UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
For the quarterly period ended September 30, 2008
For the transition period from to
Commission file number 0-20928
VAALCO Energy, Inc.
(Exact name of registrant as specified in its charter)
(State or other jurisdiction of
incorporation or organization)
(I.R.S. Employer
Identification No.)
4600 Post Oak Place
Suite 309
Houston, Texas
(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 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 October 31, 2008, there were outstanding 58,245,682 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, 2008 and December 31, 2007
Condensed Statements of Consolidated Operations Three months and nine months ended September 30, 2008 and 2007
Condensed Statements of Consolidated Cash Flows Nine months ended September 30, 2008 and 2007
Notes to Unaudited Condensed Consolidated Financial Statements
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
QUANTATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
CONTROLS AND PROCEDURES
PART II. OTHER INFORMATION
ITEM 1A. RISK FACTORS
ITEM 2. ISSUER PURCHASES OF EQUITY SECURITIES FOR THE THREE MONTHS ENDED SEPTEMBER 30, 2008
ITEM 6. EXHIBITS
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CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(in thousands of dollars, except number of shares and par value amounts)
ASSETS
Current assets:
Cash and cash equivalents
Funds in escrow
Receivables:
Trade
Accounts with partners
Other
Crude oil inventory
Materials and supplies
Prepayments and other
Total current assets
Property and equipment - successful efforts method:
Wells, platforms and other production facilities
Undeveloped acreage
Work in progress
Equipment and other
Accumulated depreciation, depletion and amortization
Net property and equipment
Other assets:
Deferred tax asset
Other long term assets
TOTAL
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable and accrued liabilities
Income taxes payable
Total current liabilities
Long term debt
Asset retirement obligations
Total liabilities
Commitments and contingencies (Note 6)
Minority interest in consolidated subsidiaries
Stockholders’ equity:
Common stock, $0.10 par value, 100,000,000 authorized shares 61,106,324 and 61,054,824 shares issued with 2,860,642 and 1,560,342 in treasury at September 30, 2008 and December 31, 2007, respectively
Additional paid-in capital
Retained earnings
Less treasury stock, at cost
Total stockholders’ equity
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)
Revenues:
Oil and gas sales
Operating costs and expenses:
Production expenses
Exploration expense
Depreciation, depletion and amortization
General and administrative expenses
Total operating costs and expenses
Operating income
Other income (expense):
Interest income
Interest expense
Other, net
Total other income (expense)
Income from continuing operations before income taxes, and minority interest
Income tax expense
Minority interest in earnings of subsidiaries
Income from continuing operations
Discontinued operations: (Note 8) Loss from discontinued operations, net of tax
Net income
Basic income per share from continuing operations
Loss from discontinued operations
Basic income per share
Diluted income per share from continuing operations
Diluted income per share
Basic weighted shares outstanding
Diluted weighted average shares outstanding
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CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS
(in thousands of dollars)
CASH FLOWS FROM OPERATING ACTIVITIES
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Amortization of debt issuance costs
Dry hole costs
Stock based compensation
Change in operating assets and liabilities:
Trade receivables
Other receivables
Net cash provided by operating activities
CASH FLOWS FROM INVESTING ACTIVITIES
Funds in escrow, net
Additions to property and equipment
Net cash used in investing activities
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of common stock
Debt issuance costs capitalized
Purchase of treasury shares
Distribution to minority interest
Net cash used in financing activities
NET CHANGE IN CASH AND CASH EQUIVALENTS
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD
CASH AND CASH EQUIVALENTS AT END OF PERIOD
Supplemental disclosure of cash flow information
Income taxes paid
Interest paid
Supplemental disclosure of non cash flow information
Change in investment in property and equipment not paid
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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, 2007, 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 the operator of two production sharing contracts in Gabon, West Africa, conducts exploration activities in one concession in Angola, West Africa and conducts exploration activities on two blocks in the British North Sea. Domestically, the Company has interests in the Texas Gulf Coast area.
VAALCO’s subsidiaries holding interests in Gabon are VAALCO Energy (International), Inc., VAALCO Gabon (Etame), Inc. and VAALCO Production (Gabon), Inc. 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.
Diluted shares consist of the following:
Item
Basic weighted average common stock issued and outstanding
Dilutive options
Total diluted shares
Options to purchase 1,678,677 and 1,797,640 shares were excluded in the three months and nine months ended September 30, 2008 and 2007, respectively, because they would have been anti-dilutive.
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FASB Statement 157, Fair Value Measurements – The Company adopted Statement of Financial Accounting Standards (“SFAS”) No. 157, Fair Value Measurements, on January 1, 2008. SFAS No. 157 defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. This statement is effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. In February 2008, the Financial Accounting Standards Board (“FASB”) issued FASB Staff Position (“FSP”) No. FAS 157-1 and No. FAS 157-2, which delays the effective date of SFAS No. 157 for all nonfinancial assets and nonfinancial liabilities, except those that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually), to fiscal years beginning after November 15, 2008, and interim periods within those fiscal years and removes certain leasing transactions from the scope of SFAS No. 157. We do not currently have any significant assets or liabilities that are measured at fair value on a recurring basis.
FASB Statement 141(R), Business Combinations, and FASB Statement 160, Noncontrolling Interests in Consolidated Financial Statements – an amendment of ARB No. 51—In December 2007, the FASB issued FASB Statement 141(R), Business Combinations, which replaced FASB Statement 141, Business Combinations, (“SFAS 141(R)”). In December 2007, the FASB also issued FASB Statement 160, Noncontrolling Interests in Consolidated Financial Statements – an amendment of ARB No. 51, (“SFAS 160”). 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. These statements are to be applied prospectively for fiscal years beginning after December 15, 2008. The Company is evaluating SFAS 141(R) and SFAS 160 to determine the impact of these statements on our consolidated financial statements.
FASB Statement 159, The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115—In February 2007, the FASB issued FASB Statement 159, The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115, (“SFAS 159”). SFAS 159 permits companies to choose to measure many financial instruments and certain other items at fair value, with changes in fair value reflected in earnings. SFAS 159 is effective as of the beginning of the first fiscal year that begins after November 15, 2007. The Company adopted SFAS 159 as of January 1, 2008 and did not elect the fair value option for any instruments that were not previously reported at fair value.
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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 September 30, 2008, there were 3,121,196 shares subject to options authorized but not granted.
During the nine months ended September 30, 2008, the Company granted no stock options.
For the three months and nine months ended September 30, 2008, the Company recognized non-cash compensation expense of $0.2 million and $0.7 million respectively, (or $0.00 and $0.01 per basic and diluted share, respectively), related to stock options. For the three months and nine months ended September 30, 2007, the Company recognized non-cash compensation expense of $0.6 million and $1.7 million, respectively (or $0.01 and $0.03 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.
A summary of the stock option activity for the nine months ended September 30, 2008 is provided below:
Outstanding at beginning of period
Granted
Exercised
Forfeited
Outstanding at end of period
Exercisable at end of period
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, 2008, unrecognized compensation costs totaled $0.6 million. The expense is expected to be recognized over a weighted average period of 0.4 years. No stock options vested during the nine months ended September 30, 2008.
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In October 2007, the Company entered into an amendment with the owner of the FPSO chartered for the Etame field to extend the contract through September 14, 2015. In connection with the charter of the FPSO, the Company, as operator of the Etame field, guaranteed the charter payments through the same 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)
Year
2008
2009
2010
2011
2012
Thereafter
The Company has recorded a liability of $0.7 million at September 30, 2008 representing the guarantee’s fair value.
In January 2006, the consortium elected to extend 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). An additional exploration well is required during the optional two-year extension.
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 spend 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 spend a minimum of $5.0 million. The Company is on schedule to commence drilling the first of two exploratory wells in December 2008.
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 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 is required to acquire and process 1,000 square kilometers of 3-D seismic, drill two exploration wells and spend a minimum of $29.5 million ($14.8 million net to the Company).
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During the optional three year extension to the contract, the Company is required to acquire 600 square kilometers of 3-D seismic data, drill two exploration wells and spend a minimum of $27.2 million ($13.6 million net to the Company). The Company 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.
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 farm-inee’s share of the well. Block 48/25c is located in the Southern Gas Basin and an exploration well is expected to be drilled during the fourth quarter of 2008. It is anticipated that the Company share of costs for this well will be approximately $8.0 million.
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, 2008 and 2007 are as follows: (in thousands)
Revenues
Income from operations
2007
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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 proceed 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 volatility of oil and gas prices, future production costs, future production quantities, operating hazards, weather, the credit and financial market crisis, and statements set forth in the “Risk Factors” section included in the Company’s Forms 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 interests in two blocks in the British North Sea. In addition, the Company has minor onshore and offshore domestic United States production in Texas and Louisiana. In Gabon, the Company operates the Etame Marin block, a 750,000 acre block offshore southern Gabon. Three fields on the Etame Marin block are under production, the Etame, Avouma and South Tchibala fields. During the nine months of 2008, these fields produced 5.9 million barrels of oil (1.4 million barrels net to the Company). The Company is also developing the Ebouri field on the Etame Marin block. Construction of the production platform was completed in April 2008 and the platform was successfully installed in Gabonese waters in August 2008. First production from the Ebouri field is expected in January 2009. In addition to developing the Ebouri field, the Company has plans to drill three exploration wells on the Etame Marin block beginning in November 2008.
Also in Gabon, the Company operates the Mutamba Iroru block, a 270,000 acre onshore license which the Company acquired in 2005. The Company anticipates drilling the first of two exploration wells on the block in December 2008. There is currently no production from the Mutamba Iroru block.
In Angola, the Company operates Block 5, a 1.4 million acre offshore license which the Company acquired in December 2006. The Company has leased 1,140 square kilometers of 3-D data over the block and has a commitment to drill two exploration wells prior to December 1, 2010. The Company expects to drill the first of the exploration wells during the second half of 2009. During September 2008, the Company shot 400 square kilometers of new 3-D seismic over a portion of Block 5 which will be interpreted over the next two quarters.
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In the British North Sea, the Company in January 2008 signed a farm-in agreement for a 25% working interest in Block 48/25c located offshore in the Southern Gas Basin. An exploration well is expected to be drilled during the fourth quarter of 2008.
Impact of the Current Financial and Credit Markets
The financial markets are undergoing unprecedented disruptions. 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 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 September 30, 2008 totaled $103.5 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 Shell, which the Company believes to be a creditworthy purchaser.
CAPITAL RESOURCES AND LIQUIDITY
Cash Flows
Net cash provided by operating activities for the nine months ended September 30, 2008 was $65.5 million, as compared to $21.7 million for the nine months ended September 30, 2007. The increase in cash provided by operations for the nine months ended September 30, 2008 compared to the nine months ended September 30, 2007 was primarily due to higher net income and more favorable changes in working capital other than cash used in operations of $0.6 million for the nine months ended September 30, 2008, compared to $14.1 million used in operations for the nine months ended September 30, 2007.
Net cash used in investing activities for the nine months ended September 30, 2008 was $24.7 million, compared to net cash used in investing activities for the nine months ended September 30, 2007 of $9.7 million. For the nine months ended September 30, 2008, the Company invested $16.0 million in the Etame Marin block operations, primarily for development of the Ebouri field. Also, the Company incurred $6.2 million of dry hole costs for a North Sea well during the period.
For the nine months ended September 30, 2008, cash used in financing activities was $13.7 million, consisting primarily of distributions to a minority interest owner of $5.0 million and purchase of shares of $8.9 million. For the nine months ended September 30, 2007, cash used by financing activities of $2.7 million consisted of $3.0 million used for distributions to minority interest holders and $0.3 million in proceeds from the issuance of common stock.
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Oil and gas prices have declined significantly since the end of the third quarter 2008. This will reduce the Company’s cash flows from operations.
Capital Expenditures
During the nine months ended September 30, 2008, the Company incurred $16.9 million of capital expenditures (including amounts carried in accounts payable at September 30, 2008), primarily associated with the construction of the development platform in the Ebouri field. During the remainder of 2008, the Company anticipates commencing an exploration program with three exploration wells on the Etame Marin block, two exploration wells on the Mutamba block and one well in the British North Sea. The budget for the six exploration wells is approximately $35.0 million net to the Company. In addition, the Company will complete the installation and commissioning of the Ebouri platform and drill one or two development wells at a remaining cost of $16 million to $24 million net to the Company. The first development well will be drilled in the fourth quarter of 2008.
Liquidity
Historically, the Company’s primary sources of capital have been cash flows from operations, private sales of equity, and debt. At September 30, 2008, the Company had cash of $103.5 million. The Company believes that this cash combined with cash flow from operations will be sufficient to fund the Company’s remaining 2008 capital expenditure budget, required debt service payments and operational needs. The Company invests cash, not required for immediate operational and capital expenditure needs, in short-term bankers acceptance and money market instruments primarily with JPMorgan Chase & Co. The Company has no exposure to the asset-backed commercial paper market which has been subject to a liquidity crisis over the past year. 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 IFC for a $30.0 million revolving credit facility which is secured by the assets of VAALCO Gabon (Etame), Inc., the subsidiary which owns the Company’s interest in the Etame Marin block. 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 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 Shell. The Company believes Shell to be a creditworthy purchaser. While the loss of Shell as a buyer might have a material adverse effect on the Company in the near term, management believes that the Company would be able to obtain other customers for its crude oil.
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Domestically, the Company produces from wells in Brazos County Texas and offshore in the Gulf of Mexico, which contributed $192,000 to revenues in the nine months ended September 30, 2008. 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 nine months ended September 30, 2008, the Company spent $6.2 million on a well in the British North Sea which was suspended as a non-commercial oil discovery and $2.1 million on other exploration activities including 2-D seismic acquisition in Gabon.
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RESULTS OF OPERATIONS
Three months ended September 30, 2008 compared to three months ended September 30, 2007
Total revenues were $55.5 million for the three months ended September 30, 2008 compared to $34.8 million for the comparable period in 2007. The Company sold approximately 517,000 net barrels of oil equivalent at an average price of $107.48 per barrel in the three months ended September 30, 2008. In the three months ended September 30, 2007, the Company sold approximately 472,000 barrels of oil equivalent at an average price of $73.79 per barrel. Crude oil production from the Etame, Avouma and South Tchibala fields is averaging 21,000 barrels of oil per day (“BOPD”) compared to approximately 20,000 BOPD in the three months ended September 30, 2007. 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 September 30, 2008 were $5.9 million compared to $3.8 million in the three months ended September 30, 2007. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized. Production expenses in the three months ended September 30, 2008 were higher than in the three months ended September 30, 2007 due to increased volumes sold as well as higher boat rental costs, higher FPSO costs, higher helicopter costs and higher fuel costs.
Exploration expense was $0.3 million for the three months ended September 30, 2008 compared to $0.7 million in the comparable period in 2007. For the three months ended September 30, 2008, exploration expense consisted of seismic processing costs in Angola. Exploration expense for the three months ended September 30, 2007 consisted primarily of seismic processing costs in Gabon and acquiring 2-D seismic in Angola.
Depreciation, depletion and amortization expenses were $6.0 million in the three months ended September 30, 2008 compared to $4.8 million in the three months ended September 30, 2007. The higher depreciation, depletion and amortization expenses during the three months ended September 30, 2008 compared to the three months ended September 30, 2007 was due to higher volumes of oil sold.
General and administrative expenses for the three months ended September 30, 2008 and 2007 were $1.5 million and $1.8 million for each period, respectively. The lower general and administrative expenses were primarily attributable to lower stock based compensation expense of $0.2 million in the three months ended September 30, 2008 compared to $0.6 million in the three months ended September 30, 2008. In both of the three months ended September 30, 2008 and 2007, the Company benefited from overhead reimbursement associated with production and development operations on the Etame Marin block.
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Other Income (Expense)
Interest income received on amounts on deposit was $0.6 million in the three months ended September 30, 2008 compared to $1.0 million in the three months ended September 30, 2007. The decrease in interest income received on amounts on deposit reflects lower interest rates in the three months ended September 30, 2008 as compared to the same period of 2007.
Income Taxes
Income taxes amounted to $17.4 million and $14.7 million for the three months ended September 30, 2008 and 2007, respectively. In the three months ended September 30, 2008 and in the three months ended September 30, 2007, the income taxes were all paid in Gabon. Income taxes in the three months ended September 30, 2008 were higher due to higher oil prices, which increased taxable revenues.
Minority Interest
The Company incurred $2.7 million and $1.2 million in minority interest charges in the three months ended September 30, 2008 and 2007, respectively. These minority interest charges were associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company.
Net Income
Net income for the three months ended September 30, 2008 was $22.3 million, compared to net income of $8.8 million for the same period in 2007. Higher oil prices and crude volumes sold, which were partially offset by higher operating costs, contributed to the higher net income in 2008.
Nine months ended September 30, 2008 compared to nine months ended September 30, 2007
Total revenues were $153.1 million for the nine months ended September 30, 2008 compared to $88.1 million for the comparable period in 2007. The Company sold approximately 1,428,000 net barrels of oil equivalent at an average price of $107.21 per barrel in the nine months ended September 30, 2008. In the nine months ended September 30, 2007, the Company sold approximately 1,334,000 barrels of oil equivalent at an average price of $66.05 per barrel. 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.
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Total production expenses for the nine months ended September 30, 2008 were $14.9 million compared to $11.1 million in the nine months ended September 30, 2007. The Company matches production expenses with crude oil sales. Any production expenses associated with unsold crude oil inventory are capitalized. Production expenses in the nine months ended September 30, 2008 were higher than in the nine months ended September 30, 2007 due to higher insurance costs, higher costs of boat and helicopter rentals, higher fuel costs and higher FPSO costs.
Exploration expense was $8.3 million for the nine months ended September 30, 2008 compared to $6.1 million in the comparable period in 2007. Exploration expense for the nine months ended September 30, 2008 included $6.2 million of dry hole costs associated with a well drilled by the Company in the North Sea. Also included in exploration expense were 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. Exploration expense for the nine months ended September 30, 2007 included $3.9 million associated with licensing 1,175 square kilometers of 3-D seismic data for Block 5 in Angola and $1.3 million for the acquisition and processing of 400 square kilometers of offshore Gabon 3-D seismic.
Depreciation, depletion and amortization expenses were $16.2 million in the nine months ended September 30, 2008 compared to $13.5 million in the nine months ended September 30, 2007. The higher depreciation, depletion and amortization expenses during the nine months ended September 30, 2008 compared to the nine months ended September 30, 2007 was due to higher volumes of oil sold and increasing percentages of total production coming from the Avouma and South Tchibala fields, which have higher depletion rates than production from the Etame field.
General and administrative expenses for the nine months ended September 30, 2008 and 2007 were $7.1 million and $6.1 million for each period, respectively. The higher general and administrative costs in the nine months ended September 30, 2008 as compared to the same period of 2007 were due in part to non-recurring legal and solicitation costs associated with the Company’s annual meeting. The Company also incurred $0.4 million of general and administrative costs related to the operation of the Company office in Angola in the nine months ended September 30, 2008. This office opened in Angola in September 2007. During the nine months ended September 30, 2008, the Company incurred $0.7 million of stock based compensation compared to $1.7 million incurred in the nine months ended September 30, 2007.
Interest income received on amounts on deposit was $2.0 million in the nine months ended September 30, 2008 compared to $2.9 million in the nine months ended September 30, 2007. The decrease in interest income received on amounts on deposit reflects lower interest rates in the nine months ended September 30, 2008 as compared to the same period of 2007. Interest expense and financing charges were $0.5 million for the nine months ended September 30, 2008 compared to $0.9 million for the nine months ended September 30, 2007, all of which was associated with the Company’s IFC loan.
17
Income taxes amounted to $65.2 million and $33.3 million for the nine months ended September 30, 2008 and 2007, respectively. In the nine months ended September 30, 2008 and 2007, the income taxes were all paid in Gabon. The higher income taxes paid in Gabon in nine months ended September 30, 2007 were due to higher oil prices and crude volumes sold.
Discontinued Operations
Expense from discontinued operations in the Philippines in the nine months ended September 30, 2007 was $0.1 million. The Philippines offices were closed in 2007 and no costs related to this office were incurred in 2008.
The Company incurred $5.7 million and $3.0 million in minority interest charges in the nine months ended September 30, 2008 and 2007, respectively. These minority interest charges were associated with VAALCO Energy (International), Inc., a subsidiary that is 90.01% owned by the Company.
Net income for the nine months ended September 30, 2008 was $37.2 million, compared to net income of $17.1 million for the same period in 2007. Higher oil prices and crude volumes sold, which was partially offset by higher operating costs, contributed to the higher net income in 2008.
18
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, principal operating 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.
19
There have been no material changes to the disclosure on this matter in our annual report on Form 10-K for the year ended December 31, 2007, other than the following:
Oil and gas prices have recently declined substantially. If there is a sustained economic downturn or recession in the United States or globally, oil and natural gas prices may continue to fall and may become and remain depressed for a long period of time, which may adversely affect the Company’s results of operations.
Currently, the capital markets are experiencing an unprecedented disruption which, if it continues for an extended period of time, may adversely affect the Company’s growth strategy.
The Company did not purchase any shares of common stock for the treasury during the three months ended September 30, 2008.
On September 14, 2007, the Company announced its intention to purchase up to $20 million of shares of its common stock for the treasury. The announcement did not specify an amount of shares or expiration date. Purchases may be made in both the open market and through negotiated transactions, and purchases may be increased, decreased or discontinued at any time without prior notice.
3.2
20
3.3
31.1
31.2
Section 1350 Certificates
32.1
32.2
21
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)
/s/ GREGORY R. HULLINGER
Dated: November 10, 2008
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EXHIBIT INDEX
Exhibits
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