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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

For the quarterly period ended June 30, 2009

For the transition period from              to             

Commission file number 1-32167

VAALCO Energy, Inc.

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

(713) 623-0801

(Issuer’s telephone number, including area code)

Indicate by check mark whether the registrant (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  x    No  ¨.

Indicate by check mark whether the registrant submitted electronically and posted on its corporate website, if applicable, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or such shorter period that the registrant was required to submit & post such filings).    Yes  ¨    No  ¨.

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

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 July 31, 2009, there were outstanding 58,115,328 shares of common stock, $0.10 par value per share, of the registrant.

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CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

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

See notes to unaudited condensed consolidated financial statements.

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CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS

(unaudited)

(in thousands of dollars, except per share amounts)

See notes to unaudited condensed consolidated financial statements.

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CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

(unaudited)

(in thousands of dollars)

Six Months Ended June 30, 2009

Six Months Ended June 30, 2008

See notes to unaudited condensed consolidated financial statements.

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CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)

(in thousands of dollars)

See notes to unaudited condensed consolidated financial statements.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The condensed 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-K for the year ended December 31, 2008, which also contain 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 oil and gas exploration and development costs.

VAALCO 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 the operator of two production sharing contracts in Gabon, West Africa, conducts exploration activities in one concession in Angola, West Africa and has recently conducted exploration activities on two blocks in the British North Sea. Domestically, the Company has minor interests in the Gulf of Mexico.

VAALCO’s subsidiaries holding interests in Gabon are VAALCO Energy (International), Inc., VAALCO Gabon (Etame), Inc. and VAALCO Production (Gabon), Inc. In Angola VAALCO holds its concession interest in VAALCO Angola (Kwanza), Inc. In Great Britain VAALCO holds its North Sea interests in VAALCO UK (North Sea), Ltd. VAALCO Energy (USA), Inc. holds interests in certain 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, (“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 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. For purposes of computing EPS in a loss quarter, potential common shares are excluded from the computation of weighted average common shares outstanding as their effect is antidilutive. For the three and six month periods ended June 30, 2009, 502,195 and 224,422 potential common shares were excluded, respectively.

Diluted shares consist of the following:

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Options to purchase 2,085,612 and 1,697,640 shares were excluded in the three months and six months ended June 30, 2009, respectively, because they would have been anti-dilutive.

On September 14, 2007, the Board of Directors of the Company adopted a Rights Agreement dated as of September 14, 2007 between the Company and the Registrar and Transfer agent of the Company, as Rights Agent. The Plan created a dividend of one right for each outstanding share of the Company’s Common Stock. The rights are represented by and traded with the Company’s Common Stock. Initially, there will be no separate certificates or market for the rights. The rights do not separate from the Common Stock unless one or both of the following conditions are met: a public announcement that a person has acquired 15% or more of the Common Stock of the Company, or a tender or exchange offer is made which, if completed, would result in the bidder beneficially owning 15% or more of the Common Stock of the Company. The Rights Agreement was voted upon at the 2009 Annual Meeting of Stockholders held on June 3, 2009. Stockholders did not approve the ratification and the Company announced on July 8, 2009 that its Board of Directors has determined to redeem the rights issued under the Company’s stockholder rights plan.

FASB Statement No. 157, Fair Value Measurements – In September 2006, the FASB issued FASB Statement No. 157, Fair Value Measurements (“SFAS 157”), which defines fair value, establishes a framework for measuring fair value and enhances disclosures about instruments carried at fair value, but does not change existing guidance as to whether or not an instrument is carried at fair value. In February 2008, the FASB issued FASB Staff Positions (“FSP”) SFAS 157-2, Effective Date for FASB Statement 157. This FSP permits the delayed application of SFAS 157 for all non-recurring fair value measurements of non-financial assets and non-financial liabilities until fiscal years beginning after November 15, 2008. The Company adopted SFAS 157, as amended, on a prospective basis beginning January 1, 2008, for its financial assets and liabilities and January 1, 2009 for its non-financial assets and liabilities. The adoption of SFAS No. 157 for our nonfinancial assets and liabilities did not have an impact on the Company’s consolidated results of operations or financial condition.

FASB Statement No. 141(R), Business Combinations, and FASB Statement No. 160, Noncontrolling Interests in Consolidated Financial Statements – an amendment of ARB No. 51 – The Company adopted FASB Statement No. 141(R), Business Combinations, which replaced FASB Statement No. 141, Business Combinations, (“SFAS 141(R)”) and FASB Statement No. 160, Noncontrolling Interests in Consolidated Financial Statements – an amendment of ARB No. 51, (“SFAS 160”) on January 1, 2009. These statements significantly change the accounting for business combinations and noncontrolling interests. Among other things, and compared to the predecessor guidance, these statements will require more assets acquired and liabilities assumed to be measured at fair value as of the acquisition date, liabilities related to contingent consideration to be remeasured to fair value each subsequent reporting period, an acquirer in preacquisition periods to expense all acquisition-related costs, and noncontrolling interests in subsidiaries initially to be measured at fair value and classified as a separate component of equity. SFAS 160 changes the accounting and reporting for minority interests, which are re-characterized as noncontrolling interests, and classified as a component of equity. We retroactively applied the presentation and disclosure requirements of SFAS 160 to all periods presented.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Final Rule, Modernization of Oil and Gas Reporting – In December 2008, the SEC released Final Rule, Modernization of Oil and Gas Reporting, to revise the existing Regulation S-K and Regulation S-X reporting requirements to align with current industry practices and technological advances. Further, the SEC on December 31, 2008, published the final rules and interpretations. Many of the revisions are updates to definitions in the existing oil and gas rules to make them consistent with the petroleum resource management system, which is a widely accepted standard for the management of petroleum resources that was developed by several industry organizations. Key revisions include the ability to include nontraditional resources in reserves, the use of new technology for determining reserves, permitting disclosure of probable and possible reserves, and changes to the pricing used to determine reserves in that companies must use a 12-month average price. The average is calculated using the first-day-of-the-month price for each of the 12 months that make up the reporting period. The SEC will require companies to comply with the amended disclosure requirements for registration statements filed after January 1, 2010, and for annual reports for fiscal years ending on or after December 15, 2009. Early adoption is not permitted. The Company is currently assessing the impact that the adoption will have on our disclosures, operating results, financial position and cash flows.

FASB FSPs No. FAS 107-1 and APB 28-1, Interim Disclosures about Fair Value of Financial Instruments – In April 2009, the FASB issued FSP No. FAS 107-1 and APB 28-1, “Interim Disclosures about Fair Value of Financial Instruments” (“FSP No. FAS 107-1”). FSP No. FAS 107-1 amends SFAS No. 107 and Accounting Principles Board (“APB”) Opinion No. 28 to require disclosures about fair value of financial instruments in interim reporting periods for publicly traded companies. We adopted the provisions and applied the presentation and disclosure requirements of this FSP for the period ending June 30, 2009.

The Company’s financial instruments consist primarily of cash, funds in escrow, trade accounts, trade payables and debt. The book values of cash, trade receivables, and trade payables are representative of their respective fair values due to the short-term maturity of these instruments. The book value of the Company’s debt instruments are considered to approximate the fair value, as the interest rates are adjusted based on rates currently in effect.

FASB Statement No. 165, Subsequent Events – In May 2009, the FASB issued SFAS No. 165, “Subsequent Events”. SFAS No. 165 establishes general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. SFAS No. 165 is effective for interim and annual reporting periods ending after June 15, 2009. We adopted SFAS No. 165 for the period ending June 30, 2009. We evaluated subsequent events through August 10, 2009.

FASB Statement No. 167, Amendments to FASB Interpretation No. 46(R) – In June 2009, the FASB issued SFAS No. 167, “Amendments to FASB Interpretation No. 46(R)”. Among other things, SFAS No. 167 amends FIN 46(R) to replace the calculation for determining which entities, if any, have a controlling financial interest in a variable interest entity (“VIE”) from a quantitative based risks and rewards calculation, to a qualitative approach that focuses on identifying which entities have the power to direct the activities of a variable interest entity that most significantly impact the entity’s economic performance and,

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the obligation to absorb losses of the entity or the right to receive benefits from the entity. This standard also requires ongoing assessments as to whether an enterprise is the primary beneficiary of a VIE (previously, reconsideration was only required upon the occurrence of specific events), modifies the presentation of consolidated VIE assets and liabilities, and requires additional disclosures about a company’s involvement in VIEs. SFAS No. 167 will be effective for the Company beginning January 1, 2010. The Company is currently assessing the impact that the adoption will have on its disclosures, operating results, financial position and cash flows.

FASB Statement No. 168, The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles – In June 2009, the FASB issued SFAS No. 168, “The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles”. SFAS No. 168 will become the source of authoritative GAAP recognized by the FASB to be applied by nongovernmental entities. Rules and interpretive releases of the SEC under authority of federal securities laws are also sources of authoritative GAAP for SEC registrants. On the effective date of this Statement, the Codification will supersede all then-existing non-SEC accounting and reporting standards. All other non-grandfathered non-SEC accounting literature not included in the Codification will become non authoritative. This statement is effective for financial statements issued for interim and annual periods ending after September 15, 2009. The Company does not expect the adoption of SFAS No. 168 to have an impact on its disclosures, operating results, financial position and cash flows.

Stock options are granted under the Company’s long-term incentive plan and have an exercise price that may not be less than the fair market value of the underlying shares on the date of grant. In general, stock options granted will become exercisable over a period determined by the Compensation Committee which in the past has been a five year life, with the options vesting over a three year period. In addition, stock options will become exercisable upon a change in control, unless provided otherwise by the Compensation Committee. At June 30, 2009, there were 1,570,896 shares subject to options authorized but not granted.

During the six months ended June 30, 2009, the Company granted no stock options.

For the three months and six months ended June 30, 2009, the Company recognized non-cash compensation expense of $0.4 million and $1.1 million respectively, (or $0.01 and $0.02 per basic and diluted share, respectively), related to stock options. For the three months and six months ended June 30, 2008, the Company recognized non-cash compensation expense of $0.2 million and $0.5 million, respectively (or $0.00 and $0.01 per basic and diluted share, respectively). These amounts were recorded as general and administrative expense. Because the Company does not pay significant United States taxes, no amounts were recorded for tax benefits related to excess stock based compensation deductions.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

A summary of the unit option activity for the six months ended June 30, 2009 is provided below:

The intrinsic value of a stock option is the amount by which the current market value of the underlying stock exceeds the exercise price of the option. As of June 30, 2009, unrecognized compensation costs totaled $1.2 million. The expense is expected to be recognized over a weighted average period of 1.1 years. Stock options vested during the six months ended June 30, 2009 totaled 547,166 options.

In September 2007, the Company entered into an amendment to the Floating Production, Storage and Offloading (“FPSO”) contract for the fields within the Etame Marin block to extend the contract until September 2015. In connection with the charter of the FPSO, the Company as operator of the Etame Marin block guaranteed the charter payments through the same time period. The charter continues for two years beyond that period unless one year’s prior notice is given to the owner of the FPSO. The Company obtained several guarantees from its partners for their share of the charter payment. The Company’s share of the charter payment is 28.1%. The Company believes the need for performance under the charter guarantee is remote. The estimated obligations for the annual charter payment and the Company’s share of the charter payments through the end of the charter are as follows (in thousands):

The Company has recorded a liability of $0.6 million at June 30, 2009 representing the guarantee’s fair value.

In January 2006, the partners elected to extend the Etame Production Sharing Contract related to the Etame Marin block for an additional five-year term commencing July 2006. The extension consists of a three-year and a two-year follow-on term. The first term carries a minimum work obligation of one exploration well for a minimum $7.0 million exploration expenditure commitment ($2.1 million net to the Company). The exploration well commitment was met with the drilling of the North Etame

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prospect in February 2009, which was abandoned after encountering water bearing sands. For the optional two year extension, an additional exploration well is required.

In November 2005, the Company signed a production sharing contract for the Mutamba Iroru block onshore Gabon. The five-year contract awards the Company exploration rights along the central coast of Gabon. During the first three years of the contract the Company is required to drill one exploration well and expend a minimum of $4.0 million. During the optional two-year extension to the contract, the Company is required to acquire specified levels of seismic data, drill one exploration well and expend a minimum of $5.0 million. In February 2009, the Company drilled the exploration well required under the first exploration period after receiving an extension on the first period to complete the well. The well was abandoned after encountering water bearing sands. A second exploration well was drilled in the first quarter of 2009. The well also found water bearing sands and was abandoned. The Company has given notice that it will enter into the second exploration period and is seeking clarification as to whether the second well drilled on the Mutamba Iroru block fulfills the exploration well commitment in the extension.

In November 2006, the Company signed a production sharing contract for Block 5 offshore Angola. The seven-year contract awards the Company exploration rights to 1.4 million acres offshore central Angola. The Company’s working interest in the contract is 40%, plus the Company is required to carry the Angolan National Oil Company, Sonangol P&P, for 10% of the work program. During the first four years of the contract, the consortium is required to acquire and process 1,000 square kilometers of 3-D seismic, drill two exploration wells and expend a minimum of $29.5 million ($14.8 million net to the Company). During the optional three-year extension to the contract, the consortium is required to acquire 600 square kilometers of 3-D seismic data, drill two exploration wells and expend a minimum of $27.2 million ($13.6 million net to the Company). The consortium acquired the 1,175 square kilometers of 3-D data called for in the first exploration period at a cost of $7.5 million ($3.75 million net to the Company) in January 2007. Subsequently, the consortium acquired 524 square kilometers of proprietary 3-D seismic data on the block during the fourth quarter of 2008 at a cost of $6.0 million ($3.0 million net to the Company). The Company has identified several potential exploration well locations and expects the consortium will drill the two exploration wells in 2010.

In January 2008, the Company signed a farm-in agreement for a 25% working interest in Block 48/25c offshore in the British North Sea. The Company is obligated to pay its share of the drilling of one well on the block and a portion of the share of the farminee’s share of the well. The block is located in the Southern Gas Basin and an exploration well began drilling in February 2009. The well was deemed to be non-commercial and was abandoned.

On June 3, 2009, a realignment agreement was signed with a joint venture partner that originally did not participate in an appraisal well and one of the development wells in the Ebouri field, offshore Gabon. Pursuant to the realignment agreement, the joint venture partner paid its proportionate share of capital expenditures for the wells, which reduced the Company’s capital expenditures by $5.7 million. In addition the Company benefits from a $15.0 million ($6.5 million net to the Company) risk

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premium being paid by the partner benefiting the other joint venture partners that originally participated in those two wells. In the quarter ended June 30, 2009 the Company received a $2.0 million payment from the partner and the payment was recorded as other operating income. The remaining proceeds of $4.5 million are expected to be received and recognized as income in the third quarter of 2009.

During the second quarter of 2009, the Gabon Ministry of Finance initiated a withholding tax audit for the Company’s Gabon operations for the period 2005 – 2007. The Company has discovered certain vendors’ invoices were processed without the applicable withholding tax payment being made to the Republic of Gabon. An estimate of the additional tax has been calculated resulting in an accrued liability in the amount of $0.8 million. The results of the audit are expected soon and it is expected the audit report claim will be made in excess of the amount recorded. Only after the report is received and resolved, perhaps through negotiations, will the final amount be known.

On June 24, 2009, the Company announced that its Board of Directors has authorized the repurchase of up to $10 million of the Company’s common stock over the next 12 months. Under the share buyback program, shares of common stock will be purchased on the open market or through privately negotiated transactions from time-to-time. The share buyback program does not obligate the Company to acquire any specific number of shares in any period, and may be modified, suspended, extended or discontinued at any time without prior notice. During the quarter ended June 30, 2009 the Company repurchased 146,354 shares at an average price of $4.15 per share totaling $0.6 million. As of August 10, 2009, the Company repurchased an additional 1,353,646 shares bringing the total amount of shares repurchased in this program to 1,500,000 shares. The average price paid for all shares was $4.14 per share totaling $6.2 million.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The Company’s operations are based in Gabon, Angola, the British North Sea and in the United States. Management reviews and evaluates the operation of each geographic segment separately. The operations of all segments include exploration for and production of hydrocarbons where commercial reserves have been found and developed. Revenues are based on the location of hydrocarbon production. The Company evaluates each segment based on income (loss) from operations. Segment activity for the three months and six months ended June 30, 2009 and 2008 are as follows: (in thousands)

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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 preceded by, followed by or that otherwise include the word “believes,” “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 the volatility of oil and natural gas prices; future production costs; future production quantities; the uncertainty of estimates of oil and natural gas reserves; the impact of competition; the availability and cost of seismic, drilling and other equipment; operating hazards inherent in the exploration for and production of oil and natural gas; difficulties encountered during the exploration for and production of oil and natural gas; difficulties encountered in delivering oil to commercial markets; general economic conditions, including the current economic and financial market crisis; changes in customer demand and producers’ supply; the uncertainty of the Company’s ability to attract capital; compliance with, or the effect of changes in, the foreign governmental regulations regarding the Company’s exploration and production, including those related to climate change; action of operators of the Company’s oil and natural gas properties; political turmoil in the Republic of Gabon; weather conditions; and statements set forth in the “Risk Factors” section included in this report and in the Company’s Form 10-K. 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 oil production sharing contracts in Gabon and Angola, and has non-active interests in two blocks in the British North Sea. In addition, the Company has minor onshore and offshore domestic United States production in the Gulf of Mexico.

The Company’s primary source of revenue is from the Etame Production Sharing Contract related to the Etame Marin block located offshore the Republic of Gabon. The Company produces from the Etame, Avouma, South Tchibala and Ebouri fields on the block. Oil production commenced from the Etame field in September 2002 and from the Avouma and South Tchibala fields in January 2007. Most recently, the Company developed the Ebouri field. Production from the first well in this field began in January 2009. A second development well began producing oil in April 2009. During the first six months of 2009, the Etame, Avouma, South Tchibala and Ebouri fields produced approximately 4.1 million bbls (1.0 million bbls net to the Company).

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Beginning in November 2008, drilling began on the first of two exploration wells, both of which are located within the Etame Marin block. The first of these wells, the North Ebouri, encountered substantial oil-filled Gamba sandstone, proving-up significant additional reserves north of the originally mapped field development outline. The second well, the North Etame prospect, encountered water bearing sands and has been abandoned. Additional drilling prospects have been identified and planning is underway to conduct a multi-well drilling program. Dependent on equipment and rig availability, drilling is expected to commence in late 2009.

Onshore Gabon, the Company has a 100% working interest in the Mutamba Iroru block located near the coast in central Gabon. The Mutamba Iroru block contains approximately 270,000 acres for exploration. The Company acquired aeromagnetic gravity data in 2008 and, together with seismic data acquired from previous operators over the Mutamba Iroru block in 2006 and 2007, drilled two exploration wells on this block in 2009. Both wells encountered water bearing sands and were abandoned. Future plans for this block are being evaluated.

In November 2006, the Company signed a production sharing contract for a 40% working interest in Block 5 offshore Angola. The seven-year contract awards the Company exploration rights to approximately 1.4 million acres along the central coast of Angola. The Company has acquired approximately 1,700 square kilometers of seismic data over a portion of the Block 5 and has been interpreting the seismic data. Assuming consortium agreement on the well objectives and rig availability, the Company expects the first of two planned exploration wells to be drilled as early as first quarter 2010.

In January 2008, the Company signed a farm-in agreement for a 25% working interest in Block 48/25c located in the Southern Gas Basin offshore in the British North Sea. The Company was obligated to pay its share of the drilling of one exploratory well on the block, the drilling of which took place in the first quarter of 2009. A substantial gas column was present but with low permeability and porosity. The well was deemed to be non-commercial and was abandoned.

Impact of the Current Financial and Credit Markets

The financial markets continue to undergo unprecedented disruptions although there are recent measures of improvement in this area. Many financial institutions have liquidity concerns prompting intervention from governments. The Company’s exposure to the disruptions in the financial markets includes the Company’s credit facility, ability to access the capital markets and investments exposure.

The Company’s credit facility extends through October 2009 and may be extended or converted into a term loan, at the Company’s option. If the disruption in the financial markets continues for an extended period of time, replacement of the credit facility may be more expensive.

Current market conditions also elevate concerns with the Company’s cash investments, which at June 30, 2009 totaled $88.4 million. With regard to the Company’s cash investments, the Company invests in bankers acceptances and money market instruments primarily with JPMorgan Chase & Co. The Company’s production in Gabon is purchased by Total Oil Trading SA (“Total”), which the Company believes to be a creditworthy purchaser.

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Oil and gas prices are also volatile as evidenced by the fluctuations seen in the past two years. In periods where commodity prices are relatively low, the Company’s cash flows from operations will be negatively impacted.

CAPITAL RESOURCES AND LIQUIDITY

Cash Flows

Net cash provided by operating activities for the six months ended June 30, 2009 was $20.6 million, as compared to $55.3 million for the six months ended June 30, 2008. The decrease in cash used in operations for the six months ended June 30, 2009 compared to the six months ended June 30, 2008 was primarily due to lower net income due to lower oil prices and due to changes in working capital other than cash which used $9.8 million for the six months ended June 30, 2009, compared to an increase in working capital other than cash of $20.2 million for the six months ended June 30, 2008.

Net cash used in investing activities for the six months ended June 30, 2009 was $54.1 million, compared to net cash used in investing activities for the six months ended June 30, 2008 of $11.4 million. For the six months ended June 30, 2009, the Company incurred $32.0 million in dry hole costs and the remainder was primarily invested in the appraisal well and two development wells in the Ebouri field. For the six months ended June 30, 2008, the Company invested $5.0 million in the Etame Marin block operations for the development of the Ebouri field and completed the drilling of an unsuccessful well in the North Sea at a cost of $6.4 million for the period.

For the six months ended June 30, 2009, cash used in financing activities was $3.6 million, consisting of distributions to a noncontrolling interest owner of $3.0 million and repurchase of shares of $0.6 million. For the six months ended June 30, 2008, cash used by financing activities of $11.8 million consisted primarily of $3.0 million used for distributions to noncontrolling interest holders and repurchase of shares of $8.9 million. In addition, the Company received $0.1 million in proceeds from the issuance of common stock upon the exercise of stock options.

Capital Expenditures

During the six months ended June 30, 2009, the Company incurred $9.3 million of net property and equipment additions (including amounts carried in accounts payable at June 30, 2009), primarily associated with the drilling of the three wells in the Ebouri field (the appraisal well plus the two development wells drilled from the Ebouri platform) totaling $18.4 million. Partially offsetting these equipment additions was a realignment agreement with a joint venture partner that originally did not participate in an appraisal well and one of the development wells in the Ebouri field. Pursuant to the realignment agreement, the joint venture partner paid its proportionate share of capital expenditures for the wells, which reduced the Company’s capital expenditures by $5.7 million. Also partially offsetting the net property and equipment additions were capitalized exploration well costs charged to expense totaling $3.0 million and an equipment reduction of $0.4 million. During the remainder of 2009 in the Etame Marin block, the Company anticipates drilling one exploration well at a cost of $4.5 million and expending an additional $2.0 million for equipment for the 2010 drilling program.

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Liquidity

Historically, the Company’s primary sources of capital have been cash flows from operations, private sales of equity, borrowings and purchase money debt. At June 30, 2009, the Company had a cash balance of $88.4 million. The Company believes that this cash combined with cash flow from operations will be sufficient to fund the Company’s remaining 2009 capital expenditure budget, required debt service payments and additional investments in working capital resulting from potential growth. As operator of the Etame Marin block and Block 5 in Angola, 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.

In June 2005, the Company executed a loan agreement with the International Finance Corporation (“IFC”) for a $30.0 million revolving credit facility which is secured by the assets of the Company’s Gabon subsidiary. The facility extends through October 2009 at which point it can be extended, or converted to a term loan. Under the revolving credit facility, the IFC holds a pledge of the Company’s interest in the Etame Marin block, and a pledge of the shares of VAALCO Gabon (Etame), Inc., the subsidiary which owns the Company’s interest in the Etame Marin block. The IFC also has a security interest in any crude oil sales contract the Company enters into for the sale of crude oil from the Etame Marin block.

Substantially all of the Company’s crude oil and 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 Total. While the loss of Total 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 Texas and offshore in the Gulf of Mexico, which contributed $43,000 to revenues in the six months ended June 30, 2009. 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 as an expense when incurred. The costs of exploratory wells are capitalized 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 as an expense. During the six months ended June 30, 2009, the Company spent $32.0 million on unsuccessful exploration wells, including $20.2 million for two wells in onshore Gabon, $2.7 million for a well in offshore Gabon, and $9.1 million for a well in the British North Sea.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

RESULTS OF OPERATIONS

Three months ended June 30, 2009 compared to three months ended June 30, 2008

Revenues

Total revenues were $32.1 million for the three months ended June 30, 2009 compared to $55.4 million for the comparable period in 2008. The Company sold approximately 544,000 net barrels of oil equivalent at an average price of $59.10 per barrel in the three months ended June 30, 2009. In the three months ended June 30, 2008, the Company sold approximately 464,000 barrels of oil equivalent at an average price of $119.18 per barrel. Crude oil production from the Etame, Avouma, South Tchibala and Ebouri fields averaged 24,000 BOPD compared to approximately 21,500 BOPD in the three months ended June 30, 2008. Crude oil sales are a function of the number and size of crude oil liftings in each quarter from the FPSO and thus crude oil sales do not always coincide with volumes produced in any given quarter.

Operating Costs and Expenses

Total production expenses for the three months ended June 30, 2009 and June 30, 2008 were $4.5 million. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized. Expenses in the three months ended June 30, 2009 were in aggregate the same as in the three months ended June 30, 2008, primarily due to lower fuel costs offset by the increase in oil sales volumes.

Exploration expense was $13.5 million for the three months ended June 30, 2009 compared to $1.3 million in the comparable period in 2008. For the three months ended June 30, 2009, exploration expense consisted primarily of dry hole costs totaling $12.1 million. The dry hole costs included $6.7 million for a well in the British North Sea, $5.0 million for two wells in onshore Gabon and $0.3 million for a well in offshore Gabon. Exploration expense for the three months ended June 30, 2008 consisted of aeromagnetic gravity data acquired over the Mutamba Iroru block, onshore Gabon, seismic acquisition and processing costs associated with the Company’s Etame Marin block and seismic processing costs in Angola.

Depreciation, depletion and amortization expenses were $5.6 million in the three months ended June 30, 2009 compared to $5.2 million in the three months ended June 30, 2008. The higher depreciation, depletion and amortization expenses during the three months ended June 30, 2009 compared to the three months ended June 30, 2008 are due to higher oil sales volumes.

General and administrative expenses for the three months ended June 30, 2009 and June 30, 2008 were $3.9 million and $3.6 million, for each period, respectively. Included in the general and administrative expenses for the three months ended June 30, 2009 was an expense for retirement benefits of $1.2 million. Included in the general and administrative expenses for the three months ended June 30, 2008 were non-recurring legal and solicitation costs associated with the Company’s annual meeting. Also during the three months ended June 30, 2009 and June 30, 2008, the Company incurred stock based compensation expense of $0.4 million and $0.2 million, respectively. In both of the three months ended June 30, 2009 and June 30, 2008, the Company benefited from overhead reimbursement associated with production and development operations on the Etame Marin block.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

Other operating income for the period ended June 30, 2009 was $2.0 million attributable to receipt of proceeds from a joint venture partner that originally elected to not participate in two wells drilled in the Ebouri field, offshore Gabon. The partner later elected to participate and paid for their proportionate share of the capital expenditures for the wells. The $2.0 million payment represents a portion of the Company’s share of an agreed risk premium benefiting the other joint venture partners that originally participated in those two wells. The remaining proceeds of $4.5 million are expected to be received and recognized as other operating income in the third quarter of 2009.

Other Income (Expense)

Other income for the three months ended June 30, 2009 and June 30, 2008 were $0.7 million and $0.8 million for each period, respectively. Included in other income for the three months ended June 30, 2009 was a foreign exchange gain of $0.6 million. Interest income received on amounts on deposit was $0.3 million in the three months ended June 30, 2009 compared to $0.8 million in the three months ended June 30, 2008. The decrease in interest income received on amounts on deposit reflects lower interest rates and amounts invested in 2009. Interest expense and financing charges for the IFC loan was $0.1 million for the three months ended June 30, 2009 compared to $0.1 million for the three months ended June 30, 2008, reflecting interest on amounts borrowed on the IFC loan, net of capitalized interest expense.

Income Taxes

Income tax expense amounted to $7.3 million and $26.5 million for the three months ended June 30, 2009 and June 30, 2008, respectively. In the three months ended June 30, 2009 and in the three months ended June 30, 2008, the income taxes were all paid in Gabon. Income taxes in the three months ended June 30, 2009 were lower due to lower oil prices and a lower percentage of oil allocated as profit oil versus cost oil which decreased taxable revenues.

Net Income (Loss)

Net loss for the three months ended June 30, 2009 was $39,000, compared to net income of $15.0 million for the same period in 2008. Lower oil prices partially offset by a higher oil sales volume and the exploration costs incurred for dry hole write-offs contributed to the lower net income in the second quarter of 2009. Net income allocated to noncontrolling interest was $1.6 million and $2.0 million in the three months ended June 30, 2009 and 2008, respectively The noncontrolling interest is associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

Six months ended June 30, 2009 compared to six months ended June 30, 2008

Revenues

Total revenues were $53.4 million for the six months ended June 30, 2009 compared to $97.5 million for the comparable period in 2008. The Company sold approximately 1,047,000 net barrels of oil equivalent at an average price of $50.95 per barrel in the six months ended June 30, 2009. In the six months ended June 30, 2008, the Company sold approximately 910,000 barrels of oil equivalent at an average price of $107.06 per barrel. Crude oil production from the Etame, Avouma, South Tchibala and Ebouri fields averaged 22,700 BOPD compared to approximately 22,300 BOPD in the six months ended June 30, 2008. Crude oil sales are a function of the number and size of crude oil liftings in each quarter from the FPSO and thus crude oil sales do not always coincide with volumes produced in any given quarter.

Operating Costs and Expenses

Total production expenses for the six months ended June 30, 2009 were $10.2 million compared to $8.9 million in the six months ended June 30, 2008. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized. Expenses in the six months ended June 30, 2009 were higher due to increased sales volumes as well as higher FPSO, boat and helicopter costs.

Exploration expense was $34.0 million for the six months ended June 30, 2009 compared to $8.0 million in the comparable period in 2008. Exploration expense for the six months ended June 30, 2009 included $32.0 million of dry hole costs. The dry hole costs included $9.1 million for a well in the British North Sea, $20.2 million for two wells in onshore Gabon and $2.7 million for a well in offshore Gabon. Exploration expense for the six months ended June 30, 2008 included $6.4 million of dry hole costs associated with a well drilled by the Company in the British North Sea. Also included in exploration expense were aeromagnetic gravity data acquired over the Mutamba Iroru block, onshore Gabon, and seismic costs associated with the Company’s Etame Marin block and Angola.

Depreciation, depletion and amortization expenses were $11.3 million in the six months ended June 30, 2009 compared to $10.2 million in the six months ended June 30, 2008. The higher depreciation, depletion and amortization expenses during the six months ended June 30, 2009 compared to the six months ended June 30, 2008 was due to higher volumes of oil sold.

General and administrative expenses for the six months ended June 30, 2009 and June 30, 2008 were $3.9 million and $5.6 million for each period, respectively. Included in the general and administrative expenses for the six months ended June 30, 2009 was an expense for retirement benefits of $1.2 million which was partially offset by a retroactive compensation adjustment of $0.9 million that benefited the Company by charging the adjustment to the Gabon partners. Included in the general and administrative expenses for the six months ended June 30, 2008 were non-recurring legal and solicitation costs associated with the Company’s annual meeting. During the six months ended June 30, 2009, the Company incurred $1.1 million of stock based compensation compared to $0.5 million incurred in the six months ended June 30, 2008. In both of the six months ended June 30, 2009 and June 30, 2008, the Company benefited from overhead reimbursement associated with production and development operations on the Etame Marin block.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

Other operating income for the period ended June 30, 2009 was $2.0 million attributable to receipt of proceeds from a joint venture partner that originally elected to not participate in two wells drilled in the Ebouri field, offshore Gabon. The partner later elected to participate and paid for their proportionate share of the capital expenditures for the wells. The $2.0 million payment represents a portion of the Company’s share of an agreed risk premium benefiting the other joint venture partners that originally participated in those two wells. The remaining proceeds of $4.5 million are expected to be received and recognized as other operating income in the third quarter of 2009.

Other Income (Expense)

Other income for the six months ended June 30, 2009 and June 30, 2008 were $1.5 million and $0.9 million for each period, respectively. The higher other income recorded in the six months ended June 30, 2009 compared to the same period in 2008 was primarily due to a foreign exchange gain of $1.0 million. Interest income received on amounts on deposit was $0.6 million in the six months ended June 30, 2009 compared to $1.4 million in the six months ended June 30, 2008. The decrease in interest income received on amounts on deposit reflects lower interest rates and amounts invested in 2009. Interest expense and financing charges was $0.1 million for the six months ended June 30, 2009 compared to $0.4 million for the six months ended June 30, 2008 all associated with the Company’s IFC loan, net of capitalized interest expense.

Income Taxes

Income tax expense amounted to $9.7 million and $47.9 million for the six months ended June 30, 2009 and June 30, 2008, respectively. In the six months ended June 30, 2009 and 2008, the income taxes were all paid in Gabon. Income taxes in the six months ended June 30, 2009 were lower due to lower oil prices and a lower percentage of oil allocated as profit oil versus cost oil which decreased taxable revenues.

Net Income (Loss)

Net loss for the six months ended June 30, 2009 was $12.0 million, compared to net income of $17.8 million for the same period in 2008. Lower oil prices partially offset by a higher oil sales volume and the exploration costs incurred for dry hole write-offs contributed to the net loss in the six months ended June 30, 2009. Net income allocated to noncontrolling interest was $2.3 million and $3.0 million in the six months ended June 30, 2009 and 2008, respectively The noncontrolling interest is associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

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 does not presently have any active hedges in place, but may do so in the future.

The Company maintains disclosure controls and procedures that are designed to provide reasonable assurance that information required to be disclosed by the Company in the reports it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to the Company’s management, including the Chief Executive Officer and Chief Financial Officer to allow timely decisions regarding required disclosure. 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.

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PART II. OTHER INFORMATION

With the exception of one risk factor, we have no material changes to the disclosure on this matter in our annual report on Form 10-K for the year ended December 31, 2008. The last paragraph of the risk factor concerning control over our foreign investments has been updated and included in the following new risk factor concerning the death of the President of Gabon in June 2009:

The Presidential election in the Republic of Gabon could affect our operations and cashflows.

Almost all of our proven reserves are located offshore of the Republic of Gabon. As of June 30, 2009, we carried an investment of approximately $136.1 million (prior to depreciation, depletion, and amortization) on our balance sheet associated with the Etame, Avouma, South Tchibala and Ebouri fields in Gabon. We have operated in Gabon since 1995 and believe we have good relations with the Gabonese government.

On June 9, 2009 The President of Gabon died and in accordance with the constitution, the President of the Senate became Interim President. Under Gabon’s constitution, no person who is a government employee may run for President. As a result, several ministers, including the energy minister, have resigned to run for President. The Prime Minister was appointed to head the transitional government and to help organize the election. The election has been scheduled to take place on August 30, 2009.

While there is an established constitutional process to provide for free and fair elections, there can be no assurance that the present or future administrations in Gabon, their policies and their regulations will not have an adverse affect on the Company’s operations or cash flows.

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The following table provides information regarding the number of shares of common stock of the Company purchased by the Company during the three months ended June 30, 2009.

Note 1—On June 24, 2009, the Company announced that its Board of Directors has authorized the repurchase of up to $10 million of the Company’s common stock over the next 12 months. Under the share buyback program, shares of common stock will be purchased on the open market or through privately negotiated transactions from time-to-time. The share buyback program does not obligate the Company to acquire any specific number of shares in any period, and may be modified, suspended, extended or discontinued at any time without prior notice.

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At the Annual Meeting of Stockholders held on June 3, 2009, four matters were voted upon:

1. Election of Directors

The Stockholders elected, by a majority vote of shares entitled to vote at the Annual Meeting, two Class II Directors and one Class III Director to serve on the Company’s Board of Directors.

2. Amendment of the Restated Certificate of Incorporation to Declassify the Board of Directors

Approval of the Amendment required the affirmative vote of the holders of at least 66 ²/3% of the outstanding shares of Common Stock. The Stockholders approved the Amendment.

3. Ratification of the Rights Agreement

Ratification of the rights plan required the affirmative vote of at least a majority vote of shares entitled to vote at the Annual Meeting. Stockholders did not approve the ratification.

4. Ratification of Independent Registered Public Accounting Firm

The Stockholders ratified the appointment of Deloitte & Touche LLP as independent auditors of the Company.

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Section 1350 Certificates

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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.

Dated: August 10, 2009

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EXHIBIT INDEX

Exhibits

Articles of Incorporation and Bylaws

Rule 13a-14(a)/15d-14(a) Certifications

Section 1350 Certificates

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