10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

x QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2011

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

For the transition period from             to             

Commission file number 1-32167

VAALCO Energy, Inc.

(Exact name of registrant as specified in its charter)

Delaware	76-0274813
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
4600 Post Oak Place Suite 300 Houston, Texas	77027
(Address of principal executive offices)	(Zip code)

(713) 623-0801

(Registrant’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 has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    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.

Large accelerated filer	¨	Accelerated filer	x
Non-accelerated filer	¨	Smaller reporting company	¨

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 October 31, 2011, there were outstanding 57,118,925 shares of common stock, $0.10 par value per share, of the registrant.

VAALCO ENERGY, INC. AND SUBSIDIARIES

Table of Contents

PART I. FINANCIAL INFORMATION
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (unaudited)
Condensed Consolidated Balance Sheets September 30, 2011 and December 31, 2010	3
Condensed Statements of Consolidated Operations Three months and nine months ended September  30, 2011 and 2010	4
Condensed Consolidated Statements of Changes in Equity Nine months ended September 30, 2011 and 2010	5
Condensed Statements of Consolidated Cash Flows Nine months ended September 30, 2011 and 2010	6
Notes to Unaudited Condensed Consolidated Financial Statements	7
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	12
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	21
CONTROLS AND PROCEDURES	21
PART II. OTHER INFORMATION	22
ITEM 1A. RISK FACTORS	22
ITEM 6. EXHIBITS	22

VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

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

	September 30, 2011			December 31, 2010
ASSETS
Current assets:
Cash and cash equivalents	$	112,575		$	81,234
Funds in escrow		991			14,932
Receivables:
Trade		11,144			14,068
Accounts with partners, net of allowance of $4.1 million at Sept. 30, 2011		8,898			16,180
Other		4,547			10,412
Crude oil inventory		5,397			548
Materials and supplies		280			501
Prepayments and other		5,054			1,482
Total current assets		148,886			139,357
Property and equipment - successful efforts method:
Wells, platforms and other		178,405			168,139
Undeveloped acreage		25,304			16,692
Work in progress		13,185			8,812
Equipment and other		3,609			2,634
		220,503			196,277
Accumulated depreciation, depletion and amortization		(118,003	)		(99,457	)
Net property and equipment		102,500			96,820
Other assets:
Deferred tax asset		1,349			1,349
Funds in escrow		10,895			874
Total Assets	$	263,630		$	238,400
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	22,408		$	26,702
Total current liabilities		22,408			26,702
Other liabilities		2,230			2,030
Asset retirement obligations		14,945			13,425
Total Liabilities		39,583			42,157
Commitments and Contingencies (Note 4)
VAALCO Energy, Inc. shareholders’ equity:
Common stock, $0.10 par value, 100,000,000 authorized shares, 63,124,472 and 62,822,805 shares issued with 6,005,547 and 6,005,547 shares in treasury at September 30, 2011 and December 31, 2010, respectively		6,312			6,282
Additional paid-in capital		67,423			64,314
Retained earnings		172,018			146,594
Less treasury stock, at cost		(25,665	)		(25,665	)
Total VAALCO Energy, Inc. shareholders’ equity		220,088			191,525
Noncontrolling interest		3,959			4,718
Total Equity		224,047			196,243
Total Liabilities and Equity	$	263,630		$	238,400

See notes to unaudited condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS

(unaudited)

(in thousands of dollars, except per share amounts)

	Three months ended September 30,						Nine months ended September 30,
	2011			2010			2011			2010
Revenues:
Oil and gas sales	$	37,350		$	32,604		$	142,669		$	96,285
Operating costs and expenses:
Production expenses		4,473			4,815			15,513			15,881
Exploration expense		1,264			695			3,572			2,114
Depreciation, depletion and amortization		5,153			4,542			17,796			12,860
General and administrative expenses		2,580			949			8,055			5,855
Bad debt expenses		4,061			—			4,061			—
Total operating costs and expenses		17,531			11,001			48,997			36,710
Operating income		19,819			21,603			93,672			59,575
Other income (expense):
Interest income		53			26			136			89
Other, net		700			(327	)		1,098			(554	)
Total other income (expense)		753			(301	)		1,234			(465	)
Income before income taxes		20,572			21,302			94,906			59,110
Income tax expense		17,117			7,369			65,046			26,839
Net income		3,455			13,933			29,860			32,271
Less net income attributable to noncontrolling interest		(1,056	)		(1,482	)		(4,436	)		(3,816	)
Net income attributable to VAALCO Energy, Inc.	$	2,399		$	12,451		$	25,424		$	28,455
Basic net income per share attributable to VAALCO Energy, Inc. common shareholders	$	0.04		$	0.22		$	0.45		$	0.50
Diluted net income per share attributable to VAALCO Energy, Inc. common shareholders	$	0.04		$	0.22		$	0.44		$	0.50
Basic weighted shares outstanding		57,072			56,435			57,023			56,428
Diluted weighted shares outstanding		57,878			57,193			57,993			56,923

See notes to unaudited condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(unaudited)

(in thousands of dollars)

Nine Months Ended September 30, 2011	VAALCO Energy, Inc. Shareholders
	Common Stock		Aditional Paid-In Capital		Retained Earnings		Treasury Stock			Noncontrolling Interest			Total
Balance at January 1, 2011	$	6,282	$	64,314	$	146,594	$	(25,665	)	$	4,718		$	196,243
Proceeds from stock issuance		30		1,207		—		—			—			1,237
Stock based compensation		—		1,902		—		—			—			1,902
Net income		—		—		25,424		—			4,436			29,860
Distribution to noncontrolling interest		—		—		—		—			(5,195	)		(5,195	)
Balance at September 30, 2011	$	6,312	$	67,423	$	172,018	$	(25,665	)	$	3,959		$	224,047
	VAALCO Energy, Inc. Shareholders
Nine Months Ended September 30, 2010	Common Stock		Aditional Paid-In Capital		Retained Earnings		Treasury Stock			Noncontrolling Interest			Total
Balance at January 1, 2010	$	6,157	$	57,550	$	109,249	$	(21,515	)	$	5,664		$	157,105
Proceeds from stock issuance		73		2,697		—		(2,603	)		—			167
Stock based compensation		—		1,925		—		(354	)		—			1,571
Net income		—		—		28,455					3,816			32,271
Redemption of rights agreement		—		—		6		—						6
Distribution to noncontrolling interest		—		—		—		—			(4,495	)		(4,495	)
Balance at September 30, 2010	$	6,230	$	62,172	$	137,710	$	(24,472	)	$	4,985		$	186,625

See notes to unaudited condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)

(in thousands of dollars)

	Nine Months Ended September 30,
	2011			2010
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	29,860		$	32,271
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization		17,796			12,860
Unrealized foreign exchange gain		(99	)		(493	)
Dry hole costs (credits)		(36	)		130
Stock based compensation		1,902			1,571
Bad debt provision		4,061			—
Other		4			—
Change in operating assets and liabilities:
Trade receivables		2,924			(12,943	)
Accounts with partners		3,221			15,116
Other receivables		6,275			(6,474	)
Crude oil inventory		(3,342	)		(301	)
Materials and supplies		221			(256	)
Prepayments and other		(3,741	)		(693	)
Accounts payable, accrued liabilities and other liabilities		(4,704	)		(6,358	)
Other long term assets		—			502
Net cash provided by operating activities		54,342			34,932
CASH FLOWS FROM INVESTING ACTIVITIES
Funds in escrow, net		3,920			28
Property and equipment expenditures		(22,963	)		(19,941	)
Net cash used in investing activities		(19,043	)		(19,913	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of common stock		1,237			123
Redemption of rights plan		—			6
Distribution to noncontrolling interest		(5,195	)		(4,495	)
Net cash used in financing activities		(3,958	)		(4,366	)
NET CHANGE IN CASH AND CASH EQUIVALENTS		31,341			10,653
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		81,234			80,570
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	112,575		$	91,223
Supplemental disclosure of cash flow information
Income taxes paid	$	62,399		$	25,938
Supplemental disclosure of non cash transactions
Property and equipment additions incurred during the period but not paid at period end	$	5,945		$	7,671
Receivable from employee for stock option exercise	$	—		$	44

See notes to unaudited condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS AND ACCOUNTING POLICIES

The condensed consolidated financial statements of VAALCO Energy, Inc. and subsidiaries (collectively, “VAALCO” or the “Company”), included herein are unaudited, and 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, 2010, 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 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 operator of consortiums internationally in Gabon and Angola and as a non-operator in the British North Sea. In Gabon and Angola, VAALCO serves as the operator for a group of companies which own working interests in production sharing contracts. Domestically, the Company has interests onshore in Montana, Texas, and Alabama and in the offshore Texas and Louisiana Gulf Coast area.

VAALCO’s subsidiaries include VAALCO Gabon (Etame), Inc., VAALCO Production (Gabon), Inc., VAALCO Angola (Kwanza), Inc., VAALCO UK (North Sea), Ltd., and VAALCO Energy (USA), Inc.

The Company has evaluated subsequent events through November 7, 2011, the date the financial statements were issued.

2. EARNINGS PER SHARE

Basic earnings per share (“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 having exercise prices less than the average market price of the common stock using the treasury stock method.

Diluted shares consist of the following:

	Three months ended				Nine months ended
	September 30, 2011		September 30, 2010		September 30, 2011		September 30, 2010
Basic weighted average common stock issued and outstanding		57,071,870		56,435,297		57,023,472		56,428,344
Dilutive options		806,068		757,593		969,876		494,601
Total dilutive shares		57,877,938		57,192,890		57,993,348		56,922,945

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VAALCO ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Options to purchase 2,490,004 and 2,490,004 shares were excluded in the three months and nine months ended September 30, 2011, respectively, because they would have been anti-dilutive. Options to purchase 1,420,940 and 1,427,606 shares were excluded in the three months and nine months ended September 30, 2010, respectively, because they would have been anti-dilutive.

3. STOCK-BASED COMPENSATION

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. A portion of the stock options granted in March 2011 and 2010 were vested immediately with the others vesting over a two year period. In addition, stock options will become exercisable upon a change in control, unless provided otherwise by the Compensation Committee. At September 30, 2011, there were 31,896 shares subject to options authorized but not granted.

For the three months and nine months ended September 30, 2011, the Company recognized non-cash compensation expense of $0.3 million and $1.9 million, respectively, related to stock options. For the three months and nine months ended September 30, 2010, the Company recognized non-cash compensation expense of $0.2 million and $1.6 million, respectively. These amounts were recorded as general and administrative expense. Because the Company does not pay significant United States federal income taxes, no amounts were recorded for tax benefits related to excess stock based compensation deductions.

A summary of the option activity for the nine months ended September 30, 2011 is provided below:

	Number of Shares Underlying Options (in thousands)			Weighted Average Exercise Price Per Share		Weighted Average Remaining Contractual Term		Aggregate Intrinsic Value (in millions)
Outstanding at beginning of period		4,266		$	5.40		2.64
Granted		1,169			6.97		4.42
Exercised		(302	)		4.12		0.93
Forfeited		(7	)		4.28		—
Outstanding at end of period		5,126		$	5.84		2.42	$	6.55
Exercisable at end of period		4,095		$	5.79		1.99	$	5.65

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VAALCO ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 September 30, 2011, unrecognized compensation costs totaled $1.3 million. The expense is expected to be recognized over a weighted average period of 1.3 years. Stock options vested during the nine months ended September 30, 2011 totaled 1.3 million options.

4. COMMITMENTS AND CONTINGENCIES

Offshore Gabon

In November 2009, the Company negotiated and signed the sixth exploration period extension on the Etame Marin block. The three year extension expires in July 2014. The Company committed to the drilling of two exploration wells and acquiring and processing 150 square kilometers of 3D seismic with a $17.5 million minimum financial commitment ($5.3 million net to the Company). The Company began seismic operations for a short period in November 2010 and resumed seismic activity in October 2011, which upon completion will satisfy the seismic obligation. One of the two required exploratory wells was drilled in the fourth quarter of 2010 with the drilling of the Omangou well, an unsuccessful effort at a cost of $2.6 million, net to the Company.

Onshore Gabon

In October 2010, the Company signed a second exploration period extension for the Mutamba Iroru block which expires in May 2012. The Company is obligated to reprocess 400 square kilometers of 2D seismic and drill one exploration well. An agreement with Total Gabon (“Total”) was completed in August 2010, which established a joint operation on the block beginning when the one year extension was finalized with the Republic of Gabon. Accordingly, Total acquired a 50% working interest in the block effective November 1, 2010. The terms of the agreement provide for Total paying a disproportionate share of the seismic reprocessing costs and the exploration well drilling costs. The seismic reprocessing began in the first quarter of 2011 and the exploration well is expected to be drilled in the first half of 2012 before the expiration of the exploration period.

Angola

In November 2006, the Company signed a production sharing contract for Block 5 offshore Angola. The four year primary contract with an optional three year extension awards the Company exploration rights to 1.4 million acres offshore central Angola. The Company’s working interest is 40%. Additionally, 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 Company was 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). The Company fulfilled its seismic obligation when it acquired 1,175 square kilometers of 3-D seismic data at a cost of $7.5 million ($3.75 million net to the Company) in January 2007 and 524 square kilometers of 3-D seismic data during the fourth quarter of 2008 at a cost of $6.0 million ($3.0 million net to the Company).

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VAALCO ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The government-assigned working interest partner was delinquent paying their share of the costs several times in 2009 and consequently was placed in a default position. By a governmental decree dated December 1, 2010, the former partner was removed from the production sharing contract, and a one year time extension was granted for drilling the two exploration commitment wells. Following the decree, the Company and the government of Angola have been working together to obtain a replacement partner. In the second quarter of 2011, the government informed the Company it was in negotiations with a potential replacement partner. The negotiations with a potential replacement partner continue, and options to amend the two-well commitment are also being discussed with the Angolan government. Because of the uncertainty surrounding the outcome of the discussions with the Angolan government, in the third quarter of 2011, the Company recorded a full allowance of $4.1 million against the accounts receivable from partners for the amounts owed to the Company above its 40% working interest plus the 10% carried interest.

The Company applied for a second time extension in June 2011 as suitable rigs would not be available until after the expiration of the first extension period. The Company has been provided assurances that the extension will be approved; however, the Company can provide no assurances that such an extension will be granted. If the government of Angola were to deny a time extension, the Company may risk forfeiture of its $10.0 million funds in escrow associated with the two-well drilling obligation and may be required to impair its leasehold costs and other investments totaling $11.0 million as of September 30, 2011.

United States

In September 2011, the Company acquired a 65% working interest in approximately 22,000 net acres covering the Middle Bakken and deeper formations in the East Poplar unit and the Northwest Poplar field in Roosevelt County, Montana. The Company is obligated to pay for 100% of the costs to drill three wells by the end of 2012, estimated at $15.0 million, including one well by June 1, 2012.

5. CAPITALIZATION OF EXPLORATORY WELL COSTS

ASC Topic 932 - Extractive Industries provides that an exploration well shall be capitalized as part of the entity’s uncompleted wells pending the determination of whether the well has found proved reserves. Further, an exploration well that discovers oil and gas reserves, which cannot be classified as proved when drilling is completed, shall be capitalized if the well has found a sufficient quantity of reserves to justify its completion as a producing well and the entity is making sufficient progress towards assessing the reserves and the economic and operating viability of the project. If either condition is not met, the exploration well would be assumed to be impaired and its costs would be charged to expense.

In the second and third quarters of 2010, the Company drilled the Southeast Etame No. 1 well with two sidetracks in the Etame Marin block offshore Gabon. The well discovered a five meter sand of oil. The Company and its partners are evaluating development options for this well in conjunction with other potential initiatives in the Etame Marin block. The Company has capitalized $8.0 million for this well in accordance with the criteria in ASC Topic 932.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

6. SEGMENT INFORMATION

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 nine months ended September 30, 2011 and 2010 are as follows: (in thousands)

	Gabon		Angola			North Sea			USA			Corporate and Other			Total
Three months ended September 30,
2011
Revenues	$	36,424	$	—		$	—		$	926		$	—		$	37,350
Income from operations		26,876		(4,452	)		(82	)		(814	)		(1,709	)		19,819
2010
Revenues	$	32,591	$	—		$	—		$	13		$	—		$	32,604
Income from operations		22,300		(516	)		(76	)		(220	)		115			21,603
	Gabon		Angola			North Sea			USA			Corporate and Other			Total
Nine months ended September 30,
2011
Revenues	$	141,691	$	—		$	—		$	978		$	—		$	142,669
Income from operations		107,934		(5,383	)		(280	)		(1,531	)		(7,068	)		93,672
2010
Revenues	$	96,207	$	—		$	—		$	78		$	—		$	96,285
Income from operations		64,965		(1,782	)		(284	)		(209	)		(3,115	)		59,575
	Gabon		Angola			North Sea			USA			Corporate and Other			Total
Total Assets
As of September 30, 2011	$	181,173	$	21,517		$	—		$	26,157		$	34,783		$	263,630
As of December 31, 2010		181,642		14,081			—			3,189			39,488			238,400

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VAALCO ENERGY, INC. AND SUBSIDIARIES

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 preceded by, followed by or that otherwise include the word “believes,” “expects,” “anticipates,” “intends,” “projects,” “target,” “goal,” “objective,” “should,” “estimates,” “predicts,” “budget,” “plans,” “forecast,” “may,” “will” 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; 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; future production costs and quantities; difficulties encountered during the exploration for and production of oil and natural gas; difficulties encountered in delivering oil to commercial markets; potential downgrade of U.S. debt; general economic conditions, including any future economic downturn and the availability of credit; changes in customer demand and producers’ supply; the uncertainty of the Company’s ability to attract capital; currency exchange rates, actions by the governments and events occurring in the countries in which the Company operates; actions by the Company’s venture partners; 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; actions of operators of the Company’s oil and gas properties; labor strikes in the Republic of Gabon; weather conditions and statements set forth in the “Risk Factors” section included in Part II, Item 1A of the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2011 and in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010. 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. In the United States the Company operates properties in the Granite Wash formation in Texas and the Middle Bakken formation in Montana. In July 2011, the Company acquired a second lease consisting of 364 acres in North Texas in the Granite Wash formation. Additionally, in September 2011, the Company acquired a 65% working interest in approximately 22,000 net acres covering the Middle Bakken and deeper formations in the East Poplar unit and the Northwest Poplar field in Roosevelt County, Montana.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

Additionally, the Company has minor interests in Brazos County, Texas producing from the Buda and Georgetown formations. The Company also owns certain minor non-operated interests in the Ship Shoal area of the Gulf of Mexico and in Pickens County, Alabama.

The Company’s primary source of revenue is from the Etame Marin 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, from the Avouma and South Tchibala fields in January 2007, and from the Ebouri field in January 2009. During the first nine months of 2011, the Etame, Avouma, South Tchibala and Ebouri fields produced approximately 6.1 million bbls (1.3 million bbls net to the Company). In November 2009, the Company signed the sixth exploration period extension on the Etame Marin block. The three year extension expires in July 2014. The Company committed to the drilling of two exploration wells, and the acquisition and processing of 150 square kilometers of 3D seismic with a $17.5 million minimum financial commitment ($5.3 million net to the Company). The Company began seismic operations for a short period in November 2010 and resumed seismic activity in October 2011, which upon completion will satisfy the seismic obligation. One of the two required exploration wells was drilled in the fourth quarter of 2010 with the drilling of the Omangou well, an unsuccessful effort at a cost of $2.6 million net to the Company.

In October 2010, the Company signed a second exploration period extension on the Mutamba Iroru block onshore in the Republic of Gabon which expires in May 2012. The Company is obligated to reprocess 400 square kilometers of 2-D seismic and drill one exploration well. An agreement with Total Gabon (“Total”) was completed in August 2010, which established a joint operation on the block beginning when the one year extension was finalized with the Republic of Gabon. Accordingly, Total acquired a 50% working interest in the block effective November 1, 2010. The terms of the agreement provide for Total paying a disproportionate share of the seismic reprocessing costs and the exploration well drilling costs. The seismic reprocessing began in the first quarter of 2011, and the exploration well is expected to be drilled in the first half of 2012 before the expiration of the exploration period.

In November 2006, the Company signed a production sharing contract for Block 5 offshore Angola. The four year primary contract with an optional three year extension awards the Company exploration rights to 1.4 million acres offshore central Angola. The Company’s working interest is 40%. Additionally, 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 Company was 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). The Company fulfilled its seismic obligation when it acquired 1,175 square kilometers of 3-D seismic data at a cost of $7.5 million ($3.75 million net to the Company) in January 2007 and 524 square kilometers of 3-D seismic data during the fourth quarter of 2008 at a cost of $6.0 million ($3.0 million net to the Company).

The government-assigned working interest partner was delinquent paying their share of the costs several times in 2009 and consequently was placed in a default position. By a governmental decree dated December 1, 2010, the former partner was removed from the production sharing contract, and a one year time extension was granted for drilling the two exploration commitment

13

VAALCO ENERGY, INC. AND SUBSIDIARIES

wells. Following the decree, the Company and the government of Angola have been working together to obtain a replacement partner. In the second quarter of 2011, the government informed the Company it was in negotiations with a potential replacement partner. The negotiations with a potential replacement partner continue, and options to amend the two-well commitment are also being discussed with the Angolan government. Because of the uncertainty surrounding the outcome of the discussions with the Angolan government, in the third quarter of 2011, the Company recorded a full allowance of $4.1 million against the accounts receivable from partners for the amounts owed to the Company above its 40% working interest plus the 10% carried interest.

The Company applied for a second time extension in June 2011 as suitable rigs would not be available until after the expiration of the first extension period. The Company has been provided assurances that the extension will be approved; however, the Company can provide no assurances that such an extension will be granted. If the government of Angola were to deny a time extension, the Company may risk forfeiture of its $10.0 million funds in escrow associated with the two-well drilling obligation and may be required to impair its leasehold costs and other investments totaling $11.0 million as of September 30, 2011.

The Company successfully drilled and completed an exploration well on its initial Granite Wash formation lease in Texas during the third quarter of 2011. The well began production in August 2011 and produced approximately 2,000 barrels of condensate and 132,000 mcf of natural gas in the quarter ended September 30, 2011.

The Company is in the planning stages including contracting for drilling rigs for the two properties where it is the operator in Montana. The Company has a 70% working interest in approximately 5,200 acres in Sheridan County, Montana in the Middle Bakken formation and a 65% working interest in approximately 22,000 acres in Roosevelt County, Montana in the Middle Bakken and lower formations.

CAPITAL RESOURCES AND LIQUIDITY

Cash Flows

Net cash provided by operating activities for the nine months ended September 30, 2011 was $54.3 million, as compared to $34.9 million for the nine months ended September 30, 2010. Although net income for the nine months ended September 30, 2011 was comparable to net income in the nine months ended September 30, 2010, non-cash adjustments to net income were $23.6 million and $14.1 million for the nine months ended September 30, 2011 and 2010 respectively. Additionally, changes in working capital other than cash used $0.8 million for the nine months ended September 30, 2011, compared to a usage of $11.4 million for the nine months ended September 30, 2010.

Net cash used in investing activities for the nine months ended September 30, 2011 was $19.0 million, compared to net cash used in investing activities for the nine months ended September 30, 2010 of $19.9 million. For the nine months ended September 30, 2011, the Company paid $23.0 million for capital expenditures, of which $9.4 million was spent to acquire mineral interests in various leases in the Granite Wash formation in Hemphill County, Texas, and the Middle Bakken formation in Sheridan and Roosevelt

14

VAALCO ENERGY, INC. AND SUBSIDIARIES

Counties, Montana, and $10.1 million was spent to drill and complete the first well on the initial Granite Wash lease. The remainder of the funds were primarily spent in the Etame Marin block offshore Gabon for the expansion of the existing production platforms. These expenditures were partially offset by the release of escrowed funds in Gabon of $3.9 million. For the nine months ended September 30, 2010, the Company drilled two development wells and an exploration well, all in the Etame Marin block for $19.9 million.

For the nine months ended September 30, 2011, cash used in financing activities was $4.0 million consisting of distributions to a noncontrolling interest of $5.2 million and the receipt of $1.2 million in proceeds from the issuance of common stock upon the exercise of stock options. For the nine months ended September 30, 2010, cash used in financing activities of $4.4 million consisted of distributions to a noncontrolling interest owner of $4.5 million and the receipt of $0.1 million in proceeds from the issuance of common stock upon the exercise of stock options.

Capital Expenditures

During the nine months ended September 30, 2011, the Company incurred $24.2 million of net property and equipment additions, primarily associated with the $9.4 million acquisition of various mineral interests in the Granite Wash formation of Hemphill County, Texas and the Middle Bakken formation in Sheridan and Roosevelt Counties, Montana, and the $10.1 million drilling expenditure for the initial well in the Granite Wash formation lease in North Texas. Of the remaining $4.7 million, $4.3 million was incurred on expansion projects for various production platforms offshore Gabon.

During the remainder of 2011, the Company anticipates its share of capital expenditures will be approximately $6.0 million for platform modifications and other capital activity offshore Gabon and $11.0 million for drilling a second Granite Wash formation well in Texas and a well in the Poplar Dome unit in Montana.

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 exploration wells are charged as an expense when incurred. The costs of exploration 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. For the nine months ended September 30, 2011, exploration expense was $3.6 million, which was primarily comprised of $2.0 million spent in North America, $0.5 million offshore Gabon, $0.4 million onshore Gabon, $0.5 million in Angola and $0.3 million in the United Kingdom. For the nine months ended September 30, 2010, exploration expense was $2.1 million which included seismic reprocessing costs in Angola of $0.7 million and seismic reprocessing and other exploration expense in Gabon totaling $1.1 million.

15

VAALCO ENERGY, INC. AND SUBSIDIARIES

Liquidity

The Company’s primary source of capital has been cash flows from operations. At September 30, 2011, the Company had unrestricted cash of $112.6 million. The Company believes that this cash combined with cash flow from operations will be sufficient to fund the Company’s remaining 2011 and 2012 capital expenditure budget and additional investments in working capital resulting from potential growth. As operator of the Etame Marin and Mutamba Iroru blocks in Gabon, Block 5 in Angola, and the two Middle Bakken formation properties in Montana, the Company enters into project related activities on behalf of its working interest partners. The Company generally obtains advances from its partners prior to significant funding commitments.

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 Mercuria Trading NV. While the loss of Mercuria Trading NV 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 in Gabon.

Domestically, the Company markets its oil condensate and natural gas under arrangements with Cokinos Energy and Eagle Rock Field Services, LP, respectively. While the loss of Cokinos Energy or Eagle Rock Field Services, LP as buyers 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 oil condensate and gas in the United States. The Company has access to several alternative buyers for oil and gas sales domestically.

16

VAALCO ENERGY, INC. AND SUBSIDIARIES

RESULTS OF OPERATIONS

Three months ended September 30, 2011 compared to three months ended September 30, 2010

Revenues

Total revenues were $37.4 million for the three months ended September 30, 2011 compared to $32.6 million for the comparable period in 2010. The Company sold approximately 324,000 net barrels of oil equivalent at an average price of $112.85 per barrel in the three months ended September 30, 2011. In the three months ended September 30, 2010, the Company sold approximately 429,000 barrels of oil equivalent at an average price of $76.17 per barrel. The lower sales volume is due to two liftings conducted in the quarter ended September 30, 2011 compared to three liftings conducted in the quarter ended September 30, 2010. Crude oil production from the Etame, Avouma, South Tchibala and Ebouri fields averaged approximately 21,500 BOPD compared to approximately 20,600 BOPD in the three months ended September 30, 2010. The production increase in the three months ended September 30, 2011 was due primarily to offshore Gabon development wells drilled in late 2010. 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.

Domestically, the Company sold approximately 137,000 net mcf of gas at an average price of $5.62 in the three months ended September 30, 2011. The Company sold 2,000 net mcf of gas at an average price of $2.72 in the three months ended September 30, 2010.

Operating Costs and Expenses

Total production expenses for the three months ended September 30, 2011 were $4.5 million compared to $4.8 million for the three months ended September 30, 2010. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized. For the three months ended September 30, 2011, production expenses of $3.0 million were capitalized, as compared to $0.3 million in the same period in 2010. This resulted in lower production expenses in the three months ended September 30, 2011, which were partly offset by higher expenses for Domestic Market Obligation (“DMO”) to the Republic of Gabon. DMO expense of $2.9 million was recorded in the three months ended September 30, 2011, as compared to $0.8 million in the three months ended September 30, 2010.

Exploration expense was $1.3 million for the three months ended September 30, 2011 compared to $0.7 million for the comparable period in 2010. For the three months ended September 30, 2011, exploration expense consisted primarily of $0.6 million for exploration activities in North America, $0.4 million for exploration activities offshore Gabon, and $0.2 million for exploration activities in Angola. Exploration expense for the three months ended September 30, 2010 consisted primarily of exploration activities of $0.2 million offshore Gabon, seismic reprocessing costs of $0.2 million in Angola, and prior year dry hole costs for withholding taxes at the Mutamba Iroru block of $0.2 million.

17

VAALCO ENERGY, INC. AND SUBSIDIARIES

Depreciation, depletion and amortization expenses were $5.2 million in the three months ended September 30, 2011 compared to $4.5 million in the three months ended September 30, 2010. Higher depreciation, depletion and amortization expenses during the three months ended September 30, 2011 compared to the three months ended September 30, 2010 were primarily due to depletion expenses recorded for the first Granite Wash well. In addition, the impact of lower sales volumes from offshore Gabon was partially offset by higher depletion rates for the quarter.

General and administrative expenses for the three months ended September 30, 2011 and 2010 were $2.6 million and $0.9 million, respectively. In each of the three month periods ended September 30, 2011 and 2010, the Company benefited from overhead reimbursement associated with production and development operations on the Etame Marin block. Overhead reimbursement for the three months ended September 30, 2011 was $0.5 million compared to $1.9 million for the same period in 2010.

During the three months ended September 30, 2011, the Company recorded a bad debt provision of $4.1 million related to the uncertainty in collecting its joint venture receivables in Angola.

Other Income (Expense)

Other income for the three months ended September 30, 2011 was $0.7 million compared to an expense of $0.3 million for the three months ended September 30, 2010. The other income recorded in the three months ended September 30, 2011 was primarily due to a foreign exchange gain of $0.4 million, while the expense in 2010 was attributable to foreign exchange losses.

Income Taxes

Income tax expense amounted to $17.1 million and $7.4 million for the three months ended September 30, 2011 and 2010, respectively. In the three months ended September 30, 2011 and 2010, the income taxes were all paid in Gabon. Income tax expense for the three months ended September 30, 2011 was higher due to a 12% increase in the oil revenues and a higher percentage of oil allocated as “profit oil” versus “cost oil” in Gabon. The income taxes the consortium pays the government of Gabon is an allocation of the remaining profit oil production from a specific contract area ranging from 50% to 60% of the oil remaining after deducting the royalty and the cost oil.

Net Income

Net income including the noncontrolling interest for the three months ended September 30, 2011 was $3.5 million, compared to $13.9 million for the same period in 2010. The lower net income for the three month period in 2011 versus 2010 is mainly attributable to higher income taxes paid to the Republic of Gabon. Net income allocated to noncontrolling interest was $1.1 million and $1.5 million in the three months ended September 30, 2011 and 2010, respectively The noncontrolling interest is associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company.

18

VAALCO ENERGY, INC. AND SUBSIDIARIES

Nine months ended September 30, 2011 compared to nine months ended September 30, 2010

Revenues

Total revenues were $142.7 million for the nine months ended September 30, 2011 compared to $96.3 million for the comparable period in 2010. The Company sold approximately 1,262,000 net barrels of oil equivalent at an average price of $112.36 per barrel in the nine months ended September 30, 2011. In the nine months ended September 30, 2010, the Company sold approximately 1,275,000 net barrels of oil equivalent at an average price of $75.69 per barrel. Crude oil production from the Etame, Avouma, South Tchibala and Ebouri fields averaged 22,200 BOPD in the nine months ended September 30, 2011, compared to approximately 20,000 BOPD in the nine months ended September 30, 2010. The production increase in the nine months ended September 30, 2011 was due primarily to production from three development wells drilled in 2010, plus the successful workover of an additional well, all offshore Gabon. 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 nine months ended September 30, 2011 were $15.5 million compared to $15.9 million in the nine months ended September 30, 2010. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized. For the nine months ended September 30, 2011, production expenses of $3.3 million were capitalized, as compared to $0.3 million in the same period in 2010. The lower production expense for the nine months ended September 30, 2011 was primarily due to higher capitalized production expenses partially offset by higher DMO expense. The higher capitalized production expenses were caused by a higher crude oil inventory balance resulting from two liftings conducted in the quarter ended September 30, 2011, compared to three liftings conducted in the quarter ended September 30, 2010.

Exploration expense was $3.6 million for the nine months ended September 30, 2011 compared to $2.1 million for the comparable period in 2010. Exploration expense for the nine months ended September 30, 2011 included $2.0 million exploration expenditures for North America, $0.4 million onshore Gabon, $0.5 million offshore Gabon, $0.5 million in Angola and $0.3 million in the United Kingdom. Exploration expense for the nine months ended September 30, 2010 included seismic reprocessing costs in Angola of $0.5 million, seismic reprocessing and site survey work on the Etame Marin block totaling $0.4 million and onshore Gabon exploration expense of $0.6 million, which included $0.4 million dry hole costs associated with the two 2009 unsuccessful exploration wells.

Depreciation, depletion and amortization expenses were $17.8 million for the nine months ended September 30, 2011 compared to $12.9 million for the nine months ended September 30, 2010. The higher depreciation, depletion and amortization expense during the nine months ended September 30, 2011 compared to the nine months ended September 30, 2010 was primarily due to higher depletion rates in Gabon and the first production in the United States from the Granite Wash formation in Texas.

19

VAALCO ENERGY, INC. AND SUBSIDIARIES

General and administrative expenses for the nine months ended September 30, 2011 and 2010 were $8.1 million and $5.9 million, respectively. In both of the nine months ended September 30, 2011 and 2010, the Company benefited from overhead reimbursement associated with production and development operations on the Etame Marin block. Overhead reimbursement for the nine months ended September 30, 2011 was $1.7 million compared to $4.2 million in the same period in 2010.

During the nine months ended September 30, 2011 the Company recorded a bad debt provision of $4.1 million related to the uncertainty in collecting its joint venture receivables in Angola.

Other Income (Expense)

Other income for the nine months ended September 30, 2011 was $1.2 million compared to expense of $0.5 million for the nine months ended September 30, 2010. The other income recorded in the nine months ended September 30, 2011 was primarily due to a foreign exchange gain of $0.8 million, compared to a foreign exchange loss of $0.6 million for the same period in 2010. Interest income received on amounts on deposit was $0.1 million in each of the nine months ended September 30, 2011 and September 30, 2010.

Income Taxes

Income tax expense amounted to $65.0 million and $26.8 million for the nine months ended September 30, 2011 and 2010, respectively. In the nine months ended September 30, 2011 and 2010, the income taxes were all paid in Gabon. Income tax expense for the nine months ended September 30, 2011 was higher due to a 47% increase in the oil revenues and a higher percentage of oil allocated as “profit oil” versus “cost oil”. The income taxes the consortium pays the government of Gabon is an allocation of the remaining profit oil production from a specific contract area ranging from 50% to 60% of the oil remaining after deducting the royalty and the cost oil.

Net Income

Net income including the noncontrolling interest for the nine months ended September 30, 2011 was $29.9 million, compared to a net income of $32.3 million for the same period in 2010. Higher income taxes paid to the Republic of Gabon partially offset by higher oil prices contributed to the lower net income in the nine months ended September 30, 2011. Net income allocated to noncontrolling interest for the nine months ended September 30, 2011 was $4.4 million as compared to $3.8 million for the nine months ended September 30, 2010. The noncontrolling interest is associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company.

20

VAALCO ENERGY, INC. AND SUBSIDIARIES

ITEM 3. QUANTITATIVE 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 does not presently have any active hedges in place, but may do so in the future.

ITEM 4. CONTROLS AND PROCEDURES

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.

21

PART II. OTHER INFORMATION

ITEM 1A. RISK FACTORS

There have been no material changes to the disclosure on this matter included in Part II, Item 1A of our quarterly report on Form 10-Q for the quarter ended March 31, 2011, and in our annual report on Form 10-K for the year ended December 31, 2010.

ITEM 6. EXHIBITS

(a) Exhibits

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

31.1	Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002.
Section 1350 Certifications
32.1	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act Of 2002.
32.2	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act Of 2002.
Interactive Data Files
101.INS	XBRL Instance Document.*
101.SCH	XBRL Taxonomy Schema Document.*
101.CAL	XBRL Calculation Linkbase Document.
101.DEF	XBRL Definition Linkbase Document.*
101.LAB	XBRL Label Linkbase Document.*
101.PRE	XBRL Presentation Linkbase Document.*

* Pursuant to Rule 406T of Regulation S-T, these interactive data files are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933 or Section 18 of the Securities Exchange Act of 1934 and otherwise are not subject to liability.

22

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)

By	/s/ GREGORY R. HULLINGER
	Gregory R. Hullinger, Chief Financial Officer
	(on behalf of the Registrant and as the principal financial officer)

Dated: November 7, 2011

23

EXHIBIT INDEX

Exhibits

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

31.1	Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002.
Section 1350 Certifications
32.1	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act Of 2002.
32.2	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act Of 2002.
Interactive Data Files
101.INS	XBRL Instance Document.*
101.SCH	XBRL Taxonomy Schema Document.*
101.CAL	XBRL Calculation Linkbase Document.
101.DEF	XBRL Definition Linkbase Document.*
101.LAB	XBRL Label Linkbase Document.*
101.PRE	XBRL Presentation Linkbase Document.*

* Pursuant to Rule 406T of Regulation S-T, these interactive data files are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933 or Section 18 of the Securities Exchange Act of 1934 and otherwise are not subject to liability.

24

EX-31.1

Exhibit 31.1

I, Robert L. Gerry, III, certify that:

(1) I have reviewed this quarterly report on Form 10-Q of VAALCO Energy, Inc.;

(2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

(3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

(4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

(5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date November 7, 2011

/s/Robert L. Gerry, III

Robert L. Gerry

Chief Executive Officer

EX-31.2

Exhibit 31.2

I, Gregory R. Hullinger, certify that:

(1) I have reviewed this quarterly report on Form 10-Q of VAALCO Energy, Inc.;

(2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

(3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

(4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

(5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date November 7, 2011

/s/ Gregory R. Hullinger

Gregory R. Hullinger

Chief Financial Officer

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of VAALCO Energy, Inc. (the “Company”) on Form 10-Q for the quarterly period ended September 30, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert L. Gerry, III, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities and Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: November 7, 2011

/s/ Robert L. Gerry, III

Robert L. Gerry, Chief Executive Officer

EX-32.2

EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of VAALCO Energy, Inc. (the “Company”) on Form 10-Q for the quarterly period ended September 30, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gregory R. Hullinger, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities and Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: November 7, 2011

/s/ Gregory R. Hullinger

Gregory R. Hullinger, Chief Financial Officer

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Condensed Consolidated Balance Sheets (Parenthetical) (USD $) In Millions, except Share data	Sep. 30, 2011	Dec. 31, 2010
Condensed Consolidated Balance Sheets [Abstract]
Accounts with partners, allowance	$ 4.1
Common stock, par value	$ 0.10	$ 0.10
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	63,124,472	62,822,805
Treasury stock, shares	6,005,547	6,005,547

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Condensed Statements Of Consolidated Operations (USD $) In Thousands, except Per Share data	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Revenues:
Oil and gas sales	$ 37,350	$ 32,604	$ 142,669	$ 96,285
Operating costs and expenses:
Production expenses	4,473	4,815	15,513	15,881
Exploration expense	1,264	695	3,572	2,114
Depreciation, depletion and amortization	5,153	4,542	17,796	12,860
General and administrative expenses	2,580	949	8,055	5,855
Bad debt expenses	4,061		4,061
Total operating costs and expenses	17,531	11,001	48,997	36,710
Operating income	19,819	21,603	93,672	59,575
Other income (expense):
Interest income	53	26	136	89
Other, net	700	(327)	1,098	(554)
Total other income (expense)	753	(301)	1,234	(465)
Income before income taxes	20,572	21,302	94,906	59,110
Income tax expense	17,117	7,369	65,046	26,839
Net income	3,455	13,933	29,860	32,271
Less net income attributable to noncontrolling interest	(1,056)	(1,482)	(4,436)	(3,816)
Net income attributable to VAALCO Energy, Inc.	$ 2,399	$ 12,451	$ 25,424	$ 28,455
Basic net income per share attributable to VAALCO Energy, Inc. common shareholders	$ 0.04	$ 0.22	$ 0.45	$ 0.50
Diluted net income per share attributable to VAALCO Energy, Inc. common shareholders	$ 0.04	$ 0.22	$ 0.44	$ 0.50
Basic weighted shares outstanding	57,072	56,435	57,023	56,428
Diluted weighted shares outstanding	57,878	57,193	57,993	56,923

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Document And Entity Information	9 Months Ended
	Sep. 30, 2011	Oct. 31, 2011
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2011
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	Q3
Entity Registrant Name	VAALCO ENERGY INC /DE/
Entity Central Index Key	0000894627
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		57,118,925

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Segment Information

9 Months Ended

Sep. 30, 2011

Segment Information [Abstract]

Segment Information

6. SEGMENT INFORMATION

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 nine months ended September 30, 2011 and 2010 are as follows: (in thousands)

	Gabon		Angola			North Sea			USA			Corporate and Other			Total
Three months ended September 30,
2011
Revenues	$	36,424	$	—		$	—		$	926		$	—		$	37,350
Income from operations		26,876		(4,452	)		(82	)		(814	)		(1,709	)		19,819
2010
Revenues	$	32,591	$	—		$	—		$	13		$	—		$	32,604
Income from operations		22,300		(516	)		(76	)		(220	)		115			21,603
	Gabon		Angola			North Sea			USA			Corporate and Other			Total
Nine months ended September 30,
2011
Revenues	$	141,691	$	—		$	—		$	978		$	—		$	142,669
Income from operations		107,934		(5,383	)		(280	)		(1,531	)		(7,068	)		93,672
2010
Revenues	$	96,207	$	—		$	—		$	78		$	—		$	96,285
Income from operations		64,965		(1,782	)		(284	)		(209	)		(3,115	)		59,575
	Gabon		Angola			North Sea			USA			Corporate and Other			Total
Total Assets
As of September 30, 2011	$	181,173	$	21,517		$	—		$	26,157		$	34,783		$	263,630
As of December 31, 2010		181,642		14,081			—			3,189			39,488			238,400

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Earnings Per Share

9 Months Ended

Sep. 30, 2011

Earnings Per Share [Abstract]

Earnings Per Share

2. EARNINGS PER SHARE

Basic earnings per share ("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 having exercise prices less than the average market price of the common stock using the treasury stock method.

Diluted shares consist of the following:

	Three months ended				Nine months ended
	September 30, 2011		September 30, 2010		September 30, 2011		September 30, 2010
Basic weighted average common stock issued and outstanding		57,071,870		56,435,297		57,023,472		56,428,344
Dilutive options		806,068		757,593		969,876		494,601
Total dilutive shares		57,877,938		57,192,890		57,993,348		56,922,945

Options to purchase 2,490,004 and 2,490,004 shares were excluded in the three months and nine months ended September 30, 2011, respectively, because they would have been anti-dilutive. Options to purchase 1,420,940 and 1,427,606 shares were excluded in the three months and nine months ended September 30, 2010, respectively, because they would have been anti-dilutive.

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Condensed Statements Of Consolidated Cash Flows (USD $) In Thousands	9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 29,860	$ 32,271
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	17,796	12,860
Unrealized foreign exchange gain	(99)	(493)
Dry hole costs (credits)	(36)	130
Stock based compensation	1,902	1,571
Bad debt provision	4,061
Other	4
Change in operating assets and liabilities:
Trade receivables	2,924	(12,943)
Accounts with partners	3,221	15,116
Other receivables	6,275	(6,474)
Crude oil inventory	(3,342)	(301)
Materials and supplies	221	(256)
Prepayments and other	(3,741)	(693)
Accounts payable, accrued liabilities and other liabilities	(4,704)	(6,358)
Other long term assets		502
Net cash provided by operating activities	54,342	34,932
CASH FLOWS FROM INVESTING ACTIVITIES
Funds in escrow, net	3,920	28
Property and equipment expenditures	(22,963)	(19,941)
Net cash used in investing activities	(19,043)	(19,913)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of common stock	1,237	123
Redemption of rights plan		6
Distribution to noncontrolling interest	(5,195)	(4,495)
Net cash used in financing activities	(3,958)	(4,366)
NET CHANGE IN CASH AND CASH EQUIVALENTS	31,341	10,653
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	81,234	80,570
CASH AND CASH EQUIVALENTS AT END OF PERIOD	112,575	91,223
Supplemental disclosure of cash flow information
Income taxes paid	62,399	25,938
Supplemental disclosure of non cash transactions
Property and equipment additions incurred during the period but not paid at period end	5,945	7,671
Receivable from employee for stock option exercise		$ 44

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Stock-Based Compensation

9 Months Ended

Sep. 30, 2011

Stock-Based Compensation [Abstract]

Stock-Based Compensation

3. STOCK-BASED COMPENSATION

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. A portion of the stock options granted in March 2011 and 2010 were vested immediately with the others vesting over a two year period. In addition, stock options will become exercisable upon a change in control, unless provided otherwise by the Compensation Committee. At September 30, 2011, there were 31,896 shares subject to options authorized but not granted.

For the three months and nine months ended September 30, 2011, the Company recognized non-cash compensation expense of $0.3 million and $1.9 million, respectively, related to stock options. For the three months and nine months ended September 30, 2010, the Company recognized non-cash compensation expense of $0.2 million and $1.6 million, respectively. These amounts were recorded as general and administrative expense. Because the Company does not pay significant United States federal income taxes, no amounts were recorded for tax benefits related to excess stock based compensation deductions.

A summary of the option activity for the nine months ended September 30, 2011 is provided below:

	Number of Shares Underlying Options (in thousands)			Weighted Average Exercise Price Per Share		Weighted Average Remaining Contractual Term		Aggregate Intrinsic Value (in millions)
Outstanding at beginning of period		4,266		$	5.40		2.64
Granted		1,169			6.97		4.42
Exercised		(302	)		4.12		0.93
Forfeited		(7	)		4.28		—
Outstanding at end of period		5,126		$	5.84		2.42	$	6.55
Exercisable at end of period		4,095		$	5.79		1.99	$	5.65

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 September 30, 2011, unrecognized compensation costs totaled $1.3 million. The expense is expected to be recognized over a weighted average period of 1.3 years. Stock options vested during the nine months ended September 30, 2011 totaled 1.3 million options.

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Commitments And Contingencies

9 Months Ended

Sep. 30, 2011

Commitments And Contingencies [Abstract]

Commitments And Contingencies

4. COMMITMENTS AND CONTINGENCIES

Offshore Gabon

In November 2009, the Company negotiated and signed the sixth exploration period extension on the Etame Marin block. The three year extension expires in July 2014. The Company committed to the drilling of two exploration wells and acquiring and processing 150 square kilometers of 3D seismic with a $17.5 million minimum financial commitment ($5.3 million net to the Company). The Company began seismic operations for a short period in November 2010 and resumed seismic activity in October 2011, which upon completion will satisfy the seismic obligation. One of the two required exploratory wells was drilled in the fourth quarter of 2010 with the drilling of the Omangou well, an unsuccessful effort at a cost of $2.6 million, net to the Company.

Onshore Gabon

In October 2010, the Company signed a second exploration period extension for the Mutamba Iroru block which expires in May 2012. The Company is obligated to reprocess 400 square kilometers of 2D seismic and drill one exploration well. An agreement with Total Gabon ("Total") was completed in August 2010, which established a joint operation on the block beginning when the one year extension was finalized with the Republic of Gabon. Accordingly, Total acquired a 50% working interest in the block effective November 1, 2010. The terms of the agreement provide for Total paying a disproportionate share of the seismic reprocessing costs and the exploration well drilling costs. The seismic reprocessing began in the first quarter of 2011 and the exploration well is expected to be drilled in the first half of 2012 before the expiration of the exploration period.

Angola

In November 2006, the Company signed a production sharing contract for Block 5 offshore Angola. The four year primary contract with an optional three year extension awards the Company exploration rights to 1.4 million acres offshore central Angola. The Company's working interest is 40%. Additionally, 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 Company was 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). The Company fulfilled its seismic obligation when it acquired 1,175 square kilometers of 3-D seismic data at a cost of $7.5 million ($3.75 million net to the Company) in January 2007 and 524 square kilometers of 3-D seismic data during the fourth quarter of 2008 at a cost of $6.0 million ($3.0 million net to the Company).

The government-assigned working interest partner was delinquent paying their share of the costs several times in 2009 and consequently was placed in a default position. By a governmental decree dated December 1, 2010, the former partner was removed from the production sharing contract, and a one year time extension was granted for drilling the two exploration commitment wells. Following the decree, the Company and the government of Angola have been working together to obtain a replacement partner. In the second quarter of 2011, the government informed the Company it was in negotiations with a potential replacement partner. The negotiations with a potential replacement partner continue, and options to amend the two-well commitment are also being discussed with the Angolan government. Because of the uncertainty surrounding the outcome of the discussions with the Angolan government, in the third quarter of 2011, the Company recorded a full allowance of $4.1 million against the accounts receivable from partners for the amounts owed to the Company above its 40% working interest plus the 10% carried interest.

The Company applied for a second time extension in June 2011 as suitable rigs would not be available until after the expiration of the first extension period. The Company has been provided assurances that the extension will be approved; however, the Company can provide no assurances that such an extension will be granted. If the government of Angola were to deny a time extension, the Company may risk forfeiture of its $10.0 million funds in escrow associated with the two-well drilling obligation and may be required to impair its leasehold costs and other investments totaling $11.0 million as of September 30, 2011.

United States

In September 2011, the Company acquired a 65% working interest in approximately 22,000 net acres covering the Middle Bakken and deeper formations in the East Poplar unit and the Northwest Poplar field in Roosevelt County, Montana. The Company is obligated to pay for 100% of the costs to drill three wells by the end of 2012, estimated at $15.0 million, including one well by June 1, 2012.

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Capitalization Of Exploratory Well Costs

9 Months Ended

Sep. 30, 2011

Capitalization Of Exploratory Well Costs [Abstract]

Capitalization Of Exploratory Well Costs

5. CAPITALIZATION OF EXPLORATORY WELL COSTS

ASC Topic 932 - Extractive Industries provides that an exploration well shall be capitalized as part of the entity's uncompleted wells pending the determination of whether the well has found proved reserves. Further, an exploration well that discovers oil and gas reserves, which cannot be classified as proved when drilling is completed, shall be capitalized if the well has found a sufficient quantity of reserves to justify its completion as a producing well and the entity is making sufficient progress towards assessing the reserves and the economic and operating viability of the project. If either condition is not met, the exploration well would be assumed to be impaired and its costs would be charged to expense.

In the second and third quarters of 2010, the Company drilled the Southeast Etame No. 1 well with two sidetracks in the Etame Marin block offshore Gabon. The well discovered a five meter sand of oil. The Company and its partners are evaluating development options for this well in conjunction with other potential initiatives in the Etame Marin block. The Company has capitalized $8.0 million for this well in accordance with the criteria in ASC Topic 932.

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Condensed Consolidated Statements Of Changes In Equity (USD $) In Thousands	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Treasury Stock [Member]	Noncontrolling Interest [Member]	Total
Balance at Dec. 31, 2009	$ 6,157	$ 57,550	$ 109,249	$ (21,515)	$ 5,664	$ 157,105
Proceeds from stock issuance	73	2,697		(2,603)		167
Stock based compensation		1,925		(354)		1,571
Net income			28,455		3,816	32,271
Redemption of rights agreement			6			6
Distribution to noncontrolling interest					(4,495)	(4,495)
Balance at Sep. 30, 2010	6,230	62,172	137,710	(24,472)	4,985	186,625
Balance at Dec. 31, 2010	6,282	64,314	146,594	(25,665)	4,718	196,243
Proceeds from stock issuance	30	1,207				1,237
Stock based compensation		1,902				1,902
Net income			25,424		4,436	29,860
Distribution to noncontrolling interest					(5,195)	(5,195)
Balance at Sep. 30, 2011	$ 6,312	$ 67,423	$ 172,018	$ (25,665)	$ 3,959	$ 224,047

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Unaudited Condensed Consolidated Financial Statements And Accounting Policies

9 Months Ended

Sep. 30, 2011

Unaudited Condensed Consolidated Financial Statements And Accounting Policies [Abstract]

Unaudited Condensed Consolidated Financial Statements And Accounting Policies

1. UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS AND ACCOUNTING POLICIES

The condensed consolidated financial statements of VAALCO Energy, Inc. and subsidiaries (collectively, "VAALCO" or the "Company"), included herein are unaudited, and 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, 2010, 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 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 operator of consortiums internationally in Gabon and Angola and as a non-operator in the British North Sea. In Gabon and Angola, VAALCO serves as the operator for a group of companies which own working interests in production sharing contracts. Domestically, the Company has interests onshore in Montana, Texas, and Alabama and in the offshore Texas and Louisiana Gulf Coast area.

VAALCO's subsidiaries include VAALCO Gabon (Etame), Inc., VAALCO Production (Gabon), Inc., VAALCO Angola (Kwanza), Inc., VAALCO UK (North Sea), Ltd., and VAALCO Energy (USA), Inc.

The Company has evaluated subsequent events through November 7, 2011, the date the financial statements were issued.

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Condensed Consolidated Balance Sheets (USD $) In Thousands	Sep. 30, 2011	Dec. 31, 2010
Current assets:
Cash and cash equivalents	$ 112,575	$ 81,234
Funds in escrow	991	14,932
Receivables:
Trade	11,144	14,068
Accounts with partners, net of allowance of $4.1 million at Sept. 30, 2011	8,898	16,180
Other	4,547	10,412
Crude oil inventory	5,397	548
Materials and supplies	280	501
Prepayments and other	5,054	1,482
Total current assets	148,886	139,357
Property and equipment - successful efforts method:
Wells, platforms and other	178,405	168,139
Undeveloped acreage	25,304	16,692
Work in progress	13,185	8,812
Equipment and other	3,609	2,634
Property, Plant and Equipment, Gross, Total	220,503	196,277
Accumulated depreciation, depletion and amortization	(118,003)	(99,457)
Net property and equipment	102,500	96,820
Other assets:
Deferred tax asset	1,349	1,349
Funds in escrow	10,895	874
Total Assets	263,630	238,400
Current liabilities:
Accounts payable and accrued liabilities	22,408	26,702
Total current liabilities	22,408	26,702
Other liabilities	2,230	2,030
Asset retirement obligations	14,945	13,425
Total Liabilities	39,583	42,157
Commitments and Contingencies (Note 4)
VAALCO Energy, Inc. shareholders' equity:
Common stock, $0.10 par value, 100,000,000 authorized shares, 63,124,472 and 62,822,805 shares issued with 6,005,547 and 6,005,547 shares in treasury at September 30, 2011 and December 31, 2010, respectively	6,312	6,282
Additional paid-in capital	67,423	64,314
Retained earnings	172,018	146,594
Less treasury stock, at cost	(25,665)	(25,665)
Total VAALCO Energy, Inc. shareholders' equity	220,088	191,525
Noncontrolling interest	3,959	4,718
Total Equity	224,047	196,243
Total Liabilities and Equity	$ 263,630	$ 238,400