ADAMS RESOURCES & ENERGY, INC. - Quarter Report: 2008 June (Form 10-Q)

body_10q.htm

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D. C. 20549

FORM 10-Q

(Mark One)

x	Quarterly report pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2008

o	Transition report pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934

For the transition period from ______________to

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 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 filero Accelerated filero Non-accelerated filerx Smaller Reporting Companyo

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 August 1, 2008.

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)

	Six Months Ended						Three Months Ended
	June 30,						June 30,
	2008			2007			2008			2007
REVENUES:
Marketing	$	2,201,820		$	1,017,489		$	1,256,183		$	548,348
Transportation		35,383			31,646			18,979			17,844
Oil and gas		9,137			6,979			5,190			3,556
		2,246,340			1,056,114			1,280,352			569,748
COSTS AND EXPENSES:
Marketing		2,189,169			1,008,461			1,248,250			542,812
Transportation		31,344			26,248			16,657			14,339
Oil and gas operations		4,201			5,111			2,775			2,223
Oil and gas property sale		-			(12,078	)		-			(12,078	)
General and administrative		5,420			5,184			2,503			2,582
Depreciation, depletion and amortization		6,072			4,766			3,034			2,275
		2,236,206			1,037,692			1,273,219			552,153

Operating earnings		10,134			18,422			7,133			17,595
Other income (expense):
Interest income		571			823			216			456
Interest expense		(45	)		(63	)		(41	)		(32	)
Earnings before income taxes		10,660			19,182			7,308			18,019

Income tax provision		3,624			6,984			2,483			6,733

Net earnings	$	7,036		$	12,198		$	4,825		$	11,286

EARNINGS PER SHARE:
Basic and diluted net earnings
per common share	$	1.67		$	2.89		$	1.15		$	2.67

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)

	June 30,			December 31,
	2008			2007
ASSETS

Current assets:
Cash and cash equivalents	$	22,676		$	23,697
Accounts receivable, net of allowance for doubtful
accounts of $720 and $192, respectively		376,199			261,710
Inventories		24,472			14,776
Fair value contracts		20,567			5,388
Income tax receivables		14			2,554
Prepayments		3,940			3,768

Total current assets		447,868			311,893

Property and equipment		118,174			110,526
Less – accumulated depreciation,
depletion and amortization		(76,529	)		(70,828	)
		41,645			39,698
Other assets:
Fair value contracts		4,131			1,563
Cash deposits and other		3,602			3,921
	$	497,246		$	357,075

LIABILITIES AND SHAREHOLDERS’ EQUITY

Current liabilities:
Accounts payable	$	366,351		$	252,310
Accounts payable – related party		285			84
Fair value contracts		18,842			4,116
Accrued and other liabilities		5,754			3,707
Current deferred income taxes		1,104			1,104
Total current liabilities		392,336			261,321

Other liabilities:
Asset retirement obligations		1,195			1,153
Deferred income taxes and other		3,309			4,063
Fair value contracts		3,928			1,096
		400,768			267,633
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		84,363			77,327
Total shareholders’ equity		96,478			89,442
	$	497,246		$	357,075

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)

	Six Months Ended
	June 30,
	2008			2007
CASH PROVIDED BY OPERATIONS:
Net earnings	$	7,036		$	12,198
Adjustments to reconcile net earnings to net cash
provided by operating activities -
Depreciation, depletion and amortization		6,072			4,766
Gains on property sales		(15	)		(12,034	)
Dry hole costs incurred		669			1,376
Impairment on oil and gas properties		872			409
Allowance for doubtful accounts		528			78
Other, net		(178	)		169
Decrease (increase) in accounts receivable		(115,017	)		(5,450	)
Decrease (increase) in inventories		(9,696	)		(5,097	)
Fair value contracts		(189	)		(129	)
Decrease (increase) in tax receivable		2,540			375
Decrease (increase) in prepayments		(172	)		(8,183	)
Increase (decrease) in accounts payable		114,253			12,259
Increase (decrease) in accrued liabilities		2,047			(3,803	)
Deferred income taxes		(744	)		746


Net cash provided by (used in) operating activities		8,006			(2,320	)

INVESTING ACTIVITIES:
Property and equipment additions		(9,595	)		(8,506	)
Insurance and tax deposits		529			(350	)
Proceeds from property sales		39			15,319
Redemption of short-term investments		10,000			-
Investment in short-term investments		(10,000	)		-

Net cash (used in) investing activities		(9,027	)		6,463

FINANCING ACTIVITIES:
Net repayments under credit agreements		-			(3,000	)

Net cash used in financing activities		-			(3,000	)

Increase in cash and cash equivalents		(1,021	)		1,143

Cash at beginning of period		23,697			20,668

Cash at end of period	$	22,676		$	21,811

Supplemental disclosure of cash flow information:

Interest paid during the period	$	45		$	67

Income taxes paid during the period	$	270		$	5,373

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 June 30, 2008, its results of operations and its cash flows for the six months ended June 30, 2008 and 2007. 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

Principles of Consolidation

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. Certain reclassifications have been made to prior year amounts in order to conform to current year presentations.

Nature of Operations

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.

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market fund or federal funds with maturity of 30 days or less. Depending on cash availability, auction rate investments in municipal bonds and bond mutual funds may also be made from time to time depending on market conditions. The Company invests in tax-free municipal securities in order to enhance the after-tax rate of return from short-term investments of cash. The Company had no auction rate investments as of June 30, 2008 and December 31, 2007.

Allowance for Doubtful Accounts

Accounts receivable result from sales of crude oil, natural gas, and refined products as well as from trucking services. Marketing segment wholesale level sales of crude oil and natural gas comprise in excess of ninety percent of accounts receivable and under industry practices, such items are “settled” and paid in cash on the twenty and twenty-five day, respectively, of the month following the transaction date. For such receivables, an allowance for doubtful accounts is determined based on specific account identification. The balance of accounts receivable results from sales of refined petroleum products and trucking services. For this component of receivables, the allowance for doubtful accounts is determined based on a review of specific accounts combined with a review of the general status of the aging of all accounts.

Inventories

Crude oil and petroleum product inventories are carried at the lower of cost or market. Petroleum products inventory includes gasoline, lubricating oils and other petroleum products purchased for resale. Petroleum products and crude oil inventory is valued at average cost. Components of inventory are as follows (in thousands):

	June 30,		December 31,
	2008		2007

Crude oil	$	22,065	$	12,437
Petroleum products		2,407		2,339

	$	24,472	$	14,776

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 capitalized costs of drilling the well are charged to expense. Costs incurred to drill and complete development wells, including dry holes, are capitalized. As of June 30, 2008, 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 recoverable 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 for impairment on a field-by-field basis. Any impairment recognized is permanent and may not be restored. For the six-month periods ended June 30, 2008 and 2007, there were impairment provisions totaling zero and $11,000, respectively, 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 $872,000 and $397,000 were recorded for the six-month periods ended June 30, 2008 and 2007, respectively.

Other Assets

Other assets primarily consist of cash deposits associated with the Company’s business activities. The Company has established certain deposits to support its participation in its liability insurance program and such deposits totaled $2,723,000 and $3,040,000 as of June 30, 2008 and December 31, 2007, respectively. In addition, the Company maintains certain deposits to support the collection and remittance of state crude oil severance taxes. Such deposits totaled $120,000 and $333,000 as of June 30, 2008 and December 31, 2007, respectively.

Revenue Recognition

Commodity purchases and sales associated with the Company’s natural gas marketing activities qualify as derivative instruments under Statement of Financial Accounting Standards (“SFAS”) No. 133. Therefore, natural gas purchases and sales are 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”. In contrast, a significant portion of crude oil purchases and sales qualify, and have been designated as, normal purchases and sales. Therefore, crude oil purchases and sales are primarily recorded on a gross revenue basis in the accompanying financial statements. Those purchases and sales of crude oil that do not qualify as “normal purchases and sales” are recorded on a net revenue basis in the accompanying financial statements. For “normal purchase and sale” activities, the Company’s customers are invoiced monthly based on contractually agreed upon terms and revenue is recognized in the month in which the physical product is delivered to the customer. Where required, the Company recognizes fair value or mark-to-market gains and losses related to its natural gas and crude oil trading activities. A detailed discussion of the Company’s risk management activities is included later in this footnote.

Substantially all of the Company’s petroleum products marketing activity qualify as a “normal purchase and sale” and revenue is recognized in the period when the customer physically takes possession and title to the product upon delivery at their facility. The Company recognizes fair value or mark-to- market gains and losses on refined product marketing activities that do not qualify as “normal purchases and sales”.

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.

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 the three-month and six-month periods ended June 30, 2008 and 2007. There were no potentially dilutive securities during those periods in 2008 and 2007.

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 condensed 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.

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.

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 such adoption did not have a material impact on net asset values. As of June 30, 2008, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Level 1			Level 2			Level 3
	Quoted Prices			Observable			Unobservable		Total
Derivatives
- Current assets	$	2,132		$	18,435		$	-	$	20,567
- Long-term assets		-			4,131			-		4,131
- Current liabilities		(231	)		(18,611	)		-		(18,842	)
- Long-term liabilities		(46	)		(3,882	)		-		(3,928	)
Net Value	$	1,855		$	73		$	-	$	1,928

The Company’s fair value contracts give rise to market risk, which represents the potential loss that may result from a change in the market value of a particular commitment. The Company monitors and manages its exposure to market risk to ensure compliance with the Company’s risk management policies. Such policies are regularly assessed to ensure their appropriateness given management’s objectives, strategies and current market conditions.

Asset Retirement Obligations

The Company records a long-term liability for the estimated retirement costs associated with certain tangible long-lived assets. The estimated fair value of such asset retirement obligations are recorded in the period in which they are incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

In addition to an accrual for asset retirement obligations, the Company maintains $75,000 in escrow cash, which is legally restricted for the potential purpose of settling asset retirement costs in accordance with certain state regulations. Such cash deposits are included in other assets in the accompanying balance sheet.

New Accounting Pronouncements

In February 2007, the Financial Accounting Standards Board “FASB” issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities”. SFAS No. 159 provides an entity with the option to measure certain assets and liabilities and other items at fair value, with changes in fair value recognized in earnings as those changes occur. The provisions of SFAS No. 159 do not affect the fair value measurement of derivative financial instruments under SFAS No. 133 as shown above. The provisions of SFAS No. 159 became effective beginning January 1, 2008. Management did not elect the fair value option for any eligible financial assets or liabilities not already carried at fair value.

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. SFAS No. 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008. Early adoption is permitted. The Company is currently evaluating the impact the adoption of SFAS No. 161 will have on its financial statements.

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 Company is currently assessing the impact of applying FSP FAS No. 157-2 to its non-financial assets and liabilities. Future financial statements are expected to include enhanced disclosures with respect to fair value measurements.

Note 3 – Segment Reporting

The Company is primarily engaged in the business of marketing crude oil, natural gas and petroleum products; 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):

- Six Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended June 30, 2008
Marketing
- Crude Oil	$	2,083,642	$	11,234		$	902	$	4,627
- Natural gas		6,004		1,282			81		-
- Refined products		112,174		(1,142	)		294		79
Marketing Total		2,201,820		11,374			1,277		4,706
Transportation		35,383		2,131			1,908		397
Oil and gas		9,137		2,049			2,887		4,481
	$	2,246,340	$	15,554		$	6,072	$	9,584
Period Ended June 30, 2007
Marketing
- Crude Oil	$	932,727	$	5,661		$	307	$	427
- Natural gas		6,668		2,492			70		52
- Refined products		78,094		286			212		268
Marketing Total		1,017,489		8,439			589		747
Transportation		31,646		3,159			2,239		159
Oil and gas		6,979		12,008			1,938		6,224
	$	1,056,114	$	23,606		$	4,766	$	7,130

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended June 30, 2008
Marketing
- Crude Oil	$	1,188,230	$	6,949		$	573	$	258
- Natural gas		3,144		750			41		-
- Refined products		64,809		(527	)		147		18
Marketing Total		1,256,183		7,172			761		276
Transportation		18,979		1,371			951		47
Oil and gas		5,190		1,093			1,322		2,376
	$	1,280,352	$	9,636		$	3,034	$	2,699
Period Ended June 30, 2007
Marketing
- Crude Oil	$	502,291	$	3,877		$	160	$	199
- Natural gas		3,232		1,198			55		17
- Refined products		42,825		141			105		106
Marketing Total		548,348		5,216			320		322
Transportation		17,844		2,433			1,072		121
Oil and gas		3,556		12,528			883		3,218
	$	569,748	$	20,177		$	2,275	$	3,661

Identifiable assets by industry segment are as follows (in thousands):

	June 30,		December 31,
	2008		2007
Marketing
- Crude oil	$	284,107	$	186,163
- Natural gas		114,609		74,585
- Refined products		23,825		21,844
Marketing Total		422,541		282,592
Transportation		19,341		18,282
Oil and gas		26,503		25,267
Other		28,861		30,934
	$	497,246	$	357,075

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.

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):

	Six months ended						Three months ended
	June 30,						June 30,
	2008			2007			2008			2007
Segment operating earnings	$	15,554		$	23,606		$	9,636		$	20,177
- General and administrative		(5,420	)		(5,184	)		(2,503	)		(2,582	)
Operating earnings		10,134			18,422			7,133			17,595
- Interest income		571			823			216			456
- Interest expense		(45	)		(63	)		(41	)		(32	)
Earnings before income taxes	$	10,660		$	19,182		$	7,308		$	18,019

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. For the first half of 2008 and 2007, the Company’s investment commitments totaled approximately $3 million and $4.3 million, respectively, in those oil and gas projects where a related party was also participating in such investments. As of June 30, 2008 and December 31, 2007, the Company owed a combined net total of $285,000 and $84,000, 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 (“COPAS”) Bulletin 5. Such overhead recoveries totaled $66,000 and $62,000 in the six-month periods ended June 30, 2008 and 2007, respectively.

David B. Hurst, Secretary of the Company, is a partner in the law firm of Chaffin & Hurst. The Company has been represented by Chaffin & Hurst since 1974 and plans to use the services of that firm in the future. Chaffin & Hurst currently leases office space from the Company. Transactions with Chaffin & Hurst are on the same terms as those prevailing at the time for comparable transactions with unrelated entities.

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 six-month period ended June 30, 2008 and 2007, the affiliated entities charged the Company $33,000 and $72,000, respectively, of expense reimbursement and the Company charged the affiliates $48,000 and $48,000, respectively, for such expense reimbursements.

Note 5 - Commitments and Contingencies

In March 2004, a suit styled Le Petit Chateau De Luxe, et. al. vs Great Southern Oil & Gas Co., et. al. was filed in the Civil District Court for Orleans Parish, Louisiana against the Company and its subsidiary, Adams Resources Exploration Corporation, among other defendants. The suit alleges that certain property in Acadia Parish, Louisiana was environmentally contaminated by oil and gas exploration and production activities during the 1970s and 1980s. An alleged amount of damage has not been specified. Management believes the Company has consistently conducted its oil and gas exploration and production activities in accordance with all environmental rules and regulations in effect at the time of operation. Management notified its insurance carrier about this claim, and thus far the insurance carrier has declined to offer coverage. The Company is litigating this matter with its insurance carrier. In any event, management does not believe the outcome of this matter will have a material adverse effect on the Company’s financial position or results of operations.

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 under the policies in certain instances the risk of insured losses is shared with a group of similarly situated entities. As of June 30, 2008, management has appropriately recognized estimated expenses and liability related to the program.

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

Results of Operations

Marketing

Marketing segment revenues, operating earnings and depreciation were as follows (in thousands):

	Six Months Ended					Three Months Ended
	June 30,					June 30,
	2008			2007		2008			2007
Revenues
Crude oil	$	2,083,642		$	932,727	$	1,188,230		$	502,291
Natural gas		6,004			6,668		3,144			3,232
Refined products		112,174			78,094		64,809			42,825
Total	$	2,201,820		$	1,017,489	$	1,256,183		$	548,348

Operating Earnings (loss)
Crude oil	$	11,234		$	5,661	$	6,949		$	3,877
Natural gas		1,282			2,492		750			1,198
Refined products		(1,142	)		286		(527	)		141
Total	$	11,374		$	8,439	$	7,172		$	5,216

Depreciation
Crude oil	$	902		$	307	$	573		$	160
Natural gas		81			70		41			55
Refined products		294			212		147			105
Total	$	1,277		$	589	$	761		$	320

Supplemental volume and price information is as follows:

	Six Months Ended				Three Months Ended
	June 30,				June 30,
	2008		2007		2008		2007
Field Level Purchase Volumes – Per day (1)
Crude oil – barrels		64,700		61,000		66,000		63,900
Natural gas – mmbtu’s		447,000		431,200		435,000		407,200

Average Purchase Price
Crude oil – per barrel	$	114.14	$	58.22	$	127.90	$	61.46
Natural Gas – per mmbtu’s	$	9.37	$	7.12	$	10.56	$	7.38

_____________________________

(1) Reflects the volume purchased from third parties at the oil and gas field level.

Crude oil revenues and operating earnings increased for the comparative current period because of an approximate doubling of crude oil prices as shown above. During the first half of 2008, average crude oil acquisition prices rose from the $90 per barrel level in January 2008 to the $133 per barrel level in June 2008. This event produced a first half 2008 inventory liquidation gain of $5,878,000 with $3,911,000 occurring during the second quarter. A similar but lesser event occurred in the first half of 2007 as crude oil prices rose from the $53 per barrel range in January 2007 to the $67 per barrel range in June 2007 producing a $1,600,000 inventory liquidation gain of which $839,000 occurred during the second quarter. As of June 30, 2008 the Company held 165,406 barrels of crude oil inventory at an average price of $133.40 per barrel.

Natural gas sales are reported net of underlying natural gas purchase costs and thus reflect gross margin. As shown above, operating margins were reduced throughout the first half of 2008 relative to 2007. During the current year, the marketplace has not provided the normal level of opportunities to enhance margins by meeting short-term day-to-day demand needs. The current condition results, in part, from 2008 weather patterns not stimulating localized demand spikes. The Company continues to add purchase volumes while still attempting to enhance per unit margins.

First half 2008 refined products operating losses occurred, in part, because the rate of increase in the crude oil driven supply cost of gasoline and diesel 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. Additionally, during the second quarter of 2008, the Company’s refined products segment increased its allowance for doubtful accounts receivable through a bad debt charge of $485,000. The Company has a number of construction industry customers experiencing significantly increased fuel costs coupled with a downturn in the housing development market. Since there is an elevated likelihood of this class of customer experiencing financial insolvency, the Company’s bad debt provision was increased accordingly. Also, adversely impacting results was a supplier’s failure to deliver biodiesel fuel as scheduled resulting in a direct loss to the Company of approximately $400,000 during the first quarter of 2008. 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 planned, the Company honored its swap commitment producing the resulting loss. The Company is pursuing recovery against the supplier.

Historically, prices received for crude oil and natural gas as well as derivative products have been volatile and unpredictable with price volatility expected to continue. See also discussion under Item 3 – Commodity Price Risk.

- Transportation

Transportation segment revenues, earnings and depreciation are as follows (in thousands):

	Six Months Ended							Three Months Ended
	June 30,				Increase			June 30,				Increase
	2008		2007		(Decrease)			2008		2007		(Decrease)

Revenues	$	35,383	$	31,646		11.8	%	$	18,979	$	17,844		6.3	%

Operating earnings	$	2,131	$	3,159		(32.5	)%	$	1,371	$	2,433		(43.6	)%

Depreciation	$	1,908	$	2,239		(14.7	)%	$	951	$	1,072		(11.3	)%

Transportation revenues include various component parts, the most significant being standard line haul charges, fuel adjustment charges and demurrage. Line haul revenues increased slightly during the first six months of 2008 to $25.2 million versus $24.4 million in the 2007 period as demand for the Company’s services generally remained strong. Fuel adjustment billings increased to $6.6 million in the first six months of 2008 compared to $3.4 million in the first six months of 2007 for comparative additional 2008 revenue of $3.2 million. However, actual fuel expense incurred increased by $4.1 million during the first six months of 2008 to $9.4 million. The inability to fully pass along fuel increases during 2008 reduced operating earnings for the comparative periods.

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):

	Six Months Ended								Three Months Ended
	June 30,					Increase			June 30,				Increase
	2008		2007			(Decrease)			2008		2007		(Decrease)
Revenues	$	9,137	$	6,979			30.9	%	$	5,190	$	3,556		45.9	%

Operating earnings (loss)
- From production	$	2,049	$	(70	)		n/c		$	1,093	$	450		142.8	%
- From property sales		-		12,078			n/c			-	$	12,078		n/c

Depreciation and depletion	$	2,887	$	1,938			48.9	%	$	1,322	$	883		49.7	%

Production volumes and price information is as follows (in thousands):

	Six Months Ended				Three Months Ended
	June 30,				June 30,
	2008		2007		2008		2007
Crude Oil
Volume – barrels		25,710		35,450		13,743		18,250
Average price per barrel	$	112.54	$	60.78	$	122.91	$	64.62

Natural gas
Volume – mcf		588,700		642,000		301,500		307,000
Average price per mcf	$	10.61	$	7.52	$	11.61	$	7.76

Increased current year oil and gas segment revenues resulted from increased commodity prices for both crude oil and natural gas. Improved revenues led to improved operating earnings from production and more than offset the effect of increased exploration costs and increased depreciation and depletion expense during 2008. Property sales as shown above for 2007 did not recur in 2008 to date. The current year increase in depreciation and depletion is primarily attributable to newly established production on a single field where the current rate of production as well as capitalized finding costs were elevated relative to estimated proved reserves established for the property. Current year production and sales volumes are reduced due to normal production declines on older properties.

Comparative exploration costs were as follows (in thousands):

	Six Months Ended				Three Months Ended
	June 30,				June 30,
	2008		2007		2008		2007
Dry hole expense	$	669	$	1,376	$	579	$	325
Prospect impairments		872		409		675		182
Seismic and geological		522		1,165		349		592

Total	$	2,063	$	2,950	$	1,603	$	1,099

During the first six months of 2008, the Company participated in the drilling of seven successful wells, three dry holes and has an interest in six wells that were in process on June 30, 2008. Evaluation on the in-process wells is anticipated during the third quarter of 2008. Participation in the drilling of approximately 29 wells is planned for the remainder of 2008 on the Company’s prospect acreage in Arkansas, Louisiana, Texas and Wyoming.

In February 2007, the Company, together with its joint interest partners, was awarded a promote license in the United Kingdom North Sea Blocks 21-1b, 21-2b and 21-3d. The Company holds a 30 percent equity interest in these blocks located in the Central Sector of the North Sea. The Company has two years to confirm an exploration prospect and identify a partner to finance, on a promoted basis, the drilling of the first well on the Block. The terms of the license do not include a well commitment. The Company also acquired an approximate nine percent equity interest in a promote licensing right to Block 42-27b, located in the Southern Sector of the U.K. North Sea.

- Outlook

Presently, crude oil and natural gas commodity prices have been trending down for the second half of 2008. Such a continued event would have an adverse effect on inventory carrying values and oil and gas segment operating earnings. Within the marketing and transportation groups, however, reduced diesel fuel costs would act to mitigate some of the impact of this price trend. The diversified nature of the Company’s lines of business provides a degree of stability during uncertain periods.

Liquidity and Capital Resources

During the first six months of 2008, net cash provided by operating activities totaled $8,006,000 versus $2,320,000 utilized by operating activities during the first six months of 2007. Management generally balances the cash flow requirements of the Company’s investment activity with available cash generated from operations. Over time, cash utilized for property and equipment additions, tracks with earnings from continuing operations plus the non-cash provision for depreciation, depletion and amortization. Presently, management intends to restrict investment decisions to available cash flow. Significant, if any, additions to debt are not anticipated. A summary of this relationship follows (in thousands):

	Six Months Ended
	June 30,
	2008			2007
Net earnings	$	7,036		$	12,198
Less net gain on sale		(15	)		(12,034	)
Add dry hole expense		669			1,376
Depreciation, depletion and amortization		6,072			4,766
Property and equipment expenditures		(9,595	)		(8,506	)

Cash provided for (by) other uses	$	4,167		$	(2,200	)

Capital expenditures during the first six months of 2008 included $5,103,000 for marketing and transportation equipment additions and $4,492,000 in property additions associated with oil and gas exploration and production activities. Included in marketing equipment addition was approximately $3.9 million expended to acquire forty-four used truck-tractor trailer combinations for use in the Company’s crude oil marketing business in Michigan, West Texas and New Mexico. For the remainder of 2008, the Company anticipates expending approximately $5 million on oil and gas exploration projects to be funded from operating cash flow and available working capital. In addition, approximately $1.5 million will be expended toward additional equipment purchases within the Company’s marketing and transportation businesses with funding from available cash flow.

- 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 up to $5 million 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 June 30, 2008 was established at $5 million. The oil and gas production loan provides for flexible borrowings subject to a borrowing base established semi-annually by the bank. The borrowing base was established at $5 million as of June 30, 2008. The line of credit loans are scheduled to expire on October 31, 2009, with the then present balance outstanding converting to a term loan payable in eight equal quarterly installments. As of June 30, 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 3.0 to 1.0 ratio of pre-tax net income to interest expense, and consolidated net worth in excess of $64,854,000. 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 believes it is in compliance with these restrictions.

The Company’s Gulfmark subsidiary maintains a separate banking relationship with BNP Paribas in order to support its crude oil purchasing activities. In addition to providing up to $80 million in letters of credit, the facility also finances up to $6 million of crude oil inventory and certain accounts receivable associated with crude oil sales. Such financing is provided on a demand note basis with interest at the bank’s prime rate plus one percent. As of June 30, 2008, the Company had $6 million of eligible borrowing capacity under this facility and no working capital advances were outstanding. Letters of credit outstanding under this facility totaled approximately $48.7 million as of June 30, 2008. The letter of credit and demand note facilities are secured by substantially all of Gulfmark’s and ARM’s assets. Under this facility, BNP Paribas has the right to discontinue the issuance of letters of credit without prior notification to the Company.

The Company’s ARM subsidiary also maintains a separate banking relationship with BNP Paribas in order to support its natural gas purchasing activities. In addition to providing up to $30 million in letters of credit, the facility finances up to $4 million of general working capital needs. Such financing is provided on a demand note basis with interest at the bank’s prime rate plus one percent. No working capital advances were outstanding under this facility as of June 30, 2008. Letters of credit outstanding under this facility totaled approximately $14.8 million as of June 30, 2008. The letter of credit and demand note facilities are secured by substantially all of Gulfmark’s and ARM’s assets. Under this facility, BNP Paribas has the right to discontinue the issuance of letters of credit without prior notification to the Company.

Critical Accounting Policies and Use of Estimates

Fair Value Accounting

As an integral part of its marketing operation, the Company enters into certain forward commodity contracts that are required to be recorded at fair value in accordance with Statement of Financial Accounting Standards No. 133, “Accounting for Derivative Instruments and Hedging Activities” and related accounting pronouncements. Management believes this required accounting, known as mark-to-market accounting, creates variations in reported earnings and the reported earnings trend. Under mark-to-market accounting, significant levels of earnings are recognized in the period of contract initiation rather than the period when the service is provided and title passes from supplier to customer. As it affects the Company’s operation, management believes mark-to-market accounting impacts reported earnings and the presentation of financial condition in three important ways.

Gross margins, derived from certain aspects of the Company’s ongoing business, are front-ended into the period in which contracts are executed. Meanwhile, personnel and other costs associated with servicing accounts as well as substantially all risks associated with the execution of contracts are expensed as incurred during the period of physical product flow and title passage.

Mark-to-market earnings are calculated based on stated contract volumes. A significant risk associated with the Company’s business is the conversion of stated contract or planned volumes into actual physical commodity movement volumes without a loss of margin. Again the planned profit from such commodity contracts is bunched and front-ended into one period while the risk of loss associated with the difference between actual versus planned production or usage volumes falls in a subsequent period.

3.	Cash flows, by their nature, match physical movements and passage of title. Mark-to-market accounting, on the other hand, creates a divergence between reported earnings and cash flows. Management believes this complicates and confuses the picture of stated financial conditions and liquidity.

The Company attempts to mitigate the identified risks by only entering into contracts where current market quotes in actively traded, liquid markets are available to determine the fair value of contracts. In addition, substantially all of the Company’s forward contracts are less than 18 months in duration. However, the reader is cautioned to develop a full understanding of how fair value or mark-to-market accounting creates reported results that differ from those presented under conventional accrual accounting.

- Trade Accounts

Accounts receivable and accounts payable typically represent the single most significant assets and liabilities of the Company. Particularly within the Company’s energy marketing and oil and gas exploration and production operations, there is a high degree of interdependence with and reliance upon third parties (including transaction counterparties) to provide adequate information for the proper recording of amounts receivable or payable. Substantially all such third parties are larger firms providing the Company with the source documents for recording trade activity. It is commonplace for these entities to retroactively adjust or correct such documents. This typically requires the Company to absorb, benefit from, or pass along such corrections to another third party.

Due to the volume and the complexity of transactions and the high degree of interdependence with third parties, this is a difficult area to control and manage. The Company manages this process by participating in a monthly settlement process with each of its counterparties. Ongoing account balances are monitored monthly and the Company attempts to gain the cooperation of such counterparties to reconcile outstanding balances. The Company also places great emphasis on collecting cash balances due and paying only bonafide properly supported claims. In addition, the Company maintains and monitors its bad debt allowance. Nevertheless a degree of risk always remains due to the customs and practices of the industry.

- Oil and Gas Reserve Estimate

The value of capitalized costs of oil and gas exploration and production related assets are dependent on underlying oil and gas reserve estimates. Reserve estimates are based on many subjective factors. The accuracy of reserve estimates depends on the quantity and quality of geological data, production performance data and reservoir engineering data, changing prices, as well as the skill and judgment of petroleum engineers in interpreting such data. The process of estimating reserves requires frequent revision of estimates (usually on an annual basis) as additional information becomes available. Calculation of estimated future oil and gas revenues are also based on estimates as to the timing of oil and gas production, and there is no assurance that the actual timing of production will conform to or approximate such estimates. Also, certain assumptions must be made with respect to pricing. The Company’s estimates assume prices will remain constant from the date of the engineer’s estimates, except for changes reflected under natural gas sales contracts. There can be no assurance that actual future prices will not vary as industry conditions, governmental regulation, political conditions, economic conditions, weather conditions, market uncertainty and other factors impact the market price for oil and gas.

The Company follows the successful efforts method of accounting, so only costs (including development dry hole costs) associated with producing oil and gas wells are capitalized. Estimated oil and gas reserve quantities are the basis for the rate of amortization under the Company’s units of production method for depreciating, depleting and amortizing of oil and gas properties. Estimated oil and gas reserve values also provide the standard for the Company’s periodic review of oil and gas properties for impairment.

- Contingencies

In March 2004, a suit styled Le Petit Chateau De Luxe, et. al. vs Great Southern Oil & Gas Co., et. al. was filed in the Civil District Court for Orleans Parish, Louisiana against the Company and its subsidiary, Adams Resources Exploration Corporation, among other defendants. The suit alleges that certain property in Acadia Parish, Louisiana was environmentally contaminated by oil and gas exploration and production activities during the 1970s and 1980s. An alleged amount of damage has not been specified. Management believes the Company has consistently conducted its oil and gas exploration and production activities in accordance with all environmental rules and regulations in effect at the time of operation. Management notified its insurance carrier about this claim, and thus far the insurance carrier has declined to offer coverage. The Company intends to litigate this matter with its insurance carrier if this matter is not resolved to the Company’s satisfaction. In any event, management does not believe the outcome of this matter will have a material adverse effect on the Company’s financial position or results of operations.

From time to time, as incident to its operations, the Company becomes involved in various accidents, 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. In addition, the Company has extensive operations that must comply with a wide variety of tax laws, environmental laws and labor laws, among others. Should an incident occur, management would evaluate the claim based on its nature, the facts and circumstances and the applicability of insurance coverage. To the extent management believes that such event may impact the financial condition of the Company, management will estimate the monetary value of the claim and make appropriate accruals or disclosure as provided in the guidelines of Statement of Financial Accounting Standards No. 5, “Accounting for Contingencies”.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

The Company is exposed to market risk, including adverse changes in interest rates and commodity prices.

Interest Rate Risk

The Company’s long-term debt facility constitutes floating rate debt. As a result, the Company’s annual interest costs fluctuate based on interest rate changes. Because the interest rate on the Company’s long-term debt is a floating rate, the fair value approximates carrying value. The Company had no long-term debt as of June 30, 2008. A hypothetical 10 percent adverse change in the floating rate would not have had a material effect on the Company’s results of operations for the three-month period ended June 30, 2008.

Commodity Price Risk

The Company’s major market risk exposure is in the pricing applicable to its marketing and production of crude oil and natural gas. Realized pricing is primarily driven by the prevailing spot prices applicable to oil and gas. Commodity price risk in the Company’s marketing operations represents the potential loss that may result from a change in the market value of an asset or a commitment. From time to time, the Company enters into forward contracts to minimize or hedge the impact of market fluctuations on its purchases of crude oil and natural gas. The Company may also enter into price support contracts with certain customers to secure a floor price on the purchase of certain supply. In each instance, the Company locks in a separate matching price support contract with a third party in order to minimize the risk of these financial instruments. Substantially all forward contracts fall within a six-month to one-year term with no contracts extending longer than three years in duration. The Company monitors all commitments, positions and endeavors to maintain a balanced portfolio.

Certain forward contracts are recorded at fair value, depending on management’s assessments of numerous accounting standards and positions that comply with generally accepted accounting principles. The fair value of such contracts is reflected on the balance sheet as fair value assets and liabilities. The revaluation of fair value contracts is recognized on a net basis in the Company’s results of operations. See discussion under “Fair Value Contracts” in Note 1 to the Unaudited Condensed Consolidated Financial Statements.

Historically, prices received for oil and gas sales have been volatile and unpredictable with price volatility expected to continue. From January 1, 2008 through June 30, 2008 average natural gas marketing segment sales price realizations ranged from a monthly low of $7.61 per mmbtu to a monthly high of $11.84 per mmbtu. Average crude oil prices ranged from a monthly low of $93.29 per barrel to a monthly high of $135.00 per barrel during the same period. A hypothetical 10 percent adverse change in average natural gas and crude oil prices, assuming no changes in volume levels, would have reduced earnings before income taxes by approximately $3,120,000 for the six-month period ended June 30, 2008.

Forward-Looking Statements—Safe Harbor Provisions

This report for the period ended June 30, 2008 contains certain forward-looking statements intended to be covered by the safe harbors provided under Federal securities law and regulation. To the extent such statements are not recitations of historical fact, forward-looking statements involve risks and uncertainties. In particular, statements under the captions (a) Management’s Discussion and Analysis of Financial Condition and Results of Operations, (b) Liquidity and Capital Resources, (c) Critical Accounting Policies and Use of Estimates, (d) Quantitative and Qualitative Disclosures about Market Risk, (e) Income Taxes, (f) Fair Value Contracts and (g) Commitments and Contingencies among others, contain forward-looking statements. Where the Company expresses an expectation or belief of future results or 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.

A number of factors could cause actual results or events to differ materially from those anticipated. Such factors include, among others, (a) general economic conditions, (b) fluctuations in hydrocarbon prices and margins, (c) variations between crude oil and natural gas contract volumes and actual delivery volumes, (d) unanticipated environmental liabilities or regulatory changes, (e) counterparty credit default, (f) inability to obtain bank and/or trade credit support, (g) availability and cost of insurance, (h) changes in tax laws, (i) the availability of capital, (j) changes in regulations, (k) results of current items of litigation, (l) uninsured items of litigation or losses, (m) uncertainty in reserve estimates and cash flows, (n) ability to replace oil and gas reserves, (o) security issues related to drivers and terminal facilities, (p) commodity price volatility, (q) demand for chemical based trucking operations and (r) successful completion of drilling activity. For more information, see the discussion under Forward-Looking Statements in the annual report on Form 10-K for the year ended December 31, 2007.

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.

During the three month period ended June 30, 2008, there have not been any changes in the Company’s internal controls over financial reporting (as defined in Rules 13a-13(f) and 15d-15(f) of the Exchange Act) 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.

In March 2004, a suit styled Le Petit Chateau De Luxe, et. al. vs Great Southern Oil & Gas Co., et. al. was filed in the Civil District Court for Orleans Parish, Louisiana against the Company and its subsidiary, Adams Resources Exploration Corporation, among other defendants. The suit alleges that certain property in Acadia Parish, Louisiana was environmentally contaminated by oil and gas exploration and production activities during the 1970s and 1980s. An alleged amount of damage has not been specified. Management believes the Company has consistently conducted its oil and gas exploration and production activities in accordance with all environmental rules and regulations in effect at the time of operation. Management notified its insurance carrier about this claim, and thus far the insurance carrier has declined to offer coverage. The Company intends to litigate this matter with its insurance carrier if this matter is not resolved to the Company’s satisfaction. In any event, management does not believe the outcome of this matter will have a material adverse effect on the Company’s financial position or results of operations.

Item 1A. - There have been no material changes in the Company’s risk factors from those disclosed in the 2007 Form 10-K.

Item 2. - None

Item 3. - None

Item 4. - Submission of Matters to a Vote of Security Holders.

On May 28, 2008, the Company held its annual meeting of shareholders, at which five directors were elected. The vote totals were as follows:

Director	Votes For		Votes Withheld		Non-Voted
K. S. Adams, Jr.		3,947,786		72,502		197,379
F. T. Webster		3,934,736		85,552		197,379
E. C. Reinauer, Jr.		3,957,336		62,952		197,379
E. J. Webster, Jr.		3,969,216		51,072		197,379
Larry E. Bell		3,980,386		39,902		197,379

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 Act 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: August 13, 2008	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