189

Results of operations (All United States Based):

	2008		2007
Revenues	$	1,437,437	$	451,514
Production costs		-771,193		-317,343
Exploration costs		0		0
Development costs		-325,000		-130,551
Depreciation & amortization		-150,498		-129,921
Provision for income tax		0		0
Net profit (loss) from oil and gas producing activities:	$	190,746	$	(126,301	)

F-15

Capitalized cost of oil and gas producing activities:

	2008			2007
Proved oil and gas lease properties	$	1,928,960		$	1,068,650
Well Equipment		977,668			1,316,710
Accumulated depreciation		-180,257			-150,430
Net capitalized costs of natural gas producing activities	$	2,726,371		$	2,234,930
Transfer to Duchess		(2,726,371	)		0
Balance of capitalized costs		0			2,234,930

Costs incurred for property acquisitions, exploration, and development:

	2008		2007
Property acquisition	$	1,400,000	$	1,506,628
Proved		0		0
Unproved		0		0
Exploration		0		0
Development		328,746		120,736
Total	$	1,728,746	$	1,627,364

Changes in discounted future cash flows of proved reserves:

	2008		2007
Future cash flows	$	0	$	13,978,098
Future production costs		0		-8,716,030
Future income tax expense		0		-1,15,034
Future net cash flows		0		4,157,034
10% annual discount		0		-1,323,971
Standardized measure of discounted future net cash flows	$	0	$	2,833,063

16. Related Party Transactions

During fiscal years 2008 and 2007, the chief executive officer and shareholder provided office space to the Company at no charge.

During fiscal years 2008 and 2007, three shareholders had unsecured non-interest bearing advances receivable from the Company. The Company has imputed an interest rate of 20% on these advances.

The Company was indebted to Duchess Private Equities Ltd., a stockholder at December 2, 2008, the date of the Duchess foreclosure. As a result of the foreclosure by Duchess, the Company transferred all of its assets in its Tubb and Fant Ranch oil & gas properties and $50,000 to retire all the debt owed to Duchess. As a result of the foreclosure the Company recognized a gain on the disposal of these assets of $5,028,954 in its consolidated statement of operations at December 31, 2008. See financial statement note 9 for a further discussion.

17. Note Payable

In December 2008, the Company issued a note payable to Duchess for $47,565 in return for the right to participate with Duchess in any future drilling in a portion of the Tubb property. The note is unsecured and carries an interest rate of 12% and matures in June 2009. Management considered the asset received in this purchase to be impaired because future cash flows from this asset could not be assured and accordingly recognized an impairment expense in the consolidated statements of operations.

F-16

18. Subsequent Events

In February 2009 and March 2009, 92,500 of the options outstanding discussed in Note 8 expired.

In February 2009, the Company issued 2,065,000 shares of common stock to various consultants for services.

In February 2009, the Company issued 60,000 shares of common stock to a consultant to pay an outstanding invoice owed to this consultant.

In February 2009, the Company issued 340,000 shares of common stock to a debt holder to pay 50% of the outstanding balance owed on the debt.

In February 2009, the Company entered into a service agreement with a consultant for services to be provided. Upon execution of the agreement, the Company issued 340,000 shares of common stock to the consultant and a three year option to purchase 500,000 shares of common stock at an exercise price of $1 per share. Under the terms of the agreement, the Company is obligated to pay the consultant $7,500 up front and $5,000 per month for the following eleven months.

ITEM 9.

CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None

ITEM 9AT. CONTROLS AND PROCEDURES

EGPI Firecreek, Inc. is responsible for establishing and maintaining adequate internal control over financial reporting. EGPI Firecreek, Inc. internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

EGPI Firecreek, Inc. management assessed the effectiveness of the Company’s internal control over financial reporting as of December 31, 2008. Management has attempted to design such disclosure controls and procedures as defined under Rule 13a-13(e) promulgated under the Securities and Exchange Act of 1934 as amended, to ensure that material information is made known to them, particularly during the period in which this report was prepared. Accordingly, based on our assessment we have concluded that, as of December 31, 2008, the Company’s internal control over financial reporting were effective based on those criteria outlined under the Securities Exchange Act.

The Company’s President and Chief Financial Officer, the (“Certifying Officer”) has evaluated the effectiveness of the Company’s disclosure controls and procedures within 90 days of the end of the period covered by this report and believe that the Company’s disclosure controls and procedures were effective based on the required evaluation as of the end of the period covered by this Report.

ITEM 9B.

OTHER INFORMATION

On February 1, 2009, the Company entered into an Advisory Service Agreement with Joseph M. Vazquez pertaining to advising corporate management, strategic planning, corporate development and forecasting, marketing, structuring investor relations programs, contract negotiations and performing general administrative duties. The term of the Agreement is for twelve (12) months ("Initial Term") which shall automatically be renewed for an additional twelve (12) month period, unless terminated upon prior notice within thirty (30) days before the end of initial term. Pursuant to the Agreement, the Company shall pay $7,500 to Mr. Vazquez for initial set up and travel costs and first months retainer rendered in connection with engagement, and 340,000 restricted shares of common stock. Thereafter, the Company shall pay $5,000 per month during the remaining months of the Initial Term of the Agreement. Further, the Company shall also issue to Mr. Vasquez three year warrants to purchase 500,000 shares at $1.00 per share. Per the terms of the Agreement, Beneficial ownership is not to exceed 4.99%.

A copy of the Advisory Services Agreement is attached hereto as Exhibit 10.33.

Please also see information in the Section of this Report titled “RECENT SALES OF UNREGISTERED SECURITIES”.

Effective April 12, 2009 by majority consent of the EGPI Firecreek, Inc. (“EGPI” or the “Company”) shareholders of record at March 31, 2009 three (3) members were elected to the Company’s Board of Directors, consisting of three members that have previously served. The Directors shall hold their respective office until the Company’s Annual Meeting of Shareholders in 2010 or until their successors are duly elected and qualified. The members of the Company’s Board of Directors are as follows:

NAME	AGE	POSITION WITH COMPANY
Dennis R. Alexander	55	Chairman
Larry W. Trapp	67	Director
Mike Trapp	42	Director

On April 12, 2009 by majority consent of the Board of Directors of EGPI Firecreek, Inc. (“EGPI” or the “Company”) the following officers were elected as officers of the Company, consisting of three officers that have previously served. The officers of the Company are as follows:

NAME	AGE	POSITION WITH COMPANY
Dennis R. Alexander	55	CEO, President and C.F.O.
Larry W. Trapp	67	Executive Vice President and Co-Treasurer
Melvena Alexander	75	Secretary and Comptroller and Co-Treasurer

Board Meeting

While the Board of Directors had no regularly scheduled physical or special meetings held during fiscal 2008, the Board of Directors business was conducted via Consent(s) to Action in Lieu of Meeting, held Electronically, Telephonically, or In Person, (the “Consent(s)”)). There were a total of five (5) consents obtained during fiscal 2008 and all members of the then Board of Directors attended at least 75% of all meetings held by the above listed Consent(s).

COMMITTEES OF THE BOARD OF DIRECTORS

The Board of Directors has decided reconfirming at this time (April 12, 2009) to maintain its Audit Committee and disbanding all other committees of the Board of Directors; specifically, its Nominating Committee, Executive Committee, Projects Committee, Compensation and Stock Option Committee, Administration and Legal Committee, Finance Committee, and Shareholder and Investor Relations Committee.

With the exception of Dennis Alexander, none of the elected members of the Board of Directors has previously served as a member of the Company’s Compensation Committee, or any other committee serving similar functions, during the last completed fiscal year.

Compensation Committee

The Company dissolved the Compensation Committee due the Company’s size, financial restrictions, time constraints, and limitations which together prohibits hiring of employees. Various compensatory arrangements during Fiscal 2008, including sub contractors, service providers, advisory and consultation arrangements, will be contracted for by the general Board of Directors. Compensation will be determined by type of service, time required, and prevailing rate for service provider or sub contractor.

Nomination Committee

The Company abolished the Nomination Committee due the Company’s size, financial restrictions, time constraints, and limitations which together prohibits hiring of employees. The process by which Directors are presently appointed to the Company consists of obtaining the majority consent of the major shareholders, and is based on their selection processes.

Audit Committee

That the Audit Committee does not have a charter that governs its activities and is composed of three members: Ms. Joanne Sylvanus, its Chairman, Mr. Dennis Alexander, member, and Ms. Melvena Alexander, member.

The responsibilities of the Audit Committee include: (1) the recommendation of the selection and retention of the Company’s independent public accountants; (2) the review of the independence of such accountants; (3) to review and approve any material accounting policy changes affecting the Company’s operating results; (4) the review of the Company’s internal control system; (5) the review of the Company’s annual financial report to stockholders; and (6) the review of applicable interested party transactions.

RATIFICATION OF APPOINTMENT OF AUDITORS

The Board of Directors has appointed Donahue Associates, L.L.C., as the Company's independent certified public accountants for the fiscal year ending December 31, 2009. Donahue Associates, L.L.C., was the independent public auditor of the Company for the fiscal year ended 2008.

There have been no disagreements between the Company and the Auditors during the term of its relationship.

PART III

ITEM 10.

DIRECTORS, EXECUTIVE OFFICERS, CORPORATE GOVERNANCE

The directors, executive officers and significant employees of the Company as of March 31, 2009 are as follows:

NAME	AGE	POSITION WITH COMPANY

Dennis R. Alexander	55	Chairman, President, and CFO of the Company, Firecreek Petroleum, Inc., and Director of IYSG ltd.
Larry W. Trapp	67	Director, Executive Vice President, and Co-Treasurer of the Company, and Firecreek Petroleum, Inc.
Mike Trapp	42	Director of the Company and Firecreek Petroleum, Inc.
Melvena Alexander	75	Co-Treasurer, Secretary and Comptroller of the Company and Firecreek Petroleum, Inc.

Term for Directors: In accordance with Article 9.2 of the Company’s Bylaws: The members of the Board of Directors shall hold office until the first annual meeting of Stockholders and until their successors shall have been elected and qualified. At the first annual meeting of Stockholders and at each annual meeting thereafter the Stockholders shall elect Directors to hold office until the next succeeding annual meeting, except in the case of classification of the Directors. Each Director shall hold office for the term for which he is elected until his successor shall have been elected and qualified.

Dennis R. Alexander has served as Chairman, President and CFO of the Company and Firecreek Petroleum, Inc. since February 10, 2007. He served as Chairman and CFO of the Company and Firecreek Petroleum, Inc. since July 1, 2004 through February 9, 2007 having served as the President and Director of the Company from May 18, 1999 to June 30, 2004. In September 1998 he was a founder, and from January 19, 1999 through its acquisition with the Company served as President and Director of Energy Producers Group, Inc. From April 1997 through March 1998, served as CEO, Director, Consultant of Miner Communications, Inc., a media communications company. From April 26, 1997 through March, 1998 he was a director of Rockline, Inc., a private mining, resource company, and a founder of World Wide Bio Med, Inc., a private health-bio care, start up company. Since March 1996 to the present he has owned Global Media Network USA, Inc., which has included management consulting, advisory services. Mr. Alexander devotes approximately 60 to 80 hours per week minimum, and more as required, to the business of the Company.

Larry W. Trapp was appointed as a Director, Executive Vice President, and Treasurer of the Company on December 3, 2008. Previously he has served in various capacities as CFO, Vice President, and Director through January 26, 2004 and is one of the original founders in 1998 through the acquisition processes with the Company, serving as Director of Energy Producers Group, Inc. Mr. Trapp earned a BS in Business Administration with emphasis in Finance from Arizona State University. Prior business experience includes Vice President of Escrow Administration for a major Title Insurance Company where he was directly responsible for the Management and performance of 22 branches and supervised an administration staff of 125 Employees.

Mike Trapp was appointed as a Director of the Company on December 3, 2008. A graduate of Rice Aviation he earned honors and honed his skills as a Airframe and Power Plant licensee working in the airline industry for many years. He recently owned his own mortgage company and is now a Senior Loan Officer for a multi-state lender in Mesa, Arizona. His strong technical and analytical skills will be a bonus in analyzing prospective projects which will enhance the Company’s growth and asset base.

Melvena Alexander has served as Co-Treasurer, Secretary and Comptroller of the Company and Firecreek Petroleum, Inc. since February 10, 2007 having served as Secretary and Comptroller of the Company and Firecreek Petroleum, Inc. since July 1, 2004 through February 9, 2007. She served as Secretary since March 15, 2003 to June 30, 2004 having been Secretary and Comptroller of the Company since May 18, 1999. In September 1998 she was a founder, and from January 19, 1999 through the acquisition processes with the Company served as Secretary of Energy Producers Group, Inc. She is founder and President of Melvena Alexander CPA since 1982, which prepares financial statements and tax reports. From October 1998 through April 16, 2004 she worked in the Department of Patient Finance at Arizona State Hospital as an Accounting Technician 11. Mrs. Alexander graduated Arizona State University with a B.S. in Accounting, received CPA Certificate, State of Arizona. She is a member of AICPA and the American Society of Women Accountants. Mrs. Alexander devotes a minimum of 40-60 hours per week, and more as required, to the business of the Company.

Family Relationships

Dennis R. Alexander, Chairman, President, and CFO is the son of Melvena Alexander, Co-Treasurer, Secretary and Comptroller.

Mike Trapp, Director, is the son of Larry W. Trapp, Director, Executive Vice President, and Co-Treasurer.

Committees Of The Board Of Directors

On April 12, 2009 the directors ratified, approved and re-confirmed in their entirety certain actions taken on June 16th, 2008, by greater than a majority of the Board of Directors of the Company for the disbanding of the following committees of the Company: Nominating Committee, Executive Projects Committee, Compensation and Stock Option Committee, Administration and Legal Committee, Finance Committee and Shareholder and Investor Relations Committee (for additional information please see Item 9B. –Other Information above listed in this report). As a result, the only committee of the Board of Directors is the Audit Committee. The Audit Committee shall consist of the following:

(1) That the Audit Committee is composed initially of three members: Ms. Joanne Sylvanus, its Chairman, Dennis Alexander and Melvena Alexander, members.

In 2009 we are again in process of evaluating various committee structures, and persons capable of becoming independent seat(s), and to provide for more independent committee function ability and standards.

COMPLIANCE WITH SECTION 16(a) OF THE SECURITIES EXCHANGE ACT OF 1934

Section 16(a) of the Securities Exchange Act of 1934 requires the Company’s officers and directors, and persons who own more than ten percent of the Company’s Common Stock, to file reports of ownership and changes in ownership with the Securities and Exchange Commission (“SEC”). Officers, directors and greater than ten percent stockholders are required by SEC regulations to furnish the Company with copies of all Section 16(a) forms they file.

Based solely on current management’s review of the copies of such forms received by it from former management, the Company believes that, during the year ended December 31, 2008, its officers, directors, and greater than ten-percent beneficial owners complied with all applicable filing requirements.

Code of Ethics

On December 31, 2003, the Company adopted its Code of Ethics and Business Conduct that applies to all of the officers, directors and/or employees of the Company. The Code of Ethics is included and filed as Exhibit 14 to our Form-10KSB filed on April 27, 2004 incorporated herein for reference. The Code is posted on our website (www.egpifirecreek.com) currently in continuous stages of upgrade development/construction. We will disclose on our completed website any waivers of, or amendments to, our Code.

ITEM 11.

EXECUTIVE COMPENSATION

The following tables summarize annual and long-term compensation paid to the Company’s Chief Executive Officer and the Company’s four other most highly compensated executive officers whose total annual salary and bonus compensation exceeded $100,000 who were serving as of December 31, 2008 for all services rendered to the Company and its subsidiaries during each of the last three fiscal years. The Company did not retain any employees and payments are made for services as available. The Company through Firecreek Petroleum, Inc. retained approximately eight employees during the first quarter of Fiscal Year 2006. All other tables required to be reported have been omitted, as there has been no compensation awarded to, earned by or paid to any of the executives of the Company that is required to be reported other than what is stated below.

All shares beneficially owned by the named executives below listed are bound by terms of a Voting Agreement (please see “Exhibit 99.3” to a Report on Form 8-K filed April 7, 2005 incorporated herein by reference).

Summary Compensation Table

Name and Principal Position	Year		Salary ($)	Stock Awards ($)		Option Awards ($)	All Other Compensation ($)

Dennis R. Alexander 9/ ()(*)		2008	n/a		n/a	-0-		-0-
Chairman, CEO, President, CFO 1/4//7		2007	n/a		n/a	-0-		-0-
		2006	n/a		n/a	-0-		148,750	2/5/

Melvena Alexander 9/ ()(*)		2008	n/a		n/a	-0-		-0-
Co Treasurer, Sect. and Cmpt. 1/6/8		2007	n/a		n/a	-0-		-0-
		2006	n/a		n/a	-0-		21,250	3/6/

1/	As part of an agreement with Firecreek Petroleum, Inc. for the Exchange of Common Stock Dated July 29, 2004, all named executives listed in the table received provisions and rights for facilitation fees, on completion of certain events, and terms to be established, as listed therein Section 9. d. of the agreement filed July 16, 2004 on Form 8-K as exhibit 21.1 thereto and incorporated for reference. Please also see “Certain Relationships and Related Transactions”.

2/	The amounts in this column for 2006 represents the aggregate value of common restricted stock issued on December 8, 2006 to the named executive. $148,750 of the amount listed in this row for 2006 represents the value of the shares issued to D.R. Alexander for services rendered, based on the closing market prices on or near such dates of $0.0085 per share (pre reverse split).

3/	The amounts in this column for 2006 represents the aggregate value of common restricted stock issued on December 8, 2006 to the named executive. $21,250 of the amount listed in this row for 2006 represents the value of the shares issued to Melvena Alexander for services rendered, based on the closing market prices on or near such dates of $0.0085 per share (pre reverse split).

4/	D.R. Alexander and Melvena Alexander received ()87,500 and ()12,500 shares (calculated on the current post reverse split basis) of restricted stock on December 8, 2006, respectively.

5/	Mr. Alexander holds a total of ()87,500 shares of common restricted stock as of ()December 31, 2006 (calculated on the current post reverse split basis). The market value of the (**) 87,500 shares on December 31, 2008 and December 31, 2007 was $5,250 and $35,000, respectively. No dividends are paid on the restricted common stock held.

6/	Melvena Alexander holds a total of ()12,500 shares of common restricted stock as of December 31, 2006 (calculated on the current post reverse split basis). The market value of the ()12,500 shares on December 31, 2008 and December 31, 2007 was $750 and $5,000, respectively. No dividends are paid on the restricted common stock held.

7/	Mr. Alexander holds a total of ()15,000 shares of common restricted stock as a result of the conversion in the aggregate of C-1, and C-2 of series C preferred to common, as of ()December 31, 2006 (calculated on the current post reverse split basis). The market value of these shares on December 31, 2008 and December 31, 2007 was $600 and $6,000, respectively. No dividends are paid on the restricted common stock held.

8/	Melvena Alexander holds a total of (**)5,500 shares of common restricted stock as a result of the conversion in the C-2 of series C preferred to common, as of December 31, 2006. The market value of these shares on December 31, 2008 and December 31, 2007 was $330 and $2,200, respectively. No dividends are paid on the restricted common stock held.

9/	D.R. Alexander and Melvena Alexander have been with the Company since 1999.

(*)	Please see “Certain Relationships and Related Transactions” for additional discussion on agreements with individual consulting firms.
(**)	All shares are calculated on a post effective one share for two hundred share (1:200) reverse split effective on October 8, 2008.

Options

The following table provides information related to remaining options held by our below named executive officer during the fiscal year ended December 31, 2008, and are calculated on the recent one share for two hundred share (1:200) reverse stock split effective October 8, 2008. These options however have expired as of February 9, 2009.

Option Awards

Name	Number of Securities Underlying Unexercised Options (#) Exercisable		Number of Securities Underlying Unexercised Options (#) Unexercisable	Option Exercise Price ($)		Option Expiration Date

Dennis R. Alexander (1) (2)
Chairman, President, CFO		10,000	N/A		140.00	2/9/2009

(1) The date of the option agreement with the named executive listed above in the table for 10,000 shares underlying unexercised options is August 9, 2004; i) The option exercise price is (3) $140.00 per share; ii) The expiration date of the option agreement is four years from the date of Vesting; iii) The Vesting Date is: For and after the expiration of on hundred eighty (180) days following the date of the agreement or February 9, 2005; iv) the Expiration Date for the option agreement 2/9/2009; v) The market price for the underlying restricted common stock on August 9, 2004, the date of grant, December 31, 2005, December 31, 2006, December 31, 2007 and December 31, 2008 for all grants listed in the table was $20.00, $6.00, $1.70, and $12.00 (calculated on post reverse split price) respectively, and vi) The exercise price of the options is equal to or in excess of the fair market value of the stock on the date of grant.

(2) For all option grants listed in the table above the following provision applies: If at any time after the date of this Agreement and prior to the expiration of all Exercise Period(s), the Company proposes to file a registration statement to register any Common Stock (other than Common Stock issued with respect to any acquisition or any employee stock option, stock purchase or similar plan) under the Securities Act of 1933, as amended (the “Securities Act”) for sale to the public in an underwritten offering, it will at each such time give prior written notice to the Optionee of its intention to do so (“Notice of Intent”) and, upon the written request of the Optionee made within 30 calendar days after the receipt of any such notice (which request must specify the number of Option Shares Optionee requests) to be included in the registration, the Company will use its best efforts to effect the registration under the Securities Act of the Option Shares which the Company has been so requested to register, provided, however, that if the managing underwriter shall certify in writing that inclusion of all or any of the Option Shares would, in such managing underwriter’s opinion, materially interfere with the proposed distribution and marketing of the Common Stock in respect of which registration was originally to be effected (such writing to state the basis of such opinion and the maximum number of shares which may be distributed without such interference), then the Company may, upon written notice to the Optionee, have the right to exclude from such registration such number of Option Shares which it would otherwise be required to register hereunder as is necessary to reduce the total amount of Common Stock to be so registered to the maximum amount which can be so marketed.

(3) Calculated on the recent one share for two hundred share (1:200) reverse stock split effective October 8, 2008.

Employee Pension, Profit Sharing or Other Retirement Plans

The Company does not have a defined benefit, pension plan, profit sharing, or other retirement plan.

Director Compensation

As of February 4, 2000 each member of the Board of Directors, subject to approval of the Chairman and CEO, may be paid $500.00 per formal meeting plus certain expenses for out of State Directors incurred in connection with attendance at Board and Committee meetings. There are no agreements provided to Directors or individual agreements with any Director other than that presented in this paragraph, and the understanding that at minimum a traveling Director will be considered by the Chairman more favorably for reimbursement of expenses for travel and may, at the election of the Chairman, be paid $500 for attendance at a formal meeting. This determination by the Chairman to provide for either reimbursement or compensation for a formal meeting is principally to be based on the finances of the Company available at the time.

Employment Agreements

The Company does not have any employment agreements with its executive officers.

ITEM 12.

SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

The following table sets forth certain information regarding the beneficial ownership of the Company’s Securities by each person or group that is known by the Company to be the beneficial owner of more than five percent of its outstanding Securities, each director of the Company, each executive officer, and all directors and executive officers of the Company as a group as of March 31, 2008. Unless otherwise indicated, the company believes that the persons named in the table below, based on information furnished by such owners, have sole voting and investment power with respect to the Common Stock beneficially owned by them, where applicable.

Under securities laws, a person is considered to be the beneficial owner of securities owned by him (or certain persons whose ownership is attributed to him) and that can be acquired by him within 60 days from the date of this Form 10-K filing, including upon the exercise of options, warrants or convertible securities. The Company determined a beneficial owner’s percentage ownership by assuming that options, warrants or convertible securities that are held by him, but not those held by any other person, and which are exercisable within 60 days of the date of this Form 10-K filing, have been exercised or converted.

The information in the following table is based on 9,547,207 shares of common stock issued and outstanding as of March 31, 2008.

Title of Class	Name and Address Beneficial Owner	Beneficial Ownership			Percent of Class

Common	Dennis R Alexander		3,472,278	(1)		36.12	%
	6564 Smoke Tree Lane
	Scottsdale, Arizona 85253

Common	Larry W. Trapp		320,906	(2)		3.34	%
	c/o 6564 Smoke Tree Lane
	Scottsdale, Arizona 85253

Common	Mike Trapp		2,000	(3)		0.02	%
	c/o 6564 Smoke Tree Lane
	Scottsdale, Arizona 85253

Common	Melvena Alexander**		204,075	(4)		2.12	%
	c/o 6564 Smoke Tree Lane
	Scottsdale, Arizona 85253

Common and Preferred	All Officers and Directors as a Group (**4-Persons)		3,999,259			41.60	%

The following table lists beneficial ownership by non directors or executive officers of the Company, of more than five percent of its outstanding Securities:

Common	Dutchess Private Equities Fund, Ltd.	1,180,854	(5)	12.28	%
	50 Commonwealth Avenue, Suite 2
	Boston, MA 02116.

(a) For all Persons in the preceding tables, and corresponding footnotes below: i) Options, warrants, and preferred stock as or if applicable, are included in calculations as to each person’s beneficial ownership position, and ii) All amounts are calculated on a post split one share for two hundred shares (1:200) reverse stock split, effective on October 8, 2008.

(1) Includes 3,472,278 shares of common stock owned directly by Mr. Dennis Alexander. Of the common shares 2,500 are held by Mr. Alexander’s wife and children. Not reflected are 10,000 shares of common restricted stock under presently exercisable stock options which may be purchased by Mr. Alexander. These options have expired unexercised on February 9, 2009.

(2) Includes 320,906 shares of common stock owned directly by Mr. Larry W. Trapp.

(3) Includes 2,000 shares of common stock owned directly by Mike Trapp.

(4) Includes 204,075 shares owned directly by Mrs. Melvena Alexander.

(5) Includes 1,180,854 shares owned by Dutchess Private Equities Fund, Ltd., a corporation formed under the laws of the Cayman Islands. Douglas Leighton and Michael Novielli are the Directors of Dutchess Private Equities Fund, Ltd. and are former members of the Company’s Board of Directors and, as such, they have voting and dispositive power over the securities beneficially owned by such entity. For further information please see information listed in Form 13-D filed on December 8, 2008.

ITEM 13.

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.

Transactions with Executive Management; Fiscal Year Ended December 31, 2008, December 31, 2007, and December 31, 2006.

Please see “EXECUTIVE COMPENSATION” section of this document related to transactions in addition to those contained in this section including, rights and provisions, grants and bonus, additional consideration and other compensation for the following named executives: Dennis R. Alexander, Chairman, President, and Chief Financial Officer and Director, and Melvena Alexander, Co Treasurer, Comptroller, and Secretary.

Transactions with Former Executive Management, For The Fiscal Years Ended December 31, 2008, December 31, 2007, and December 31, 2006 respectively.

For additional information other than that furnished in this section regarding: Current Officer and Director Dennis R. Alexander, Chairman, President, and CFO, and former Officers and Directors John R. Taylor, President and Director, William E. Merritt, Executive Vice President, General Counsel and Director please see information under Item 10 – “Executive Compensation” and other information contained in Form 10-KSB filed April 14, 2006, incorporated herein by reference; For former Officers and Directors George B. Faulder, former Vice President and Director of the Company and Firecreek Petroleum; and, Gregg Fryett, former CEO and Director of the Company and Firecreek Petroleum, and International Yacht Sales Group, LTD., please see information under Item 10 – “Executive Compensation” and other information contained in Form 10-KSB filed April 12, 2005, incorporated herein by reference.

Contracts

The Company has verbal and month to month contracts with various entities (owned by related parties) to provide accounting, management, and other professional services. The entities, their owners and their amounts are as follows for the fiscal year ended December 31, 2008 listed in Table 1 below, and for the fiscal years ended December 31, 2007, and December 31, 2006 listed in Table 2 below.

Table 1

		Paid		Accrued
Entity	Related Party	2008		2008

Global Media Network USA, Inc. * **	Dennis R. Alexander (1)	$	195,250	$	50,000
Tirion Group, Inc.	Rupert C. Johnson (2)	$	-0-	$	43,000
Melvena Alexander, CPA * ***	Melvena Alexander (3)	$	108,875	$	-0-
DLM Asset Management, Inc.	Dermot McAtamney (4)	$	33,535	$	-0-

*Part of the amounts paid in 2008 for each of the above named Executives were for the unpaid accrual amounts due from 2007.

** For 2008, the contract amounts paid to Global Media Network USA, Inc. were in the aggregate $112,500. An additional $82,750 was paid against prior year accruals.

*** For 2008, the contract amounts paid to Melvena Alexander CPA were in the aggregate $65,000. An additional $43,875 was paid against prior year accruals.

(1)	Dennis R. Alexander, Chairman, CEO, and CFO, and is a shareholder of the Company.

(2)	Rupert C. Johnson, a Director through June 9, 2008, and a Co- shareholder of the Company.

(3)	Melvena Alexander, Secretary, Co Treasurer, Secretary and Comptroller, and is a shareholder of the Company.

(4)	Dermot McAtamney, a Director, Executive Vice President, Co Treasurer through June 9, 2008, and is a shareholder of the Company.

Table 2

		Paid						Accrued
Entity	Related Party	2007			2006			2007			2006

Global Media Network USA, Inc.	Dennis R. Alexander (1)		$	89,750		$	138,000		$	120,250		$	30,000
Tirion Group, Inc.	Rupert C. Johnson (2)			7,000			50,000			43,000			20,000
Melvena Alexander, CPA	Melvena Alexander (3)		$	59,250		$	86,750		$	43,875		$	13,250
DLM Asset Management, Inc.	Dermot McAtamney (4)			55,200			80,800			3,300			22,500

(1)	Dennis R. Alexander, Chairman and CFO, and is a shareholder of the Company.

(2)	Rupert C. Johnson, a Director through June 9, 2008, and a Co- shareholder of the Company.

(3)	Melvena Alexander, Secretary and Comptroller, and is a shareholder of the Company.

(4)	Dermot McAtamney, a Director, Executive Vice President, Co Treasurer through June 9, 2008, and is a shareholder of the Company.

Related Party Transaction(s) Involving Acquisition and Issuances of Shares both preferred and common to Dennis R. Alexander, c/o the Company’s address at 6564 Smoke Tree Lane, Scottsdale Arizona 85253.

Related Party Transaction(s) Involving Issuance of Shares both preferred and common, promissory notes, and convertible debentures as of December 31, 2007, December 31, 2006, and December 31, 2005 with Dutchess Private Equities Fund, Ltd. (“DPEF”), Douglas Leighton (“Leighton”) and Michael Novielli (“Novielli”, together with DPEF and Leighton, “Dutchess”) each with a business address of 50 Commonwealth Avenue, Suite #2, Boston, MA 02116. Messrs. Leighton and Novielli are the Directors of DPEF.

Information required under this section can be found in previously filed documents:

Note: As reported by Mr. Alexander, the Company’s Chairman, Principle Executive Officer, and CFO, please see information contained in Form 13-D filed December 5, 2008, and in a Current Report on Form 8-K filed December 3, 2008.

Note: As reported by Dutchess please also see information contained in Form 13-D filed December 8, 2008, in a Current Report on Form 8-K filed December 3, 2008, and including information prior contained in Form 13-D filed on January 29, 2008.

1. Current Report on form 8-K filed on January 7, 2008, incorporated herein by reference.

2. Current Report on Form 8-K filed on June 19, 2007, incorporated herein by reference.

3. Current Report on Form 8-K filed on March 29, 2007, incorporated herein by reference.

4. Current Report on Form 8-K filed on July 7, 2006, incorporated herein by reference.

5. Current Report on Form 8-K filed on April 27, 2006, incorporated herein by reference.

6. Current Report on Form 8-K filed on December 16, 2005, incorporated herein by reference.

7. Current Report on Form 8-K filed on November 16, 2005, incorporated herein by reference.

8. Current Report on Form 8-K filed on September 13, 2005, incorporated herein by reference.

Shares, Options, and Warrants Issued During The Fiscal Year Ended December 31, 2006 to Officers, Directors, and Consultants.

Information required under this section can be found in previously filed documents:

1. Current Report on Form 8-K filed on January 12, 2006

2. Current Report on Form 8-K filed on February 3, 2006

3. Current Report on Amended 8-K/A filed on March 17, 2006

4. Post Effective amendments for registration statement filed on April 26, 2006

5. Current Report on Form 8-K filed on December 12, 2006 for earliest date of event on December 7, 2006

6. Current Report on Form 8-K filed on December 13, 2006 for earliest date of event on December 8, 2006

Share Issuance to Current Officer Of The Company

On February 8, 2009, by majority consent of the Board of Directors, the Company approved the following issuances of its restricted common stock, par value $0.001 per share, to the following named officer for services rendered (see also additional information under the heading “Recent Sales of Unregistered Securities” earlier in this report).

Larry W. Trapp c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09	300,000	For services rendered to the Company or FPI	$	18,000

Melvena Alexander c/o 6564 Smoke Tree Lane Scottsdale, Arizona 85253	2/8/09	180,000	For services rendered to the Company or FPI	$	10,800

(*) Issuances are approved, subject to such persons being entirely responsible for their own personal, Federal, State, and or relevant single or multi jurisdictional income taxes, as applicable.

(**) $28,800 of the financing proceeds in the immediately preceding table were used primarily in consideration of services rendered to the Company and/or Firecreek Petroleum, Inc. (“FPI”).

(1)	Mr. Larry W. Trapp, for business and consulting and advisory services; He is a shareholder, an officer, (Executive Vice President, and Co-Treasurer) and director of the Company and Firecreek Petroleum, Inc.

(2)	Melvena Alexander, for day to day operational services and business provisions; Mrs. Alexander is a shareholder, and an officer (Secretary, Comptroller, and Co Treasurer) of the Company.

Salary to Former Officers and Directors

Former Officers and Directors John R. Taylor, President and Director of the Company and Firecreek Petroleum, William E. Merritt, Executive Vice President, General Counsel and Director of the Company and Firecreek Petroleum, and George B. Faulder, a Vice President and Director of the Company and Firecreek Petroleum, all of which are Shareholders of the Company, received salaries in the amount of USD $25,000, USD $ 25,000, and USD $20,000 respectfully, during 2006 (see other related compensation and non compensation stock issuances to John R. Taylor, William E. Merritt, and George B. Faulder listed in this section).

Option Issuances

The following table provides information related to options granted, vesting to our former named executive officers during the fiscal year ended December 31, 2004, in behalf of and exchange agreement with Firecreek Petroleum, Inc effective July 1, 2004. These options have expired as of February 9, 2009. The following table provides information calculated on the recent one share for two hundred share (1:200) reverse stock split effective October 8, 2008. These options however have expired as of February 9, 2009.

Name	Number of Securities Underlying Options Granted (#)a/b/		% of Total Options Granted in Fiscal Year		Exercise or Base Price ($/sh)			Expiration Date

John R. Taylor		10,000	11.76	%		$	140.00	2/9/09
William E. Merritt		10,000	11.76	%		$	140.00	2/9/09
Gregg Fryett		10,000	11.76	%		$	140.00	2/9/09
George B. Faulder		10,000	11.76	%		$	140.00	2/9/09

a/ The market price for the underlying restricted common stock on August 9, 2004, the date of grant, December 31, 2005, December 31, 2006, December 31, 2007 and December 31, 2008 for all grants listed in the table was $20.00, $6.00, $1.70, and $12.00 (calculated on post reverse split price) respectively.

b/ Including those executives listed in the above table, the total number of options vesting in the Fiscal Year 2005 to all officers, consultants, directors, and advisors, either affiliated or non affiliated, was 17,000,000 pre reverse or calculated as 85,000 post reverse split.

The following are excerpts from certain provisions contained in the option agreement with the persons listed above, and include but are not limited to the following:

(1) The date of all agreements set forth in the table above is August 9, 2004, (2) The exercise price for all option agreements is $140.00 per share, calculated on the post reverse split basis, one share for two hundred shares, effective October 8, 2008, (3) The expiration of each of the agreements is four (4) years from the date of Vesting, (4) The Vesting Date is: For and after the expiration of on hundred eighty (180) days following the date of the agreement or February 9, 2005, (5) The Expiration Date for all option agreements is 2/9/2009, and (6) The exercise price of the options is equal to or in excess of the fair market value of the stock on the date of grant.

(7) For all option grants listed in the table above the following provision is provided: If at any time after the date of this Agreement and prior to the expiration of all Exercise Period(s), the Company proposes to file a registration statement to register any Common Stock (other than Common Stock issued with respect to any acquisition or any employee stock option, stock purchase or similar plan) under the Securities Act of 1933, as amended (the “Securities Act”) for sale to the public in an underwritten offering, it will at each such time give prior written notice to the Optionee of its intention to do so (“Notice of Intent”) and, upon the written request of the Optionee made within 30 calendar days after the receipt of any such notice (which request must specify the number of Option Shares Optionee requests) to be included in the registration, the Company will use its best efforts to effect the registration under the Securities Act of the Option Shares which the Company has been so requested to register, provided, however, that if the managing underwriter shall certify in writing that inclusion of all or any of the Option Shares would, in such managing underwriter’s opinion, materially interfere with the proposed distribution and marketing of the Common Stock in respect of which registration was originally to be effected (such writing to state the basis of such opinion and the maximum number of shares which may be distributed without such interference), then the Company may, upon written notice to the Optionee, have the right to exclude from such registration such number of Option Shares which it would otherwise be required to register hereunder as is necessary to reduce the total amount of Common Stock to be so registered to the maximum amount which can be so marketed.

Aggregated Option Exercises in Last Fiscal Year and Fiscal Year-End Option Value

Name	Shares Acquired On Exercise		Value Realized	Number of Securities Underlying Unexercised Options		Value of Unexercised In-the-money Options

John R. Taylor		—	—		10,000	—
William E. Merritt		—	—		10,000	—
Gregg Fryett		—	—		10,000	—
George B. Faulder		—	—		10,000	—

Unsecured, Demand Note Payable to John R. Taylor, President and Director, for loans made to Firecreek Petroleum, Inc. Total for the note is $316,483 at December 31, 2004. The note is current at March 31, 2005, and thereafter reduced to $59,531 at December 31, 2005. Additional loans were incurred in Q1 2006 totaling $15,162, and in Q2 2006 totaling $15,934. The additional loans carry 6% interest rates. Total balance owed including interest at the rate of 6% is $108,027 at December 31, 2006. The note is current at March 31, 2007, 2008, and as of February 5, 2009 has been paid down $51,750. The balance of the note is due on demand.

Unsecured, Demand Note Payable to George B. Faulder IV, former Vice-President and Director, for loans made to Firecreek Petroleum. Total for the note is $59,389 at December 31, 2005. Additional loans were incurred in Q1 2006 totaling $19,189, and in Q2 2006 $3,862. The additional loans carry 6% interest rates. Total balance owed including interest at the rate of 6% is $68,084 at December 31, 2006. The note is current at March 31, 2007, 2008, and 2009. The note is due on demand.

In May 2005, the Company’s wholly-owned subsidiary, Firecreek Petroleum headquartered at 6777 Camp Bowie Blvd S-215, Ft. Worth, TX 76116, became the lessee of office space in Fort Worth, Texas. The lease is for 24 months from June 1, 2005 through May 31, 2007. The offices were closed by Firecreek Petroleum, Inc. approximately March 31, 2006 and were then moved to the Parent Company offices in Scottsdale Arizona. On July 9, 2008, the Company and Firecreek Petroleum, having legally disputed the lease with Hickman Investments, Ltd., entered a Settlement Agreement with Hickman, effective July 1, 2008, to resolve all disputes relating to the Lawsuit (the “Settlement”), which concluded the disputed litigation. For further information please see Current Report on Form 8-K, as amended, filed on July 10, 2008, incorporated herein by reference.

The Chief Executive Officer and shareholder of the Company provided corporate office space through 2007 and 2008 at no charge. There is no further agreement in place to pay for the premises. At December 31, 2008 through March 31, 2009 the premises continue to be provided free of charge.

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

The Audit Committee has adopted a policy regarding the retention of the independent auditors that requires pre-approval of all services by the Audit Committee or the Chairman of the Audit Committee. When services are pre-approved by the Chairman of the Audit Committee, notice of such approvals is given simultaneously to the other members of the Audit Committee or board of directors if Audit Committee is represented by only one member.

The Audit Committee has reviewed and discussed the fees paid to Donahue Associates for the reports covering fiscal 2008 and 2007 for audit, audit-related, tax and other services.

The Audit Committee has reviewed and discussed the audited financial statements with the Company’s management; and discussed with Donahue Associates, L.L.C. independent auditors for the Company, the matters required to be discussed by Statement on Auditing Standards No. 61, Communication with Audit Committees, as amended.

The aggregate fees billed for the fiscal year ended December 31, 2008 for professional services rendered by Donahue Associates, L.L.C. for the audit of the Company’s financial statements were $11,000 paid for in fiscal 2009.

The fees for the fiscal year ended December 31, 2007 were $22,500 paid for in fiscal 2008. For quarterly review of interim financial statements filed on Form 10-QSB for fiscal 2008 and 2007, $6,000 and, $6,500 respectively, were paid.

Audit-Related Fees

Donahue Associates, L.L.C. did not bill us for any assurance or related services that were related to the performance of the audit of the financial statements.

Tax Fees

Since December 22, 2003 Donahue Associates has not provided any professional services for tax compliance, tax advice and tax planning with the exception of consolidated tax returns for 2008 and 2007which were $450 and $450, respectively.

Other Fees

No other fees were paid to Donahue Associates, L.L.C.

PART IV

ITEM 15. Exhibits, Financial Statement Schedules

Exhibit No.		Description

2.1		Agreement for the Exchange of Common Stock, dated December 12, 2003 (relating to the acquisition of International Group Holdings, Inc.) (filed as exhibit 2.1 to the Current Report on Form 8-K dated December 1, 2003, filed December 15, 2003 and incorporated herein by reference).

2.2		Agreement for the Exchange of Common Stock, dated June 29, 2004 (relating to acquisition of Firecreek Petroleum, Inc.) (filed as exhibit 2.1 to Current Report on form 8-K dated June 24, 2004, filed July 15, 2004 and incorporated herein by reference).

3.1		Articles of Amendment to Articles of Incorporation of EGPI Firecreek, Inc. (filed as Exhibit 99.1 to Current Report on Form 8-K dated Feb. 15, 2005, filed February 22, 2005 and incorporated herein by reference). *

3.2		Correction of Articles of Amendment to Articles of Incorporation of EGPI Firecreek Inc., filed with the Nevada Secretary of State on May 12, 2005.

3.3		Amended By-Laws of Registrant, dated July 1, 2004 (filed as exhibit 2.2 to Current Report on Form 8-K dated June 4, 2004, filed July 15, 2004, and incorporated herein by reference).

5.1		Consent of Gersten, Savage, LLP (filed as Exhibit 5.1 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.1		Securities Purchase Agreement dated May 18, 2005, between the Company and Tirion Group, Inc. (filed as an Exhibit to Current Report on Form 8-K dated May 26, 2005 and incorporated herein by reference).

10.2		Registration Rights Agreement dated May 18, 2005, between the Company and Tirion Group, Inc. (filed as an Exhibit to Current Report on Form 8-K dated May 26, 2005 and incorporated by reference).

10.3		Intellectual Property Security Agreement dated May 2, 2005, by and between the Company and AJW Partners and its affiliates (filed as an Exhibit on Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.4		Guaranty and Pledge Agreement dated May 2, 2005, between the Company, Greg Fryett, CEO of the Company, and AJW Partners and its affiliates (filed as an Exhibit to Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.5		Security Agreement dated May 2, 2005, between the Company and AJW Partners and its affiliates (filed as an Exhibit to Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.6		Form of Callable Secured Convertible Note to AJW Partners LLC, dated May 2, 2005 (filed as an Exhibit to Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.7		Form of Callable Secured Convertible Note to AJW Offshore Limited, dated May 2, 2005 (filed as an Exhibit to Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.8		Form of Callable Secured Convertible Note to AJW Qualified Partners, LLC, dated May 2, 2005 (filed as an Exhibit to Form 10-QSB for quarter ended March 31, 2005 and incorporated herein by reference).

10.9		Form of Callable Secured Convertible Note to New Millenium Capital Partners II, LLC, dated May 2, 2005, (filed as an Exhibit to Form 10-QSB for quarter ended March 31, 2005 and incorporated herein by reference).

10.10		Final Voting Agreement of EGPI Firecreek (filed as exhibit 99.3 to Current Report on Form 8-K dated April 5, 2005, filed April 7, 2005 and incorporated herein by reference).

10.11		Form of Stock Purchase Warrant issued to AJW Partners LLC, effective May 2, 2005, Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.12		Form of Stock Purchase Warrant issued to AJW Offshore Limited, effective May 2, 2005, Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.13		Form of Stock Purchase Warrant issued to AJW Qualified Partners, LLC, effective May 2, 2005, Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.14		Form of Stock Purchase Warrant to New Millenium Capital Partners II, LLC, effective May 2, 2005, Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.15		Fee Protector Agreement, dated June 14, 2005, by and between the Company and DLM Asset Management, Inc. (filed as an Exhibit to the Current Report on Form 8-K/A dated June 20, 2005 and incorporated herein by reference).

10.16		Repurchase Agreement dated May 31, 2005, by and between the Company and AJW Partners (filed as an Exhibit to the Current Report on Form 8-K/A dated June 2, 2005 and incorporated herein by reference).

10.17		Callable Secured Convertible Note, dated May 18, 2005 issued to Tirion Group (filed as an Exhibit to Current Report on Form 8-K dated May 26, 2005 and incorporated herein by reference).

10.18		Stock Purchase Warrant, dated May 18, 2005 issued to Tirion Group (filed as an Exhibit to Current Report on Form 8-K dated May 26, 2005 and incorporated herein by reference).

10.19		Standard Office Lease between the Company and Camp Bowie Centre (filed as an Exhibit to Current Report on Form 8-K dated May 26, 2005 and incorporated herein by reference).

10.20		Securities Purchase Agreement, dated May 2, 2005, between the Company and AJW Partners and its affiliates (filed as an Exhibit to Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.21		Registration Rights Agreement, dated May 2, 2005, between the Company and AJW Partners and Affiliates (filed as an Exhibit to Form 10-QSB for the quarter ended March 31, 2005 and incorporated herein by reference).

10.22		Investment Agreement, dated as of June 28, 2005, by and between the Company and Dutchess Private Equities Fund, II, LP (filed as Exhibit 10.22 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.23		Registration Rights Agreement, dated as of June 28, 2005, by and between the Company and Dutchess Private Equities Fund, II, L.P. (filed as Exhibit 10.23 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.24		Placement Agent Agreement, dated June 28, 2005, by and between the Company, U.S. Euro Securities and Dutchess Equities Fund II L.P. (filed as Exhibit 10.24 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.25		Extension and Amendment of Corporate Advisory Agreement between the Company and Steven Antebi; dated June 13, 2005 (Replaces incorrect exhibit previously filed.) (filed as Exhibit 10.25 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.26		Amendment to Investment Agreement, dated August 23, 2005 by and between the Company and Dutchess Private Equities Fund, II, LP (filed as Exhibit 10.26 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.27		Amendment to Registration Rights Agreement, dated as of August 23, 2005, by and between the Company and Dutchess Private Equities Fund, II, L.P. (filed as Exhibit 10.27 to Registration Statement on Form SB-2/A filed on September 2, 2005 and incorporated herein by reference).

10.28		Extension and Amendment of Certain Provisions of Corporate Advisory Agreement between the Company and Steven Antebi, dated January 30, 2006 (filed as Exhibit 10.1 to Current Report on Form 8-K filed February 3, 2006 and incorporated herein by reference).

10.29		Warrant Certificate containing revised terms of previously issued warrant issued to Steven Antebi, dated July 12, 2005 (filed as Exhibit 10.4 to Current Report on Form 8-K filed on February 3, 2006 and incorporated herein by reference).

10.30		Business Relationship Letter Agreement between the Company, Firecreek, and The Sahara Group (filed on Exhibit 10.30 with the Report on Form 10-KSB filed on April 14, 2006 and incorporated herein by reference).

10.31		Annual Report on Form 10-KSB, filed on April 12, 2005, and incorporated herein by reference.

10.32		Oil and Gas Participation and Rights Agreement (the ”Participation Agreement”) between the Company and Dutchess Private Equities Fund, Ltd. furnished with this Report.

10.33		Advisory Services Agreement between EGPI Firecreek, Inc. and Joseph M. Vasquez, dated February 1, 2009, furnished with this Report.

10.34		Promissory Note Agreement between EGPI Firecreek, Inc. and Dutchess Private Equities Fund, Ltd., furnished with this Report.

10.35		Current Report on Form 8-K, filed on December 3, 2008, incorporated herein by reference

21		Updated List of Subsidiaries

31.1		Certification Pursuant to Section 302

32.1		Certification Pursuant to Section 906

PART F/S FINANCIAL STATEMENTS

The financial statements of the Company as required by Item 310 of Regulation S-B are included in Part II, Item 7 of this report.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on April 15, 2008 on its behalf by the undersigned, thereunto duly authorized.

	EGPI FIRECREEK, INC.
	(Registrant)

	By:	/s/ Dennis R. Alexander
		Dennis R. Alexander
		Chairman, CEO, CFO, and Director

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

Signature	Title	Date

/s/ Dennis R. Alexander	Chairman, CEO, and CFO	April 15, 2009
Dennis R. Alexander	(Chief Financial Officer)

/s/ Larry W. Trapp	Executive Vice President, Co-Treasurer,	April 15, 2009
Larry W. Trapp	and Director

/s/ Mike Trapp	Director	April 15, 2009
Mike Trapp