SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549
FORM 10-Q
| x | Quarterly report pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934 |
For the quarterly period ended March 31, 2009
Commission File Number 1-7908
ADAMS RESOURCES & ENERGY, INC.
(Exact name of Registrant as specified in its charter)
| Delaware | | 74-1753147 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
| 4400 Post Oak Pkwy Ste 2700 , Houston, Texas 77027 |
| (Address of principal executive office & Zip Code) |
Registrant's telephone number, including area code (713) 881-3600
Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 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 o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o
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 definition of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 126-2 of the Exchange Act. (Check one)
Large accelerated filer o Accelerated filer o Non-accelerated filer x Smaller Reporting Company o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES o NO x
A total of 4,217,596 shares of Common Stock were outstanding at May 1, 2009.
PART 1 – FINANCIAL INFORMATION
Item 1. Financial Statements
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share data)
| | | Three Months Ended | |
| | | | |
| | | | | | | |
| REVENUES: | | | | | | |
| Marketing | | $ | 327,112 | | | $ | 945,637 | |
| Transportation | | | 10,943 | | | | 16,404 | |
| Oil and gas | | | 2,086 | | | | 3,947 | |
| | | | 340,141 | | | | 965,988 | |
| COSTS AND EXPENSES: | | | | | | | | |
| Marketing | | | 320,958 | | | | 940,919 | |
| Transportation | | | 10,207 | | | | 14,687 | |
| Oil and gas | | | 1,435 | | | | 1,426 | |
| General and administrative | | | 2,310 | | | | 2,917 | |
| Depreciation, depletion and amortization | | | 2,431 | | | | 3,038 | |
| | | | 337,341 | | | | 962,987 | |
| | | | | | | | | |
| Operating earnings | | | 2,800 | | | | 3,001 | |
| | | | | | | | | |
| Other income (expense): | | | | | | | | |
| Interest income | | | 32 | | | | 355 | |
| Interest expense | | | (6 | ) | | | (4 | ) |
| | | | | | | | | |
| Earnings before income tax | | | 2,826 | | | | 3,352 | |
| | | | | | | | | |
| Income tax provision | | | 956 | | | | 1,141 | |
| | | | | | | | | |
| Net earnings | | $ | 1,870 | | | $ | 2,211 | |
| | | | | | | | | |
| EARNINGS PER SHARE: | | | | | | | | |
| Basic and diluted net earnings per common share | | $ | .44 | | | $ | .52 | |
| | | | | | | | | |
| DIVIDENDS PER COMMON SHARE | | $ | - | | | $ | - | |
The accompanying notes are an integral part of these financial statements.
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands)
| | | March 31, | | | December 31, | |
| | | | | | | |
| ASSETS | | | | | | |
| | | | | | | |
| Current assets: | | | | | | |
| Cash and cash equivalents | | $ | 22,311 | | | $ | 18,208 | |
| Accounts receivable, net of allowance for doubtful | | | | | | | | |
| Accounts of $1,297 and $1,251, respectively | | | 111,248 | | | | 119,401 | |
| Inventories | | | 11,108 | | | | 14,207 | |
| Fair value contracts | | | 7,085 | | | | 8,697 | |
| Income tax receivable | | | 3,558 | | | | 3,629 | |
| Prepayments | | | 10,809 | | | | 5,224 | |
| | | | | | | | | |
| Total current assets | | | 166,119 | | | | 169,366 | |
| | | | | | | | | |
| Property and equipment | | | 122,823 | | | | 118,863 | |
| Less – accumulated depreciation, | | | | | | | | |
| Depletion and amortization | | | (85,149 | ) | | | (83,277 | ) |
| | | | 37,674 | | | | 35,586 | |
| Other assets: | | | | | | | | |
| Fair value contracts | | | 75 | | | | - | |
| Deferred income tax asset | | | 1,611 | | | | 2,035 | |
| Cash deposits and other | | | 3,508 | | | | 3,939 | |
| | | $ | 208,987 | | | $ | 210,926 | |
| | | | | | | | | |
| LIABILITIES AND SHAREHOLDERS’ EQUITY | | | | | | | | |
| | | | | | | | | |
| Current liabilities: | | | | | | | | |
| Accounts payable | | $ | 113,358 | | | $ | 115,183 | |
| Accounts payable – related party | | | 47 | | | | 89 | |
| Fair value contracts | | | 6,450 | | | | 8,196 | |
| Accrued and other liabilities | | | 3,294 | | | | 3,930 | |
| Current deferred income taxes | | | 772 | | | | 409 | |
| Total current liabilities | | | 123,921 | | | | 127,807 | |
| | | | | | | | | |
| Other liabilities: | | | | | | | | |
| Fair value contracts | | | 67 | | | | - | |
| Asset retirement obligations | | | 1,275 | | | | 1,260 | |
| Other long-term | | | 93 | | | | 98 | |
| | | | 125,356 | | | | 129,165 | |
| Commitments and contingencies (Note 5) | | | | | | | | |
| | | | | | | | | |
| Shareholders’ equity: | | | | | | | | |
| Preferred stock - $1.00 par value, 960,000 shares | | | | | | | | |
| authorized, none outstanding | | | - | | | | - | |
| Common stock - $.10 par value, 7,500,000 shares | | | | | | | | |
| authorized, 4,217,596 shares outstanding | | | 422 | | | | 422 | |
| Contributed capital | | | 11,693 | | | | 11,693 | |
| Retained earnings | | | 71,516 | | | | 69,646 | |
| Total shareholders’ equity | | | 83,631 | | | | 81,761 | |
| | | $ | 208,987 | | | $ | 210,926 | |
The accompanying notes are an integral part of these financial statements.
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
| | | Three Months Ended | |
| | | | |
| | | | | | | |
| CASH PROVIDED BY OPERATIONS: | | | | | | |
| Net earnings | | $ | 1,870 | | | $ | 2,211 | |
| Adjustments to reconcile net earnings to net cash | | | | | | | | |
| from operating activities - | | | | | | | | |
| Depreciation, depletion and amortization | | | 2,431 | | | | 3,038 | |
| Gains on property sales | | | (55 | ) | | | (22 | ) |
| Dry hole costs incurred | | | 224 | | | | 90 | |
| Impairment of oil and gas properties | | | 124 | | | | 197 | |
| Provision for doubtful accounts | | | 46 | | | | 24 | |
| Other, net | | | 479 | | | | 10 | |
| Decrease (increase) in accounts receivable | | | 8,107 | | | | (41,472 | ) |
| Decrease (increase) in inventories | | | 3,099 | | | | (6,731 | ) |
| Net change in fair value contracts | | | (142 | ) | | | 283 | |
| Decrease (increase) in income tax receivable | | | 71 | | | | 401 | |
| Decrease (increase) in prepayments | | | (5,585 | ) | | | (2,217 | ) |
| Increase (decrease) in accounts payable | | | (1,836 | ) | | | 53,351 | |
| Increase (decrease) in accrued liabilities | | | (636 | ) | | | 371 | |
| Deferred income taxes | | | 787 | | | | (358 | ) |
| | | | | | | | | |
| Net cash provided by operating activities | | | 8,984 | | | | 9,176 | |
| | | | | | | | | |
| INVESTING ACTIVITIES: | | | | | | | | |
| Property and equipment additions | | | (4,907 | ) | | | (6,885 | ) |
| Insurance and excise tax refunds (deposits) | | | (38 | ) | | | (53 | ) |
| Proceeds from property sales | | | 64 | | | | 22 | |
| Redemption of short-term investments | | | - | | | | 10,000 | |
| Investment in short-term investments | | | - | | | | (10,000 | ) |
| | | | | | | | | |
| Net cash used in investing activities | | | (4,881 | ) | | | (6,916 | ) |
| | | | | | | | | |
| Increase in cash and cash equivalents | | | 4,103 | | | | 2,260 | |
| | | | | | | | | |
| Cash at beginning of period | | | 18,208 | | | | 23,697 | |
| | | | | | | | | |
| Cash at end of period | | $ | 22,311 | | | $ | 25,957 | |
| | | | | | | | | |
The accompanying notes are an integral part of these financial statements
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED
CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Basis of Presentation
The accompanying condensed consolidated financial statements are unaudited but, in the opinion of the Company's management, include all adjustments (consisting of normal recurring accruals) necessary for the fair presentation of its financial position at March 31, 2009, its results of operations and its cash flows for the three months ended March 31, 2009 and 2008. Certain information and note disclosures normally included in annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted pursuant to Securities and Exchange Commission rules and regulations. Although the Company believes the disclosures made are adequate to make the information presented not misleading, it is suggested that these consolidated financial statements be read in conjunction with the financial statements, and the notes thereto, included in the Company's latest annual report on Form 10-K. The interim statement of operations is not necessarily indicative of results to be expected for a full year.
Note 2 - Summary of Significant Accounting Policies
Nature of Operations and Principles of Consolidation
The Company is engaged in the business of crude oil, natural gas and petroleum products marketing, as well as tank truck transportation of liquid chemicals and oil and gas exploration and production. Its primary area of operation is within a 1,000 mile radius of Houston, Texas. The accompanying consolidated financial statements include the accounts of Adams Resources & Energy, Inc., a Delaware corporation, and its wholly owned subsidiaries (the "Company") after elimination of all significant intercompany accounts and transactions. In order to conform to current year presentations, certain reclassifications have been made to prior year amounts in the Statement of Cash Flows under “Provision for Doubtful Accounts”.
Cash and Cash Equivalents
Cash and cash equivalents include any Treasury bill, commercial paper, money market funds or federal funds with maturity of 90 days or less. Depending on cash availability and market conditions, investments in municipal bonds may also be made from time to time. The Company invests in tax-free municipal securities in order to enhance the after-tax rate of return from short-term investments of cash.
Inventories
Crude oil and petroleum product inventories are carried at the lower of average cost or market. Petroleum products inventory includes gasoline, lubricating oils and other petroleum products purchased for resale. Components of inventory are as follows (in thousands):
| | | March 31, | | | December 31, | |
| | | | | | | |
| | | | | | | |
| Crude oil | | $ | 8,788 | | | $ | 11,710 | |
| Petroleum products | | | 2,320 | | | | 2,497 | |
| | | | | | | | | |
| | | $ | 11,108 | | | $ | 14,207 | |
Property and Equipment
Expenditures for major renewals and betterments are capitalized, and expenditures for maintenance and repairs are expensed as incurred. Interest costs incurred in connection with major capital expenditures are capitalized and amortized over the lives of the related assets. When properties are retired or sold, the related cost and accumulated depreciation, depletion and amortization ("DD&A") is removed from the accounts and any gain or loss is reflected in earnings.
Oil and gas exploration and development expenditures are accounted for in accordance with the successful efforts method of accounting. Direct costs of acquiring developed or undeveloped leasehold acreage, including lease bonus, brokerage and other fees, are capitalized. Exploratory drilling costs are initially capitalized until the properties are evaluated and determined to be either productive or nonproductive. Such evaluations are made on a quarterly basis. If an exploratory well is determined to be nonproductive, the costs of drilling the well are charged to expense. Costs incurred to drill and complete development wells, including dry holes, are capitalized. As of March 31, 2009, the Company had no unevaluated or suspended exploratory drilling costs.
Producing oil and gas leases, equipment and intangible drilling costs are depleted or amortized over the estimated proved reserves using the units-of-production method. Other property and equipment is depreciated using the straight-line method over the estimated average useful lives of three to fifteen years for marketing, three to fifteen years for transportation and ten to twenty years for all others.
The Company periodically reviews long-lived assets for impairment whenever there is evidence that the carrying value of such assets may not be recoverable. This consists of comparing the carrying value of the asset with the asset’s expected future undiscounted cash flows without interest costs. Estimates of expected future cash flows represent management’s best estimate based on reasonable and supportable assumptions. Proved oil and gas properties are reviewed quarterly for impairment triggers on a field-by-field basis. Any impairment recognized is permanent and may not be restored. For the three-month periods ended March 31, 2009 and 2008 there were no impairment provisions on producing oil and gas properties. In addition, on a quarterly basis, management evaluates the carrying value of non-producing properties and unevaluated properties and may deem them impaired for lack of drilling activity. Accordingly, impairment provisions on non-producing properties totaling $124,000 and $197,000 were recorded for the three-month periods ended March 31, 2009 and 2008, respectively.
Impairments in the value of long-lived assets are made in accordance with the provisions of SFAS No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets”. For producing properties, the fair value is determined based on an internal discounted cash-flow model. Cash flows are determined based on estimated future production and prices and then discounted using an internal rate of return consistent with that used by the Company to evaluate cash flows of other assets of a similar nature. For non-producing properties, the fair value is determined based on management’s knowledge of current geological evaluations, drilling results and activity in the area and intent to drill as it relates to the remaining term of the underlying oil and gas leasehold interest. Such evaluations of producing and non-producing property interests are based upon Level 3 inputs as described in SFAS 157.
Cash deposits and other assets
The Company has established certain deposits to support its participation in its liability insurance program and remittance of state crude oil severance taxes and other state collateral deposits. In addition, the Company has accounts and notes receivable from certain customers that are expected to be collected over a long-term period. Components of cash deposits and other assets are as follows (in thousands):
| | | March 31, | | | December 31, | |
| | | | | | | |
| | | | | | | |
| Insurance collateral deposits | | $ | 2,810 | | | $ | 2,794 | |
| State collateral deposits | | | 301 | | | | 279 | |
| Accounts and notes receivable | | | 102 | | | | 503 | |
| Materials and supplies | | | 295 | | | | 363 | |
| | | $ | 3,508 | | | $ | 3,939 | |
Revenue Recognition
Commodity purchases and sale contracts utilized by the Company’s marketing businesses qualify as derivative instruments under Statement of Financial Accounting Standards (“SFAS”) No. 133, “Accounting for Derivative Instruments and Hedging Activities.”
All natural gas, as well as certain specifically identified crude oil purchase and sale contracts are designated as trading activities under the guidance provided by SFAS No. 115, “Accounting for Certain Debt and Equity Securities.” From the time of contract origination, such contracts are marked-to-market under SFAS No. 133 and recorded on a net revenue basis in the accompanying financial statements in accordance with Emerging Issues Task Force (“EITF”) 02-03 “Issues Involved in Accounting for Derivative Contracts Held for Trading Purposes and Contracts Involved in Energy Trading and Risk Management Activities.”
Substantially all crude oil and refined products purchase and sale contracts qualify and are designated as non-trading activities and the Company accordingly elects the normal purchases and sales exception under SFAS No. 133. For normal purchase and sale activities, the Company’s customers are invoiced monthly based upon contractually agreed upon terms and revenue is recognized in the month in which the physical product is delivered to the customer. Such sales are recorded gross in the financial statements based on the guidance provided by EITF 99-19, “Reporting Revenue Gross as a Principal versus Net as an Agent.”
Certain crude oil contracts may be with a single counterparty to provide for similar quantities of crude oil to be bought and sold at different locations. These contracts are entered into for a variety of reasons, including effecting the transportation of the commodity, to minimize credit exposure, and/or to meet the competitive demands of the customer. Consistent with the requirements of EITF 04-13, “Accounting for Purchases and Sales of Inventory with the Same Counterparty,” these buy/sell arrangements are reflected on a net revenue basis in the accompanying financial statements.
Transportation customers are invoiced, and the related revenue is recognized as the service is provided. Oil and gas revenue from the Company’s interests in producing wells is recognized as title and physical possession of the oil and gas passes to the purchaser.
Statement of Cash Flows
Interest paid totaled $6,000 and $4,000 during the three-month periods ended March 31, 2009 and 2008, respectively. Income taxes paid during these same periods totaled $24,000 and $5,000, respectively. Non-cash investing activities for property and equipment in accounts payable were $530,000 and $49,000 as of March 31, 2009 and 2008, respectively. There were no significant non-cash financing activities in any of the periods reported.
Earnings Per Share
The Company computes and presents earnings per share in accordance with SFAS No. 128, “Earnings Per Share”, which requires the presentation of basic earnings per share and diluted earnings per share for potentially dilutive securities. Earnings per share are based on the weighted average number of shares of common stock and potentially dilutive common stock shares outstanding during the period. The weighted average number of shares outstanding was 4,217,596 for 2009 and 2008. There were no potentially dilutive securities during those periods.
Share-Based Payments
During the periods presented herein, the Company had no stock-based employee compensation plans, nor any other share-based payment arrangements.
Use of Estimates
The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Examples of significant estimates used in the accompanying consolidated financial statements include the accounting for depreciation, depletion and amortization, revenue accruals, oil and gas property impairments, the provision for bad debts, insurance related accruals, income taxes, contingencies and valuation of fair value contracts.
Use of derivative instruments
The Company’s marketing segment is involved in the purchase and sale of crude oil and natural gas. The Company seeks to make a profit by procuring such commodities as they are produced and then delivering such products to the end use or intermediate use marketplace. As is typical for the industry, such transactions are made pursuant to the terms of forward month commodity purchase and/or sale contracts. These contracts meet the definition of a derivative instrument as defined by SFAS No. 133 and therefore, the Company accounts for such contracts in accordance with the rules therein. The Company’s objective of entering into commodity contracts is not to manage commodity price risk nor is the objective to trade or speculate on commodity prices. Rather, such underlying contracts are standard for the industry and are the governing document for the Company’s crude oil and natural gas wholesale distribution businesses. The accounting methodology utilized by the Company for its commodity contracts is further discussed below under the caption “Fair Value Measurements”.
The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Unaudited Balance Sheet as of March 31, 2009 as follows (in thousands):
| | Balance Sheet | | | |
| | | | | |
| Asset Derivatives | | | | |
| | | | | |
| Derivatives not designated as hedging | | | | |
| instruments under SFAS No. 133 | | | | |
| | | | | |
| - Fair value commodity contracts | Current assets | | $ | 7,537 | |
| - Fair value commodity contracts | Other assets | | | 75 | |
| | | | | | |
| Total asset derivatives | | | | 7,612 | |
| Less counterparty offsets | | | | (452 | ) |
| | | | | | |
| Total asset fair value contracts | | | | 7,160 | |
| | | | | | |
| Liability Derivatives | | | | | |
| | | | | | |
| Derivatives not designated as hedging | | | | | |
| instruments under SFAS | | | | | |
| | | | | | |
| - Fair value commodity contracts | Current liabilities | | | (6,902 | ) |
| - Fair value commodity contracts | Other liabilities | | | (67 | ) |
| | | | | | |
| Total liability derivatives | | | | (6,969 | ) |
| Less Counterparty offsets | | | | 452 | |
| | | | | | |
| Total liability fair value contracts | | | | (6,517 | ) |
| | | | | | |
| Net fair value contracts | | | $ | 643 | |
The Company only enters into commodity contracts with credit worthy counterparties or obtains collateral support for such activities. No credit loss provision has been applied to the Company’s forward commodity contract valuations and the Company currently holds no collateral from its counterparties. The Company has, however, posted margin collateral in support of certain commodity contracts. Such cash collateral held by the Company’s counterparties totaled $943,000 as of March 31, 2009. The Company is not subject to any credit-risk-related trigger events.
Commodity contracts (derivatives) are reflected in the accompanying Unaudited Statement of Operations for the three months ended March 31, 2009 as follows (in thousands):
| | Statement of Operations | |
| | | |
| Derivatives not designated as hedging | | |
| Instruments under SFAS No. 133 | | |
| | | |
| - Fair value commodity contracts | Revenues - marketing | $142 |
The impact of commodity contracts on revenues for the three months ended March 31, 2009 of $142,000 represents a non-cash addition to earnings and is reflected as such under the caption “Net change in fair value contracts” in the accompanying Unaudited Statement of Cash Flows.
Fair Value Measurements
The carrying amount reported in the balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.
Fair value contracts consist of derivative financial instruments as defined under SFAS No. 133 and such contracts are recorded as either an asset or liability measured at its fair value. Changes in fair value are recognized immediately in earnings unless the derivatives qualify for, and the Company elects, cash flow hedge accounting. The Company had no contracts designated for hedge accounting under SFAS No. 133 during any current reporting periods.
SFAS No. 157, “Fair Value Measurements”, defines fair value, establishes a framework for measuring fair value and expands disclosures related to fair value measurements. SFAS No. 157 clarifies that fair value should be based on assumptions that market participants would use when pricing an asset or liability and establishes a fair value hierarchy of three levels that prioritizes the information used to develop those assumptions. Currently, for all items presented herein, the Company utilizes a market approach to valuing its contracts. On a contract by contract, forward month by forward month basis, the Company obtains observable market data for valuing its contracts. The data utilized falls into a fair value hierarchy as defined by SFAS No. 157. The fair value hierarchy gives the highest priority to quoted prices in active markets and the lowest priority to unobservable data. The fair value hierarchy is summarized as follows:
| | Level 1 – quoted prices in active markets for identical assets or liabilities that may be accessed at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. The Company utilizes the New York Mercantile Exchange “NYMEX” for its Level 1 valuations. |
| | Level 2 – (a) quoted prices for similar assets or liabilities in active markets, (b) quoted prices for identical assets or liabilities but in markets that are not actively traded or in which little information is released to the public, (c) observable inputs other than quoted prices and (d) inputs derived from observable market data. |
| | Level 3 – Unobservable market data inputs for assets or liabilities. |
The Company adopted SFAS No. 157 effective January 1, 2008 and the adoption did not have a material impact on financial assets or liabilities recorded at fair value. As of March 31, 2009, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):
| | | | | | | |
| | | Level 1 | | | Level 2 | | | Level 3 | | | | |
| | | | | | | | | | | | | |
| Derivatives | | | | | | | | | | | | |
| - Current assets | | $ | 768 | | | $ | 6,317 | | | $ | - | | | $ | 7,085 | |
| - Long-term assets | | | - | | | | 75 | | | | - | | | | 75 | |
| - Current liabilities | | | (46 | ) | | | (6,404 | ) | | | - | | | | (6,450 | ) |
| - Long-term liabilities | | | - | | | | (67 | ) | | | - | | | | (67 | ) |
| Net Value | | $ | 722 | | | $ | (79 | ) | | $ | - | | | $ | 643 | |
When determining fair value measurements, the Company makes credit valuation adjustments to reflect both its own nonperformance risk and its counterparty’s nonperformance risk. When adjusting the fair value of derivative contracts for the effect of nonperformance risk, the impact of netting and any applicable credit enhancements, such as collateral postings, thresholds, and guarantees are considered. Credit valuation adjustments utilize Level 3 inputs, such as credit scores to evaluate the likelihood of default by the Company or its counterparties. As of March 31, 2009, credit valuation adjustments were not significant to the overall valuation of the Company’s fair value contracts. As a result, applicable fair value assets and liabilities in their entirety are classified in Level 2 of the fair value hierarchy.
New Accounting Pronouncements
In February 2008, the FASB issued FASB Staff Position No. FAS 157-2, “Effective Date of FASB Statement No. 157”, (“FSP FAS No. 157-2”). This Staff Position amends SFAS No. 157 to delay the effective date of SFAS No. 157 for non-financial assets and non-financial liabilities until fiscal years beginning after November 15, 2008, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis. The adoption of the additional provisions of SFAS No. 157 did not have a material effect on the Company’s financial position, results of operations or cash flows.
In March 2008, the FASB issued SFAS No. 161, “Disclosures about Derivative Instruments and Hedging Activities – an amendment of FASB Statement No. 133”, as amended and interpreted. SFAS No. 161 changes the disclosure requirements for derivative instruments and hedging activities. Entities are required to provide enhanced disclosures about (a) how and why an entity uses derivative instruments, (b) how derivative instruments and related hedged items are accounted for under SFAS No. 133 and its related interpretations and (c) how derivative instruments and related hedged items affect an entity’s financial position, financial performance, and cash flows. The Company adopted SFAS No. 161 effective January 1, 2009. The disclosures required by SFAS No. 161 are presented above.
In December 2008, the Securities and Exchange Commission released Final Rule, Modernization of Oil and Gas Reporting to revise the existing Regulation S-K and Regulation S-X reporting requirements to align with current industry practices and technological advances. The new disclosure requirements include provisions that permit the use of new technologies to determine proved reserves if those technologies have been demonstrated empirically to lead to reliable conclusions about reserve volumes. In addition, the new disclosure requirements require a company to (a) disclose its internal control over reserves estimation and report the independence and qualification of its reserves preparer or auditor, (b) file reports when a third party is relied upon to prepare reserves estimates or conducts a reserve audit and (c) report oil and gas reserves using an average price based upon the prior 12-month period rather than period-end prices. The disclosures required by this ruling will become effective for the Company’s Annual Report on Form 10-K for the year ended December 31, 2009.
In April 2009, the FASB issued FASB Staff Position No. 157-4, “Determining Fair Value When the Volume and Level of Activity for the Asset or Liability have Significantly Decreased and Identifying Transactions that are not Orderly,” (“FSP No. FAS 157-4”). FSP No. FAS 157-4 provides additional guidance for estimating fair value under FAS No. 157 when the volume and level of market activity for an asset or liability have significantly decreased when compared with normal market activity for the asset or liability. If there is a significant decrease in the volume and activity for the asset or liability, transactions or quoted prices may not be determinative of fair value in an orderly transaction and further analysis and adjustment of the transactions or quoted prices may be necessary. FSP No. FAS 157-4 is effective for the quarter ended June 30, 2009 and the Company does not anticipate any significant adjustments to its estimates of fair value for assets and liabilities measured at fair value upon adoption.
In April 2009, the FASB issued FASB Staff Position No. FAS 107-1 and APB 28-1, “Interim Disclosures about Fair Value of Financial Instruments,” (“FSP No. FAS 107-1 and APB 28-1”). FSP No. FAS 107-1 and APB 28-1 amends SFAS No. 107, “Disclosures about Fair Value of Financial Instruments” to require disclosures about the fair value of financial instruments for interim reporting periods. FSP No. FAS 107-1 and APB 28-1 is effective for the quarter ended June 30, 2009 and the Company does not anticipate any significant adjustments to its financial position, results of operations or cash flows upon adoption.
Note 3 – Segment Reporting
The Company is primarily engaged in the business of marketing crude oil, natural gas and petroleum products as well as tank truck transportation of liquid chemicals and oil and gas exploration and production. Information concerning the Company’s various business activities is summarized as follows (in thousands):
| | | | | | Segment | | | Depreciation | | | Property and | |
| | | | | | Operating | | | Depletion and | | | Equipment | |
| | | Revenues | | | Earnings (Loss) | | | Amortization | | | Additions | |
| For the three months ended | | | | | | | | | | | | |
| March 31, 2009 | | | | | | | | | | | | |
| Marketing | | | | | | | | | | | | |
| - Crude Oil | | $ | 300,453 | | | $ | 3,831 | | | $ | 529 | | | $ | 658 | |
| - Natural gas | | | 3,907 | | | | 1,352 | | | | 41 | | | | - | |
| - Refined Products | | | 22,752 | | | | 265 | | | | 136 | | | | 129 | |
| Marketing Total | | | 327,112 | | | | 5,448 | | | | 706 | | | | 787 | |
| Transportation | | | 10,943 | | | | (178 | ) | | | 914 | | | | 1,144 | |
| Oil and gas | | | 2,086 | | | | (160 | ) | | | 811 | | | | 2,976 | |
| | | $ | 340,141 | | | $ | 5,110 | | | $ | 2,431 | | | $ | 4,907 | |
| March 31, 2008 | | | | | | | | | | | | | | | | |
| Marketing | | | | | | | | | | | | | | | | |
| - Crude oil | | $ | 895,412 | | | $ | 4,285 | | | $ | 329 | | | $ | 4,369 | |
| - Natural gas | | | 2,860 | | | | 532 | | | | 40 | | | | - | |
| - Refined products | | | 47,365 | | | | (615 | ) | | | 147 | | | | 61 | |
| Marketing Total | | | 945,637 | | | | 4,202 | | | | 516 | | | | 4,430 | |
| Transportation | | | 16,404 | | | | 760 | | | | 957 | | | | 350 | |
| Oil and gas | | | 3,947 | | | | 956 | | | | 1,565 | | | | 2,105 | |
| | | $ | 965,988 | | | $ | 5,918 | | | $ | 3,038 | | | $ | 6,885 | |
Segment operating earnings reflect revenues net of operating costs and depreciation, depletion and amortization. Segment earnings reconcile to earnings from continuing operations before income taxes as follows (in thousands):
| | | Three months ended | |
| | | | |
| | | | | | | |
| Segment operating earnings | | $ | 5,110 | | | $ | 5,918 | |
| - General and administrative | | | (2,310 | ) | | | (2,917 | ) |
| Operating earnings | | | 2,800 | | | | 3,001 | |
| - Interest income | | | 32 | | | | 355 | |
| - Interest expense | | | (6 | ) | | | (4 | ) |
| Earnings before income tax | | $ | 2,826 | | | $ | 3,352 | |
Identifiable assets by industry segment are as follows (in thousands):
| | | March 31, | | | December 31, | |
| | | | | | | |
| Marketing | | | | | | |
| - Crude oil | | $ | 90,026 | | | $ | 85,774 | |
| - Natural gas | | | 37,674 | | | | 46,599 | |
| - Refined products | | | 11,257 | | | | 13,037 | |
| Marketing Total | | | 138,957 | | | | 145,410 | |
| Transportation | | | 14,815 | | | | 14,915 | |
| Oil and gas | | | 23,053 | | | | 21,904 | |
| Other | | | 32,162 | | | | 28,697 | |
| | | $ | 208,987 | | | $ | 210,926 | |
Intersegment sales are insignificant. Other identifiable assets are primarily corporate cash, accounts receivable, and properties not identified with any specific segment of the Company’s business. All sales by the Company occurred in the United States.
Note 4 - Transactions with Affiliates
Mr. K. S. Adams, Jr., Chairman and Chief Executive Officer, and certain of his family partnerships and affiliates have participated as working interest owners with the Company’s subsidiary, Adams Resources Exploration Corporation. Mr. Adams and such affiliates participate on terms similar to those afforded other non-affiliated working interest owners. In recent years, such related party transactions generally result after the Company has first identified oil and gas prospects of interest. Typically the available dollar commitment to participate in such transactions is greater than the amount management is comfortable putting at risk. In such event, the Company first determines the percentage of the transaction it wants to obtain, which allows a related party to participate in the investment to the extent there is excess available. In those instances where there was no excess availability there has been no related party participation. Similarly, related parties are not required to participate, nor is the Company obligated to offer any such participation to a related or other party. When such related party transactions occur, they are individually reviewed and approved by the Audit Committee comprised of the independent directors on the Company’s Board of Directors. During the first quarter of 2009 and 2008, the Company’s investment commitments totaled approximately $3.3 million and $1.1 million, respectively, in those oil and gas projects where a related party was also participating in such investments. As of March 31, 2009 and December 31, 2008, the Company owed a combined net total of $47,000 and $89,000, respectively, to these related parties. In connection with the operation of certain oil and gas properties, the Company also charges such related parties for administrative overhead primarily as prescribed by the Council of Petroleum Accountants Society Bulletin 5. Such overhead recoveries totaled $34,000 and $32,000 for the three-month periods ended March 31, 2009 and 2008, respectively, and are included in oil and gas segment operating expenses.
The Company also enters into certain transactions in the normal course of business with other affiliated entities including direct cost reimbursement for shared phone and secretarial services. For the three-month period ended March 31, 2009 and 2008, the affiliated entities charged the Company $29,000 and $16,000, respectively, of expense reimbursement and the Company charged the affiliates $40,000 and $24,000, respectively, for such expense reimbursements.
Note 5 - Commitments and Contingencies
Under certain of the Company’s automobile and workers compensation insurance policies, the Company can either receive a return of premium paid or be assessed for additional premiums up to pre-established limits. Additionally, in certain instances the risk of insured losses is shared with a group of similarly situated entities. As of March 31, 2009, management has appropriately recognized estimated expenses and liability related to the program.
From time to time as incidental to its operations, the Company becomes involved in various lawsuits and/or disputes. Primarily as an operator of an extensive trucking fleet, the Company is a party to motor vehicle accidents, worker compensation claims and other items of general liability as would be typical for the industry. Management of the Company is presently unaware of any claims against the Company that are either outside the scope of insurance coverage, or that may exceed the level of insurance coverage, and could potentially represent a material adverse effect on the Company’s financial position or results of operations.
Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Results of Operations
Marketing segment revenues, operating earnings and depreciation are presented as follows (in thousands):
| | | | | | Segment | | | Depreciation | |
| | | | | | Operating | | | Depletion and | |
| | | Revenues | | | Earnings | | | Amortization | |
| Period ended March 31, 2009 | | | | | | | | | |
| | | | | | | | | | |
| - Crude Oil | | $ | 300,453 | | | $ | 3,831 | | | $ | 529 | |
| - Natural gas | | | 3,907 | | | | 1,352 | | | | 41 | |
| - Refined Products | | | 22,752 | | | | 265 | | | | 136 | |
| Total | | $ | 327,112 | | | $ | 5,448 | | | $ | 706 | |
| | | | | | | | | | | | | |
| Period ended March 31, 2008 | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| - Crude oil | | $ | 895,412 | | | $ | 4,285 | | | $ | 329 | |
| - Natural gas | | | 2,860 | | | | 532 | | | | 40 | |
| - Refined products | | | 47,365 | | | | (615 | ) | | | 147 | |
| Total | | $ | 945,637 | | | $ | 4,202 | | | $ | 516 | |
Supplemental volume and price information is as follows:
| | | Three Months Ended | |
| | | | |
| | | | | | | |
| | | | | | | |
Field Level Purchase Volumes – Per day (1) | | | | | | |
| Crude oil – barrels | | | 68,537 | | | | 63,965 | |
| Natural gas – mmbtu’s | | | 391,492 | | | | 459,513 | |
| | | | | | | | | |
| Average Purchase Price | | | | | | | | |
| Crude Oil – per barrel | | $ | 38.24 | | | $ | 98.85 | |
| Natural Gas – per mmbtu | | $ | 4.36 | | | $ | 8.27 | |
_________________
(1) Reflects the volume purchased from third parties at the oil and gas field level.
Crude oil revenues were reduced for the comparative current period because of significantly lower crude oil prices as shown in the table above. While overall crude oil prices were reduced during the first quarter of 2009, the direction of change in prices initially declined but then increased during the period. The average acquisition price of crude oil moved from the $41 per barrel level at the beginning of the year to $48 per barrel for the March 2009 average price. This event produced a first quarter 2009 inventory liquidation gain of $1,325,000. A similar event occurred in the first quarter of 2008 as crude oil prices rose from the $90 per barrel range in January 2008 to the $105 per barrel range in March 2008 producing a $1,967,000 inventory liquidation gain. As of March 31, 2009 the Company held 184,045 barrels of crude oil inventory at an average price of $47.75 per barrel.
Natural gas sales are reported net of underlying natural gas purchase costs and thus reflect gross margin. As shown above, such margins were increased in the first quarter of 2009 relative to 2008. Such increase reflects a return to more normal margin levels as the Company’s natural gas margins were compressed due to competitive pressures existing in the marketplace.
Last year’s refined products segment operating loss occurred because the rate of increase in the crude oil driven supply cost of motor fuel exceeded the rate of increase in the market value of such fuels. As a result, per unit margins narrowed and did not cover fixed operating expenses. Also, the Company’s supplier of biodiesel fuel failed to deliver scheduled product resulting in a direct loss to the Company of approximately $400,000. The product was contracted to the Company at a fixed price and the Company had entered into an offsetting price protection agreement (a swap). Although the underlying material did not ship as scheduled, the Company honored its swap commitment producing the resulting loss. Subsequently, the Company has revised the terms of its biodiesel fuel supply contracts to shift the price risk to the supplier in order to avoid the recurrence of such items.
- Transportation
Transportation segment revenues, earnings and depreciation are as follows (in thousands):
| | | Three Months Ended | | | | |
| | | | | | Increase | |
| | | | | | | | | | |
| | | | | | | | | | |
| Revenues | | $ | 10,943 | | | $ | 16,404 | | | | (33 | )% |
| | | | | | | | | | | | | |
| Operating earnings (loss) | | $ | (178 | ) | | $ | 760 | | | | (123 | )% |
| | | | | | | | | | | | | |
| Depreciation | | $ | 914 | | | $ | 957 | | | | (4 | )% |
Revenues are decreased and operating results turned to a loss for the transportation segment due to a lack of customer demand during the first quarter of 2009. The Company’s customers are predominately the domestic United States petrochemical industry, and demand for such products is driven primarily by activity within the housing and automotive sectors. The current national economic recession has severely and adversely impacted this segment of the Company’s business. Customer demand is down approximately 30% and, to date, has shown few signs of recovery. In March 2009, the Company instituted cost cutting measures including a reduction in personnel levels in order to better align costs with the Company’s level of revenues.
- Oil and Gas
Oil and gas segment revenues and operating earnings are primarily a function of crude oil and natural gas prices and volumes. Comparative amounts for revenues, operating earnings and depreciation and depletion are as follows (in thousands):
| | | Three Months Ended | | | | |
| | | | | | | |
| | | | | | | | | | |
| Revenues | | $ | 2,086 | | | $ | 3,947 | | | | (47 | )% |
| | | | | | | | | | | | | |
| Operating earnings (loss) | | $ | (160 | ) | | $ | 956 | | | | (117 | )% |
| | | | | | | | | | | | | |
| Depreciation and depletion | | $ | 811 | | | $ | 1,565 | | | | (48 | )% |
The revenue and earnings decline for the oil and gas segment is attributable to decreased crude oil and natural gas prices as shown in the tables below. Depreciation and depletion expense is reduced in the current period because a significant decline in hydrocarbon prices at year-end December 31, 2008 caused significant impairment provisions to be recorded. Such charges reduced the level of capitalized costs for amortizing in the current period.
Production volumes and prices were as follows (in thousands):
| | | Three Months Ended | |
| | | | |
| | | | | | | |
| Crude Oil | | | | | | |
| Volume – barrels | | | 14,262 | | | | 11,967 | |
| Average price per barrel | | $ | 39.62 | | | $ | 100.63 | |
| | | | | | | | | |
| Natural gas | | | | | | | | |
| Volume – mcf | | | 329,751 | | | | 287,162 | |
| Average price per mcf | | $ | 4.61 | | | $ | 9.55 | |
Exploration costs were as follows (in thousands):
| | | Three Months Ended | |
| | | | |
| | | | | | | |
| Dry hole expense | | $ | 224 | | | $ | 90 | |
| Prospect impairments | | | 124 | | | | 197 | |
| Seismic and geological | | | 185 | | | | 173 | |
| | | | | | | | | |
| Total | | $ | 533 | | | $ | 460 | |
During the first three months of 2009, the Company participated in the drilling of 12 successful wells with three dry holes. Additionally, the Company has an interest in eight wells that were in process on March 31, 2009. Evaluation on the in-process wells is anticipated during the second quarter of 2009. Participation in the drilling of approximately 20 wells is planned for the remainder of 2009 on the Company’s prospect acreage in Arkansas, Louisiana and Texas.
- Outlook
Management anticipates continued relative strength for the marketing segment. Results from the transportation segment are expected to track with the overall national economy, although cost reductions should return this segment to profitable levels. Reduced natural gas prices will continue to hamper results from the Company’s oil and gas segment. Originally planned drilling activity for 2009 has been scaled back with current pricing conditions calling for caution in this area.
Liquidity and Capital Resources
The Company’s liquidity primarily derives from net cash provided from operating activities and such amount was $8,984,000 and $9,176,000 for each of the three-month periods ended March 31, 2009 and 2008, respectively. As of March 31, 2009 and December 31, 2008, the Company had no bank debt or other forms of debenture obligations. Cash and cash equivalents totaled $22,311,000 as of March 31, 2009, and such balances are maintained in order to meet the timing of day-to-day cash needs. Working capital, the excess of current assets over current liabilities, totaled $42,198,000 as of March 31, 2009. Management believes current cash balances, together with expected cash generated from future operations, will be sufficient to meet short-term and long-term liquidity needs.
The Company utilizes cash from operations to make discretionary investments in its oil and natural gas exploration, marketing and transportation businesses, which comprise substantially all of the Company’s investing cash outflows for each of the past three years. The Company does not look to proceeds from property sales to fund its cash flow needs. Except for a total of $3.2 million in operating lease payments for transportation equipment and office lease space, the Company’s future commitments and planned investments can be readily curtailed if operating cash flows contract.
Capital expenditures during the first three months of 2009 included $1,931,000 for marketing and transportation equipment additions and $2,976,000 in property additions associated with oil and gas exploration and production activities. For 2009, the Company anticipates expending an additional approximate $5 million on oil and gas exploration projects to be funded from operating cash flow and available working capital. In addition, approximately $2.2 million will be expended during the second half of 2009 toward the purchase of 110 tractors scheduled to come off lease financing with funding for such purchase from available cash flow.
Historically, the Company pays an annual dividend in the fourth quarter of each year, and the Company last paid a $.50 per common share or $2,109,000 dividend to shareholders of record as of December 2, 2008. The most significant item affecting future increases or decreases in liquidity is earnings from operations and such earnings are dependent on the success of future operations (see Item 1A Risk Factors in the annual report on Form 10-K for the year ended December 31, 2008). While the Company has available bank lines of credit (see below), management has no current intention to utilize such lines of credit or issue additional equity.
- Banking Relationships
The Company’s primary bank loan agreement with Bank of America provides for two separate lines of credit with interest at the bank’s prime rate minus ¼ of one percent. The working capital loan provides for borrowings based on 80 percent of eligible accounts receivable and 50 percent of eligible inventories. Available capacity under the line is calculated monthly and as of March 31, 2009 the Company elected to establish the line at $5 million. The oil and gas production loan provides for flexible borrowings subject to a borrowing base requested by the Company and approved semi-annually by the bank. The borrowing base was established at $5 million as of March 31, 2009. The working capital facilities are subject to a ½ of one percent commitment fee. The line of credit loans are scheduled to expire on October 31, 2009, with the then present balance outstanding, if any, converting to a term loan payable in eight equal quarterly installments. As of March 31, 2009 and December 31, 2008 there was no bank debt outstanding under the Company’s two revolving credit facilities.
The Bank of America loan agreement, among other things, places certain restrictions with respect to additional borrowings and the purchase or sale of assets, as well as requiring the Company to comply with certain financial covenants, including maintaining a 1.0 to 1.0 ratio of consolidated current assets to consolidated current liabilities, maintaining a 2.0 to 1.0 ratio of earnings before interest and taxes to interest expense, and consolidated net worth in excess of $61,844,000. Should the Company’s net worth fall below this threshold, the Company may be restricted from payment of additional cash dividends on its common stock. The Company is in compliance with these restrictions.
Critical Accounting Policies and Use of Estimates
There has been no material changes to the Company’s “Critical Accounting Policies and Use of Estimates” disclosures that have occurred since the disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008.
Item 3. Quantitative and Qualitative Disclosures about Market Risk
There has been no material changes to the Company’s “Quantitative and Qualitative Disclosures about Market Risk” that have occurred since the disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008.
Forward-Looking Statements –Safe Harbor Provisions
This quarterly report for the period ended March 31, 2009 contains certain forward-looking statements covered by the safe harbors provided under Federal securities law and regulations. To the extent such statements are not recitations of historical fact, forward-looking statements involve risks and uncertainties. In particular, statements included herein and/or in the Company’s latest annual report on Form 10-K under the captions (a) Production and Reserve Information, (b) Regulatory Status and Potential Environmental Liability, (c) Management’s Discussion and Analysis of Financial Condition and Results of Operations, (d) Critical Accounting Policies and Use of Estimates, (e) Quantitative and Qualitative Disclosures about Market Risk, (f) Income Taxes, (g) Concentration of Credit Risk, (h) Price Risk Management Activities, and (i) Commitments and Contingencies, among others, contain forward-looking statements. Where the Company expresses an expectation or belief regarding future results of events, such expression is made in good faith and believed to have a reasonable basis in fact. However, there can be no assurance that such expectation or belief will actually result or be achieved.
With the uncertainties of forward looking statements in mind, the reader should consider the risks discussed elsewhere in this report and other documents filed with the Securities and Exchange Commission from time to time and the important factors described in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008, under “Item 1A Risk Factor” that could cause actual results to differ materially from those expressed in any forward-looking statement made by or on behalf of the Company
Item 4. Disclosure Controls and Procedures
The Company maintains “disclosure controls and procedures” (as defined in Rule 13a-15(e) and 15d-15(e) under the Securities and Exchange Act of 1934, as amended (the “Exchange Act”) that are designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Exchange Act are recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely discussions regarding required disclosure. As of the end of the period covered by this quarterly report, an evaluation was carried out under the supervision and with the participation of the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based upon that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that the design and operation of these disclosure controls and procedures were effective as of March 31, 2009.
Changes in Internal Control over Financial Reporting.
There have not been any changes in the Company’s internal control over financial reporting during the fiscal quarter ended March 31, 2009 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
PART II. OTHER INFORMATION
Item 1.
From time to time as incident to its operations, the Company becomes involved in various lawsuits and/or disputes. Primarily as an operator of an extensive trucking fleet, the Company may be a party to motor vehicle accidents, worker compensation claims or other items of general liability as would be typical for the industry. Except as disclosed herein, management of the Company is presently unaware of any claims against the Company that are either outside the scope of insurance coverage, or that may exceed the level of insurance coverage, and could potentially represent a material adverse effect on the Company’s financial position or results of operations.
| | Item 1A. - There are no material changes in the Company’s risk factors from those disclosed in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008. |
Item 3. - None
Item 4. - None
Item 5. – None
Item 6. Exhibits
| 31.1 | Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| | |
| 31.2 | Certification of Chief Financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| | |
| 32.1 | Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley of 2002 |
| | |
| 32.2 | Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
| | |
Pursuant to 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.
| | ADAMS RESOURCES & ENERGY, INC |
| | (Registrant) |
| | |
| | |
| | |
| Date: May 13, 2009 | By /s/K. S. Adams, Jr. |
| | K. S. Adams, Jr. |
| | Chief Executive Officer |
| | |
| | |
| | By /s/Frank T. Webster |
| | Frank T. Webster |
| | President & Chief Operating Officer |
| | |
| | |
| | By /s/Richard B. Abshire |
| | Richard B. Abshire |
| | Chief Financial Officer |
EXHIBIT INDEX
| Exhibit | |
| Number | Description |
| | |
| 31.1 | Certificate of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| | |
| 31.2 | Certificate of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| | |
| 32.1 | Certificate of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
| | |
| 32.2 | Certificate of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
