VAALCO ENERGY INC /DE/ - Quarter Report: 2005 September (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

For the quarterly period ended September 30, 2005

For the transition period from              to             

Commission file number 0-20928

VAALCO Energy, Inc.

(Exact name of small business issuer as specified in its charter)

(713) 623-0801

(Issuer’s telephone number, including area code)

Check whether the issuer (1) 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  x    No  ¨.

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x.

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

As of November 4, 2005, there were outstanding 56,874,950 shares of common stock, $0.10 par value per share.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(in thousands of dollars, except number of shares and par value amounts)

See notes to consolidated financial statements.

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STATEMENTS OF CONSOLIDATED OPERATIONS

(Unaudited)

(in thousands of dollars, except per share amounts)

See notes to consolidated financial statements.

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STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)

(in thousands of dollars)

See notes to consolidated financial statements.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

The consolidated financial statements of VAALCO Energy, Inc. and subsidiaries (collectively, “VAALCO” or the “Company”), included herein are unaudited, but include all adjustments consisting of normal recurring accruals which the Company deems necessary for a fair presentation of its financial position, results of operations and cash flows for the interim period. Such results are not necessarily indicative of results to be expected for the full year. These financial statements should be read in conjunction with the financial statements and notes thereto included in the Company’s Form 10-KSB for the year ended December 31, 2004, which also contains a summary of the significant accounting policies followed by the Company in the preparation of its consolidated financial statements. These policies were also followed in preparing the quarterly report included herein. The Company follows the successful efforts method of accounting for its oil and gas exploration and development costs.

VAALCO Energy, Inc., a Delaware corporation, is a Houston-based independent energy company principally engaged in the acquisition, exploration, development and production of crude oil and natural gas. VAALCO owns producing properties and conducts exploration activities as operator of an international consortium in Gabon, West Africa. Domestically, the Company has interests in the Texas Gulf Coast area.

VAALCO’s subsidiaries holding interests in Gabon are VAALCO Energy (International), Inc., VAALCO Gabon (Etame), Inc. and VAALCO Production (Gabon), Inc. VAALCO Energy (USA), Inc. holds interests in properties in the United States.

The Company accounts for earnings per share in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 128 – Earnings per Share, which establishes the requirements for presenting earnings per share (“EPS”). SFAS No. 128 requires the presentation of “basic” and “diluted” EPS on the face of the income statement. Basic EPS is calculated using the average number of shares of common stock outstanding during each period. Diluted EPS assumes the conversion of preferred stock during the period it was outstanding into common stock and the exercise of all stock options and warrants having exercise prices less than the average market price of the common stock using the treasury stock method.

Diluted Shares consist of the following:

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

The Company records the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred by capitalizing it as part of the carrying amount of the long-lived asset. The Company records the systematic accretion and depreciation of future abandonment costs of tangible assets such as platforms, wells, service assets, pipelines, and other facilities. The fair value of the liability for an asset’s retirement obligation is recorded in the period in which it is incurred if a reasonable estimate of the fair value can be made and the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The following table describes changes in our ARO liability during the nine-month periods ended September 30, 2005 and 2004.

Share based payment - In December 2004, the Financial Accounting Standards Board (“FASB”) issued SFAS No. 123(R), Share-Based Payment, which establishes accounting standards for all transactions in which an entity exchanges its equity instruments for goods and services. SFAS No. 123(R) focuses primarily on accounting for transactions with employees, and carries forward without change to prior guidance for share-based payments for transactions with non employees.

SFAS No. 123(R) eliminates the intrinsic value measurement objective in APB Opinion 25 and generally requires the Company to measure the cost of employee services received in exchange for an award of equity instruments based on the fair value of the award on the date of the grant. The standard requires grant date fair value to be estimated using either an option-pricing model which is consistent with the terms of the award or a market observed price, if such a price exists. Such cost must be recognized over the period during which an employee is required to provide service in exchange for the award (which is usually the vesting period). The standard also requires the Company to estimate the number of instruments that will ultimately be issued, rather than accounting for forfeitures as they occur.

The Company is required to apply SFAS No. 123(R) to all awards granted, modified or settled in our first annual reporting period under U.S. GAAP beginning after June 15, 2005 or January 1, 2006. The Company is also required to use either the “modified prospective method” or the “modified retrospective method.” Under the modified prospective method,

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

the Company must recognize compensation cost for all awards granted after the Company adopts the standard and for the unvested portion of previously granted awards that are outstanding on that date.

Under the modified retrospective method, the Company must restate its previously issued financial statements to recognize the amounts the Company previously calculated and reported on a pro forma basis, as if the prior standard had been adopted.

Under both methods, the Company is permitted to use either a straight line or an accelerated method to amortize the cost as an expense for awards with graded vesting. The standard permits and encourages early adoption.

The Company has not yet completed the analysis of the impact of SFAS 123(R). Because of the inexact and subjective nature of deriving non-freely traded employee stock option values, the Company has adopted the disclosure-only provisions of SFAS No. 123 and continues to account for stock-based compensation using the intrinsic value method prescribed in Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees. Accordingly, no compensation cost has been recognized for the Company’s stock-based plans. Had compensation cost for the Company’s stock-based compensation plans been determined based on the fair value at the grant dates for awards under those plans consistent with the optional method prescribed by SFAS No. 123, the Company’s net income and net income per share would have been adjusted to the pro forma amounts indicated below (in thousands, except per share data):

The total stock based employee compensation expense was determined under the fair value based method for all awards, net of related tax effects. The effects of applying SFAS No. 123 in the disclosure may not be indicative of future amounts as additional awards in future years are anticipated.

The valuation of the options awarded in 2003 is based upon a Black-Scholes model assuming expected volatility of 38%, risk-free interest rate of 5.5%, expected life of options of 3 to 5 years, depending upon the award and an expected dividend yield of 0%. The valuation of options awarded in 2004 and 2005 is based on a Black-Scholes model assuming expected volatility of 62%, risk free interest rate of 5.5%, expected life of options of five years and expected dividend yield of 0%.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

SFAS 151, Inventory Costs - In November 2004, the FASB issued SFAS No. 151, Inventory Costs, an amendment of ARB No. 43, Chapter 4, which amends Chapter 4 of ARB No. 43 that deals with inventory pricing. The statement clarifies the accounting for abnormal amounts of idle facility expenses, freight, handling costs, and spoilage. Under previous guidance, paragraph 5 of ARB No. 43, chapter 4, items such as idle facility expense, excessive spoilage, double freight, and rehandling costs might be considered to be so abnormal, under certain circumstances, as to require treatment as current period charges. This statement eliminates the criterion of “so abnormal” and requires that those items be recognized as current period charges. This statement is effective for inventory costs incurred during fiscal years beginning after June 15, 2005, although earlier application is permitted for fiscal years beginning after the date of issuance of this statement. Retroactive application is not permitted. Management is analyzing the requirements of this new statement and believes that its adoption will not have any significant impact on the Company’s financial position, results of operations or cash flows.

SFAS 153, Exchange of Non-Monetary Assets - In December 2004, the FASB issued SFAS No. 153, Exchanges of Nonmonetary Assets, an amendment of APB No. 29. This statement amends Opinion 29 to eliminate the exception for nonmonetary exchanges of similar productive assets and replaces it with a general exception for exchanges of nonmonetary assets that do not have commercial substance. The statement specifies that a nonmonetary exchange has commercial substance if the future cash flows of the entity are expected to change significantly as a result of the exchange. This statement is effective for nonmonetary asset exchanges occurring in fiscal periods beginning after June 15, 2005. Earlier application is permitted for nonmonetary asset exchanges occurring in fiscal periods beginning after the date this statement is issued. Retroactive application is not permitted. Management will analyze the requirements of this new statement if the Company enters into an exchange of non-monetary assets.

FASB Statement No. 19 – On April 4, 2005, the FASB issued FASB Staff Position No. FAS 19-1 (“FSP FAS 19-1”), which addressed a discussion that was ongoing within the oil industry regarding capitalization of costs of drilling exploratory wells. Paragraph 19 of FASB Statement No. 19, Financial Accounting and Reporting by Oil and Gas Producing Companies (“FASB No. 19”), requires costs of drilling exploratory wells to be capitalized pending determination of whether the well has found proved reserves. If the well has found proved reserves, the capitalized costs become part of the entity’s wells, equipment, and facilities; if, however, the well has not found proved reserves, the capitalized costs of drilling the well are expensed. Questions arose in practice about the application of this guidance due to changes in oil and gas exploration processes and lifecycles. The issue was whether there are circumstances that would permit the continued capitalization of exploratory well costs if reserves cannot be classified as proved within one year following the completion of drilling, other than when additional exploration wells are necessary to justify major capital expenditures and those wells are underway or firmly planned for the near future. FSP FAS 19-1 amends FASB No. 19 to allow for the continued capitalization of suspended well costs

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the enterprise is making sufficient progress assessing the reserves and the economic and operating viability of the plan. The issuance of this amendment did not result in an adjustment to the Company suspended well costs. The Company had $6.5 million of suspended well costs associated with exploration wells at Avouma and Ebouri in Gabon at September 30, 2005 and December 31, 2004 being carried as work in progress. In February 2005, the Company received approval to declare the reserves commercial from the Gabon government and in April 2005 the government approved the assignment of a development area. For the Ebouri discovery, the Company acquired new seismic over the discovery in January 2005 and is actively processing and interpreting these data. The Company intends to file for a development area and submit a development plan after the seismic is processed later in 2005 or early 2006.

FASB Statement No. 154 – In May 2005, the FASB issued FASB Statement No. 154, Accounting Changes and Error Corrections (“Statement 154”). Statement 154 requires companies to recognize changes in accounting principle, including changes required by a new accounting pronouncement when the pronouncement does not include specific transition provisions, retrospectively to prior periods’ financial statements. Statement 154 is effective for accounting changes and corrections of errors made in fiscal years beginning after December 15, 2005. The Company does not believe that the adoption of Statement 154 will have a material effect on its financial position or results of operations.

The Company charters a floating production, storage and offloading system (“FPSO”) for use in the Etame field, and as operator of the Etame field, guaranteed the charter payments through September 2010. The Company has agreed to continue the charter of the FPSO for up to two years beyond September 2010, unless one year’s prior notice is given to the owner of the FPSO. The Company obtained guarantees from its partners for each of their shares of the charter payment. The Company’s share of the charter payment is 28.1%.

The estimated obligations for the full charter payment and the Company’s share of the charter payments are as follows (in thousands of dollars):

The Company has recorded a liability of $0.5 million at September 30, 2005 representing the guarantee’s fair value.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

On April 30, 2004, the Company closed the sale of all of its assets associated with Service Contract 6 and Service Contract 14 in the Philippines. Terms of the sale included the assumption by the partners of the Company’s entire share of any abandonment, environmental or other liabilities associated with the Service Contracts. The Company has reclassified earnings to break out the results of discontinued operations for prior periods in its financial statements.

Income from discontinued operations

During the third quarter of 2005, the Company entered into derivative commodity instruments to hedge its exposure to price fluctuations on crude oil production. Under collar arrangements, if the index price rises above the ceiling price, the Company pays the counterparty. If the index price falls below the floor price, the counterparty pays the Company. The index used for hedging the crude prices is Dated Brent.

At September 30, 2005, the Company had 3 open crude oil collar arrangements. The Company has elected not to designate any positions as cash flow hedges for accounting purposes, and accordingly, records the net change in the mark-to-market valuation of these derivative contracts in the consolidated statement of operations.

At September 30, 2005, the Company had a $352,000 derivative liability, which is classified as short-term. The Company had $352,000 unrealized losses for the three months and nine months ended September 30, 2005.

During the three months and nine months ended September 30, 2004, the Company had no outstanding commodity price hedging contracts. The following table reflects a summary of the Company’s hedging positions at September 30, 2005.

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FOR THE THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 2005

(Unaudited)

As of September 30, 2005, the Company had a term loan with the International Finance Corporation (“IFC”), a subsidiary of the World Bank in the amount of $2.0 million. In June 2005, the Company executed a loan agreement for a $30.0 million revolving credit facility secured by the assets of the Company’s Gabon subsidiary. The facility will be utilized to finance a portion of the Avouma and Ebouri development activities. The facility extends through June 2008 at which point it can be extended, or converted to a term loan. It is anticipated that this facility will become effective during the fourth quarter of 2005 after requisite loan registration filings with the Gabon government are completed. This facility will replace the existing term credit facility, which will be repaid.

On March 17, 2005, the holder of the remaining 6,667 shares of preferred stock converted the preferred stock to common stock at the rate of 2,750 shares of common stock per share of preferred stock, resulting in 18,334,250 shares of common stock being issued. In connection with the transaction, the holder exercised warrants to purchase 5,250,000 shares of common stock under a cashless exercise procedure and was issued 4,635,244 shares of common stock. The 614,756 shares which were used to pay the purchase price under the cashless exercise were placed in the treasury. The stock acquired by the conversion of preferred stock and exercise of the warrants was subsequently sold in block sales over the American Stock Exchange. With the completion of the conversion of preferred stock and exercises of warrants the Company has no preferred stock or warrants outstanding.

On February 7, 2005, the holder of warrants to purchase 250,000 shares of common stock exercised the warrants under a cashless exercise procedure and was issued 222,707 shares of common stock. The 27,293 shares which were used to pay the purchase price under the cashless exercise were placed in the treasury.

During the three months and nine months ended September 30, 2005, employees and contractors exercised options to receive 114,166 and 595,799 shares of common stock, respectively, resulting in net proceeds to the Company of $111,000 and $583,000, respectively. During the three months and nine months ended September 30, 2004, employees and contractors exercised options to receive 391,665 and 466,665 shares of common stock, respectively, resulting in net proceeds to the Company of $222,000 and $245,000, respectively.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This report 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 (“Exchange Act”). All statements other than statements of historical fact included in this report (and the exhibits hereto), including without limitation, statements regarding the Company’s financial position and estimated quantities and net present values of reserves, and statements proceed by, followed by or that otherwise include the word “believe,” “expects,” “anticipates,” “intends,” “projects,” “target,” “goal,” “objective,” “should,” or similar expressions or variations of such expressions are forward looking statements. The Company can give no assurances that the assumptions upon which such statements are based will prove to have been correct. Important factors that could cause actual results to differ materially from the Company’s expectations (“Cautionary Statements”) include volatility of oil and gas prices, future production costs, future production quantities, operating hazards, weather, and statements set forth in the “Risk Factors” section included in the Company’s Forms 10-KSB, which are herein incorporated by reference. All subsequent written and oral forward looking statements attributable to the Company or persons acting on its behalf are expressly qualified by the Cautionary Statements.

INTRODUCTION

The Company operates the Etame field on behalf of a consortium of five companies offshore of the Republic of Gabon. The Phase 1 development of the field occurred in 2002 and consisted of completing three wells producing into a 1.1 million barrel FPSO. The Phase 2 development commenced in 2004 and consisted of two wells. The second well of the Phase 2 development (the Etame-6H well) commenced drilling in June 2005 and was completed in July of 2005. Prior to the Etame-6H well, the Company drilled an exploration well south of the recently discovered Avouma which resulted in a dry hole (the “Avouma South” well).

During the nine months ended September 30, 2005, the Etame field produced 5.2 million barrels (1.45 million barrels net to the Company). The Etame field currently produces at approximately 18,500 BOPD (5,200 BOPD net to the Company).

The Company’s results of operations are affected by currency exchange rates. While oil sales are denominated in U.S. dollars, portions of operating costs in Gabon are denominated in local currency. An increase in the exchange rate of the local currency to the dollar will have the effect of increasing operating costs, while a decrease in the exchange rate will reduce operating costs. The Gabon local currency is tied to the Euro, which appreciated substantially against the dollar in 2004. During 2005, the Euro has depreciated approximately 10 percent versus the dollar. In the past, the Company has not entered into any currency hedges to fix or reduce volatility of changes in the exchange rate between the dollar and the Euro, and currently has no plans to do so in the future.

The Company sells its Gabon production to Shell Western Supply and Trading, Limited at spot market prices.

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CAPITAL RESOURCES AND LIQUIDITY

Cash Flows

Net cash provided by operating activities for the nine months ended September 30, 2005 was $34.7 million, as compared to $9.3 million provided by operations for the nine months ended September 30, 2004. Net funds provided by operations in the nine months ended September 30, 2005 included net income of $24.2 million, non-cash depreciation, depletion and amortization of $4.3 million, exploration expense add back of $2.6 million, minority interest add back of $3.0 million and cash used for working capital of $0.8 million. In the nine months ended September 30, 2004, net cash provided by operating activities included net income of $18.3 million, non-cash depreciation, depletion and amortization of $3.4 million, exploration expense add back of $0.2 million, add back of minority interest of $2.2 million and cash used for working capital of $14.8 million.

Net cash used in investing activities for the nine months ended September 30, 2005 was $14.8 million as compared to $12.8 million for the nine months ended September 30, 2004. In the nine months ended September 30, 2005, the Company invested funds to upgrade the gas lift compressor on the FPSO, to drill the Avouma South exploration well and drill the Etame-6H development well, and to begin construction of the Avouma development platform. In the nine months ended September 30, 2004, the Company added to its investment in Gabon by participating in the Ebouri well, which resulted in an oil discovery, and to drill the Etame-5H well.

In the nine months ended September 30, 2005, net cash used in financing activities was $2.2 million, consisting of $1.8 million of debt reduction and $1.0 million in distributions to minority interest, and partially offset by $0.6 million of proceeds from the issuance of common stock. Net cash used in financing activities in the nine months ended September 30, 2004 was $2.4 million, consisting of $2.5 million of debt repayment offset by net proceeds from issuance of common stock of $0.2 million and purchase of treasury shares of $0.1 million.

Capital Expenditures

During the nine months ended September 30, 2005, the Company incurred costs of $10.3 million on activities to upgrade the gas lift compressor on the FPSO, to drill the Avouma South exploration well, for the drilling of the Etame-6H development well and for the cost to begin construction of the Avouma development platform. During the remainder of 2005, the Company anticipates incurring costs for construction on the Avouma platform development project. Total capital expenditures for the remainder of 2005 are anticipated to be approximately $4.0 million.

Historically, the Company’s primary sources of capital have been cash flows from operations, private sales of equity, borrowings and purchase money debt. At September 30, 2005, the Company had cash of $45.3 million. The Company believes that this cash combined with cash flow from operations will be sufficient to fund the Company’s remaining 2005 capital expenditure budget, required debt repayments of $0.5 million and additional investments in

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working capital resulting from potential growth. In addition, the Company has recently negotiated a $30.0 million revolving line of credit with the International Finance Corporation (“IFC”), a subsidiary of the World Bank. It is anticipated that this facility will become available during the fourth quarter of 2005. This facility will replace an existing term credit facility, which has a total of $2.0 million remaining outstanding.

As operator of the Etame field, the Company enters into project related activities on behalf of its working interest partners. The Company generally obtains advances from it partners prior to significant funding commitments.

On September 8, 2002, the Company commenced production from the Etame field offshore Gabon. Through September 30, 2005, total field production sold was 18.2 million barrels (5.1 million barrels net to the Company).

Substantially all of the Company’s crude oil and natural gas is sold at the well head at posted or index prices under short-term contracts. In Gabon, the Company markets its crude oil under an agreement with Shell Western Trading and Supply, Limited. While the loss of Shell as a buyer might have a material adverse effect on the Company in the near term, management believes that the Company would be able to obtain other customers for its crude oil.

Domestically, the Company produces from wells in Brazos County, Frio County, Dimmit County, Texas and the Gulf of Mexico. Domestic production is sold via separate contracts for oil and gas. The Company has access to several alternative buyers for oil and gas sales domestically.

Oil and Gas Exploration Costs

The Company uses the “successful efforts” method of accounting for its oil and gas exploration and development costs. All expenditures related to exploration, with the exception of costs of drilling exploratory wells are charged to expense as incurred. The costs of exploratory wells are capitalized on the balance sheet pending determination of whether commercially producible oil and gas reserves have been discovered. If the determination is made that a well did not encounter potentially economic oil and gas quantities, the well costs are charged to expense.

At September 30, 2005, the Company carried $10.6 million on the balance sheet as work in progress. Of that amount, $6.5 million was associated with exploratory wells for the Company’s share of the costs of the Ebouri No. 1 well and the Avouma No. 1 well. The Ebouri No. 1 and Avouma No. 1 wells resulted in discoveries of oil and gas. The remaining $4.1 million is associated with the cost the Avouma development project.

For offshore exploratory discoveries, it is not unusual to have exploratory well costs remain suspended while additional appraisal and engineering work on the potential oil and gas field is performed and regulatory and government approvals are sought. In Gabon, the government must approve the commerciality of the reserves, assign a development area and approve a formal development plan prior to a field being developed. In February 2005, the Company received approval to declare the Avouma reserves commercial from the Gabon government and in April 2005 the government approved the assignment of a development area. The Company

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subsequently filed a development plan which has been approved by the government and has begun construction of the facilities for the project. In the Ebouri field, the Company acquired new seismic in January 2005 and is actively processing and interpreting these data. The Company intends to file for a development area and submit a development plan after the seismic is processed later in 2005 or early 2006.

Contractual Obligations

The Company has completed all of its commitments to the Gabon government under Etame contract. Beginning in October 2004, the Company entered into the fourth exploration period, which required a gross expenditure for exploration activities of $5.0 million ($1.5 million net to the Company). This commitment was satisfied with the drilling of the Avouma South exploration well in May 2005. The fourth exploration period expires in July 2006. The Company has entered into negotiations with the government for a fifth exploration period, but there can be no assurance that it will be successful in obtaining the extension.

In addition to its lending relationships and obligations, the Company has contractual obligations under operating leases. The table below summarizes these obligations and commitments at September 30, 2005 (in thousands):

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RESULTS OF OPERATIONS

Three months ended September 30, 2005 compared to three months ended September 30, 2004

Revenues

Total revenues were $26.6 million for the three months ended September 30, 2005 compared to $18.3 million for the comparable period in 2004. The Company sold approximately 453,000 barrels of oil equivalent after royalties at an average price of $58.75 in three months ended September 30, 2005. In the three months ended September 30, 2004, the Company sold approximately 447,000 barrels of oil equivalent after royalties at an average price of $40.77 per barrel.

Operating Costs and Expenses

Total production expenses for the three months ended September 30, 2005 were $3.0 million compared to $2.9 million in the three months ended September 30, 2004. The increased expense is primarily due to higher cost for operating the FPSO and for chartering lifting assist vessels. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized.

Exploration expense was $0.1 million for the three months ended September 30, 2005 compared to $0.1 million in the comparable period in 2004. Exploration expense in the three months ended September 30, 2005 included $0.1 million for seismic processing. Exploration expense in the three months ended September 30, 2004 periods was associated with seismic interpretation activity on the Etame block.

Depreciation, depletion and amortization expenses were $1.4 million in the three months ended September 30, 2005 compared to $1.5 million in the three months ended September 30, 2004. The deprecation, depletion and amortization expenses during the three months ended September 30, 2005 reflect the effects of adding proved developed reserves associated with ET-6H well.

General and administrative expenses for the three months ended September 30, 2005 and 2004 were $0.2 million and $0.3 million for each period, respectively. In the three months ended September 30, 2005 and 2004, the Company benefited from overhead reimbursement associated with production and drilling operations on the Etame block.

Other Income (Expense)

Interest income received on amounts on deposit was $0.3 million in the three months ended September 30, 2005 compared to $0.1 in the three months ended September 30, 2004. Interest expense and financing charges for the IFC loan was $0.1 million for both the three months ended September 30, 2005 and 2004.

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Income Taxes

Income taxes amounted to $8.3 million and $3.0 million for the three months ended September 30, 2005 and 2004, respectively. In both periods, the income tax was paid in Gabon. The higher income tax paid in 2005 was due in part to higher oil prices. In addition, the Company pays a higher income tax in Gabon after it recovers the costs it expends to explore for, develop and produce oil in Gabon. The maximum deduction from income taxes of costs exceeded remaining unrecovered costs, and was not fully available in the three months ended September 30, 2005. In the three months ended September 30, 2004 the maximum deduction was available.

Discontinued Operations

Loss from discontinued operations in the Philippines in the three months ended September 30, 2005 was $25,000 compared to a $0.2 million loss in the three months ended September 30, 2004. In the three months ended September 30, 2004, the loss was associated with the sale of the Philippines assets.

Minority Interest

The Company incurred $1.4 million in minority interest charges in the three months ended September 30, 2005. These minority interest charges were associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company. In the three months ended September 30, 2004, minority interest charges of $1.1 million were incurred.

Net Income

Net income for the three months ended September 30, 2005 was $11.9 million, compared to net income of $9.2 million for the same period in 2004. In the three months ended September 30, 2005, the Company experienced higher tax rates than in the three months ended September 30, 2004. In the three months ended September 30, 2004, the Company experienced lower crude oil prices than in the three months ended September 30, 2005.

Nine months ended September 30, 2005 compared to nine months ended September 30, 2004

Revenues

Total revenues were $66.3 million for the nine months ended September 30, 2005 compared to $38.0 million for the same period in 2004. The increase in revenues was due to higher crude oil sales of approximately 1,311,000 barrels of oil equivalent after royalties in 2005 compared to 1,051,000 barrels of oil equivalent after royalties in 2004. Crude oil prices averaged $50.58 per barrel of oil equivalent in 2005 compared to $36.15 in 2004.

Operating Costs and Expenses

Total production expenses for the nine months ended September 30, 2005 were $8.4 million compared to $7.0 million in the nine months ended September 30, 2004. A portion of the increased expense is due to higher cost for operating the FPSO and for chartering lifting assist vessels. Production expenses in 2005 also included $0.3 million of higher costs associated with a domestic payment obligation as compared to 2004.

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Exploration expense was $2.6 million for the nine months ended September 30, 2005 compared to $0.2 million in the comparable period in 2004. Exploration expense in the nine months ended September 30, 2005 included $2.2 million for the Avouma South well, and $0.4 million for seismic acquisition and processing. Exploration expense in the nine months ended September 30, 2004 was associated with seismic interpretation activity on the Etame block.

Depreciation, depletion and amortization expenses were $4.3 million in the nine months ended September 30, 2005 compared to $3.3 million in the nine months ended September 30, 2004. The higher deprecation, depletion and amortization expenses during the nine months ended September 30, 2005 reflect the effects of the increase in amortizable costs due to the addition of the Etame 5H and Etame 6H wells and higher crude oil volumes sold.

General and administrative expenses for the nine months ended September 30, 2005 and 2004 were $0.9 million and $0.5 million, respectively. The Company experienced higher general and administrative reimbursements in 2004 than in 2005 from partners in the Etame concession associated with higher levels of capital expenditures in 2004.

Other Income (Expense)

Interest income of $0.7 million was received from amounts on deposit during the nine months ended September 30, 2005 compared to $0.2 million during the nine months ended September 30, 2004. In the nine months ended September 30, 2005, the Company incurred $0.3 million in interest expense associated with the IFC development loan. Interest expense and financing charges for the IFC loan amounted to $0.4 million in the nine months ended September 30, 2004 The higher interest expense was due to a larger average balance on the loan in 2004.

Income Taxes

Income taxes amounted to $23.1 million and $6.3 million for the nine months ended September 30, 2005 and 2004 respectively. The higher income tax paid in 2005 was due in part to higher oil prices. In addition, the Company pays a higher income tax in Gabon after it recovers the costs it expends to explore for, develop and produce oil in Gabon. The maximum deduction from income taxes of costs exceeded remaining unrecovered costs, and was not fully available in the nine months ended September 30, 2005. In the nine months ended September 30, 2004 the maximum deduction was available. The Company paid $140,000 in alternative minimum taxes in the first half of 2005 which was recorded as a deferred tax asset and $1.5 million in taxes in the Philippines which had previously been reserved and was being carried as taxes payable.

Discontinued operations

The Company incurred a loss on discontinued operations of $16,000 and $141,000 in the nine months ended September 30, 2005 and 2004, respectively. These losses were associated with the sale of the Company’s former Philippines assets.

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Minority Interest

The Company incurred $3.0 million in minority interest charges in the nine months ended September 30, 2005 associated with the VAALCO Energy (International), Inc. subsidiary that is 90.01% owned by the Company. In the second quarter of 2005, $1.0 million of this minority interest charge was distributed to the minority interest owner. Minority interest charges of $2.2 million were incurred during the nine months ended September 30, 2004.

Net Income (Loss)

Net income attributable to common stockholders for the nine months ended September 30, 2005 was $24.2 million, compared to net income attributable to common stockholders of $18.3 million for the same period in 2004. The higher net income in 2005 was due to higher crude oil volumes sold at higher prices, and was partially offset by higher exploration costs.

ITEM 3. QUANTATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company’s results of operations are dependent upon the difference between prices received for its oil and gas production and the costs to find and produce such oil and gas. Oil and gas prices have been and are expected in the future to be volatile and subject to fluctuations based on a number of factors beyond the control of the Company. The Company has entered into hedging arrangements for a portion of its crude oil production (See Footnote 7 – Derivatives and Hedging Arrangements).

ITEM 4. CONTROLS AND PROCEDURES

The Company’s management, including the Company’s principal executive officer and principal financial officer, has evaluated the effectiveness of the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, the Company’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures were effective as of the end of the period covered by this Quarterly Report on Form 10-Q. There were no changes in the Company’s internal controls over financial reporting that occurred during the Company’s last fiscal quarter that have materially affected, or are reasonably likely to materially affect the Company’s internal control over financial reporting.

ITEM 5. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

At the annual meeting of stockholders held on June 8, 2005 the holders of Common shares elected one Class I Director and three Class II Directors. The stockholders also approved the appointment of Deloitte & Touche as auditors of the Company. The votes cast for the Class I director and the Class II directors proposed by the Company’s definitive proxy statement on

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Schedule 14A, out of a total of 56,217,284 shares of Common Stock deemed to be outstanding and entitled to vote at the annual meeting were as follows:

Regarding the proposal to approve the appointment of Deloitte & Touche as the Company’s auditors, 40,755,082 votes were cast for the proposal, 72,030 votes were cast against the proposal and 0 votes abstained from voting.

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PART II. OTHER INFORMATION

ITEM 6. EXHIBITS

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SIGNATURES

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

VAALCO ENERGY, INC.

(Registrant)

Dated: November 4, 2005

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EXHIBIT INDEX

Exhibits

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