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 September 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~~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 o 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 November ~~1, 2008.~~10, 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)

	Nine Months Ended						Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						September 30,						September 30,
	2008			2007			2008			2007			2009			2008			2009			2008
REVENUES:
Marketing	$	3,466,429		$	1,697,574		$	1,264,609		$	680,085		$	1,391,453		$	3,466,429		$	562,834		$	1,264,609
Transportation		53,974			48,854			18,591			17,208			33,701			53,974			11,471			18,591
Oil and gas		14,259			9,981			5,122			3,002			6,356			14,259			1,994			5,122
		3,534,662			1,756,409			1,288,322			700,295			1,431,510			3,534,662			576,299			1,288,322
COSTS AND EXPENSES:
Marketing		3,463,202			1,683,122			1,274,033			674,661			1,373,305			3,463,202			558,314			1,274,033
Transportation		47,369			40,893			16,025			14,645			29,171			47,369			9,216			16,025
Oil and gas operations		7,386			7,708			3,185			2,597			6,297			7,386			2,834			3,185
Oil and gas property sale		-			(12,078	)		-			-
General and administrative		7,458			7,491			2,038			2,307			6,946			7,458			2,252			2,038
Depreciation, depletion and amortization		9,157			7,038			3,085			2,272			7,517			9,157			2,537			3,085
		3,534,572			1,734,174			1,298,366			696,482			1,423,236			3,534,572			575,153			1,298,366

Operating earnings (loss)		90			22,235			(10,044	)		3,813
Operating earnings														8,274			90			1,146			(10,044	)

Other income (expense):
Interest income		879			1,266			308			443			138			879			82			308
Interest expense		(136	)		(75	)		(91	)		(12	)		(23	)		(136	)		(15	)		(91	)
Earnings (loss) before income taxes		833			23,426			(9,827	)		4,244
Earnings before income tax														8,389			833			1,213			(9,827	)

Income tax provision (benefit)		73			8,373			(3,551	)		1,389			3,146			73			574			(3,551	)

Net earnings (loss)	$	760		$	15,053		$	(6,276	)	$	2,855
Net earnings													$	5,243		$	760		$	639		$	(6,276	)

EARNINGS PER SHARE:
Basic and diluted net earnings (loss)
per common share	$	.18		$	3.57		$	(1.49	)	$	.68
Basic and diluted net earnings (loss) per common share													$	1.24		$	.18		$	.15		$	(1.49	)


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)

	September 30,			December 31,			September 30,			December 31,
	2008			2007			2009			2008
ASSETS

Current assets:
Cash and cash equivalents	$	39,045		$	23,697		$	36,728		$	18,208
Accounts receivable, net of allowance for doubtful
accounts of $1,050 and $192, respectively		234,906			261,710
accounts of $1,263 and $1,251, respectively								137,924			119,401
Inventories		16,398			14,776			13,655			14,207
Fair value contracts		4,287			5,388			3,090			8,697
Income tax receivables		3,853			2,554
Prepayments		4,006			3,768
Income tax receivable								-			3,629
Prepayments and other								9,679			5,224

Total current assets		302,495			311,893			201,076			169,366

Property and equipment		120,138			110,526			122,554			118,863
Less – accumulated depreciation,
depletion and amortization		(79,260	)		(70,828	)
Depletion and amortization								(88,563	)		(83,277	)
		40,878			39,698			33,991			35,586
Other assets:
Fair value contracts		353			1,563			483			-
Deferred income tax asset								1,761			2,035
Cash deposits and other		3,730			3,921			3,070			3,939
	$	347,456		$	357,075		$	240,381		$	210,926

LIABILITIES AND SHAREHOLDERS’ EQUITY

Current liabilities:
Accounts payable	$	243,498		$	252,310		$	143,734		$	115,183
Accounts payable – related party		127			84			83			89
Fair value contracts		2,580			4,116			2,766			8,196
Accrued and other liabilities		6,194			3,707			4,279			3,930
Current deferred income taxes		1,097			1,104			686			409
Total current liabilities		253,496			261,321			151,548			127,807

Other liabilities:
Fair value contracts								457			-
Asset retirement obligations		1,230			1,153			1,289			1,260
Deferred income taxes and other		2,262			4,063
Fair value contracts		266			1,096
Other long-term liabilities								83			98
		257,254			267,633			153,377			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			422			422
Contributed capital		11,693			11,693			11,693			11,693
Retained earnings		78,087			77,327			74,889			69,646
Total shareholders’ equity		90,202			89,442			87,004			81,761
	$	347,456		$	357,075		$	240,381		$	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)

	Nine Months Ended						Nine Months Ended
	September 30,						September 30,
	2008			2007			2009			2008
CASH PROVIDED BY OPERATIONS:
Net earnings	$	760		$	15,053		$	5,243		$	760
Adjustments to reconcile net earnings to net cash
provided by operating activities -
Depreciation, depletion and amortization		9,157			7,038			7,517			9,157
Loss (gain) on property disposals		383			(12,034	)
Loss (gain) on property sales								(93	)		383
Dry hole costs incurred		1,860			2,847			365			1,860
Impairment of oil and gas properties		1,293			633
Impairment on oil and gas properties								2,761			1,293
Provision for doubtful accounts		858			111			12			858
Deferred income taxes								551			(1,793	)
Net change in fair value contracts								151			(55	)
Other, net		(37	)		301			296			(37	)
Decrease (increase) in accounts receivable		25,946			(11,760	)		(18,535	)		25,946
Decrease (increase) in inventories		(1,622	)		(5,581	)		552			(1,622	)
Net change in fair value contracts		(55	)		(6	)
Decrease (increase) in tax receivable		(1,299	)		904
Decrease (increase) in income tax receivable								3,629			(1,299	)
Decrease (increase) in prepayments		(238	)		(2,382	)		(4,455	)		(238	)
Increase (decrease) in accounts payable		(8,901	)		13,757			28,636			(8,901	)
Increase (decrease) in accrued liabilities		2,487			(4,644	)		349			2,487
Deferred income taxes		(1,793	)		380

Net cash provided by operating activities		28,799			4,617			26,979			28,799

INVESTING ACTIVITIES:
Property and equipment additions		(13,780	)		(12,104	)		(9,505	)		(13,780	)
Insurance and tax refunds (deposits)		290			(424	)
Insurance and excise tax refunds								587			290
Proceeds from property sales		39			15,319			459			39
Redemption of short-term investments		10,000			15,000			-			10,000
Investment in short-term investments		(10,000	)		(15,000	)		-			(10,000	)

Net cash (used in) investing activities		(13,451	)		2,791			(8,459	)		(13,451	)

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

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

Increase in cash and cash equivalents		15,348			4,408			18,520			15,348

Cash at beginning of period		23,697			20,668			18,208			23,697

Cash at end of period	$	39,045		$	25,076

Supplemental disclosure of cash flow information:

Interest paid during the period	$	136		$	79

Income taxes paid during the period	$	2,319		$	7,449

Increase (decrease) in liabilities associated with
property additions	$	(132	)	$	(704	)
C Cash at end of period							$	36,728		$	39,045

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 September 30, ~~2008,~~2009, its results of operations for the three and nine-month periods ended September 30, 2009 and 2008 and its cash flows for the nine months ended September 30, ~~2008~~2009 and ~~2007.~~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. The impact on the accompanying financial statements of events occurring after September 30, 2009 has been evaluated through November 13, 2009.

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 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 Cashflows under “Provision for Doubtful Accounts”.

~~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. 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.

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market ~~fund~~funds or federal funds with maturity of 90 days or less. Depending on cash availability ~~auction rate~~and market conditions, investments in municipal bonds ~~and bond mutual funds~~ may also be made from time to ~~time depending on market conditions.~~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. The Company had no ~~auction rate~~ investments ~~as of~~in municipal bonds at September 30, ~~2008 and~~2009 or December 31, ~~2007.~~2008.

~~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 twentieth and twenty-fifth 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 average cost or ~~market.~~market price. 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):

	September 30,		December 31,
	2008		2007		September 30,		December 31,
					2009		2008
Crude oil	$	13,706	$	12,437	$	12,042	$	11,710
Petroleum products		2,692		2,339		1,613		2,497

	$	16,398	$	14,776	$	13,655	$	14,207

Prepayments

The components of prepayments and other are as follows (in thousands):

	September 30,		December 31,
	2009		2008

Cash collateral deposits for commodity purchases	$	5,504	$	2,082
Insurance premiums		2,670		1,985
Natural gas pipeline imbalances		751		369
Rents, license and other		754		788

	$	9,679	$	5,224

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 September 30, ~~2008,~~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 ~~recoverable~~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 its 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. Producing oil and gas properties are reviewed quarterly for impairment triggers on a field-by-field basis. For properties requiring impairment, the fair value is estimated based on an internal discounted cash-flow model. Cash flows are developed based on estimated future production and prices and then discounted using an internal rate of return consistent with that used by the Company in evaluating cash flows for other assets of a similar nature. For the nine-month periods ended September 30, ~~2008~~2009 and ~~2007,~~2008 there were $517,000 and zero impairment provisions ~~totaling zero and $11,000, respectively,~~ on producing oil and gas ~~properties. In addition,~~properties, respectively. Such provisions also totaled $295,000 and zero for the three-month periods ended September 30, 2009 and 2008, respectively.

Fair value measurements for producing oil and gas properties for the nine-month period ended September 30, 2009 summarized as follows (in thousands):

	Producing Properties Evaluated for Fair Value Impairment

Net book value at December 31, 2008	$	518

Property additions		43
Depletion taken		(44	)
Impairment valuation loss		(517	)

Fair value at September 30, 2009	$	-

All fair value measurements for producing oil and gas properties are based on Level 3 – Significant Unobservable Inputs (see Fair Value Measurements below).

On a quarterly basis, management also evaluates the carrying value of non-producing ~~properties~~oil and ~~unevaluated~~gas properties and may deem them impaired for lack of drilling activity. Accordingly, impairment provisions on non-producing properties totaling ~~$1,293,000~~$2,244,000 and ~~$622,000~~$1,293,000 were recorded for the nine-month periods ended September 30, 2009 and 2008, respectively. Such provisions totaled $1,570,000 and ~~2007, respectively. Impairment provisions on non-producing properties totaled~~ $421,000 ~~and $225,000~~ for the three-month periods ended September 30, ~~2008~~2009 and ~~2007, respectively.~~

~~Other Assets~~2008. For non-producing properties, impairments are 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.

~~Other~~Cash deposits and 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 $2,751,000 and $3,040,000 as of September 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~~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 ~~totaled $131,000~~ and ~~$333,000~~other assets are as ~~of September 30, 2008 and December 31, 2007, respectively.~~follows (in thousands):

	September 30,		December 31,
	2009		2008
Insurance collateral deposits	$	2,189	$	2,794
State collateral deposits		297		279
Accounts and notes receivable		273		503
Materials and supplies		311		363
	$	3,070	$	3,939

Revenue Recognition

Commodity ~~purchases~~purchase 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~~instruments. Further, 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.”~~activities. From the time of contract origination, such trading activity 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.”statements.

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.~~methodology for such activity. For normal purchase and sale activities, the Company’s customers are invoiced monthly based upon contractually agreed upon terms ~~and~~with 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~~because the ~~guidance provided by EITF 99-19, “Reporting Revenue Gross as~~Company takes title to and has risk of loss for the products, is the primary obligor for the purchase, establishes the sale price independently with a ~~Principal versus Net as an Agent.”~~third party, and maintains credit risk associated with the sale of the product.

Certain crude oil contracts may be with a single counterparty to provide for similar quantities of crude oil to be bought and sold at ~~two~~ different locations. These contracts are entered into for a variety of reasons, including effecting the transportation of the commodity, to minimize credit exposure, ~~and~~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~~Such 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.

Banking Relationships

In August 2009, the Company entered into a Credit and Security Agreement with Wells Fargo Bank to provide a $40 million letter of credit facility. Pursuant to the Wells Fargo agreement, the Company discontinued its previous working capital lines of credit with Bank of America. The Wells Fargo facility provides for the issuance of up to $40 million of letters of credit to support the Company’s crude oil and natural gas marketing businesses based on the eligible accounts receivable within those operations. Letters of credit outstanding totaled $19.9 million as of September 30, 2009. The letter of credit facility places certain restrictions on the Company’s Gulfmark Energy, Inc. and Adams Resources Marketing, Ltd. subsidiaries. Such restrictions included the maintenance of a combined 1.1 to 1.0 current ratio and the maintenance of positive net earnings as defined among other restrictions. Management believes the Company is currently in compliance with all such covenants.

Statement of Cash Flows

Interest paid totaled $23,000 and $136,000 during the nine-month periods ended September 30, 2009 and 2008, respectively. Income taxes paid during these same periods totaled $549,000 and $2,319,000, respectively. The Company also received a $2,000,000 income tax refund during the first nine months of 2009. Non-cash investing activities for property and equipment in accounts payable were $439,000 and $267,000 as of September 30, 2009 and 2008, respectively and $561,000 as of December 31, 2008. 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 ~~the three-month~~2009 and ~~nine-month periods ended September 30, 2008 and 2007.~~2008. There were no potentially dilutive securities during those ~~periods in 2008 and 2007.~~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 ~~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.

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 users 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 and therefore, the Company accounts for such contracts at fair value, unless the normal purchase and sale exception is elected. 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”.

None of the Company’s derivative instruments have been designated as hedging instruments and the estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of September 30, 2009 as follows (in thousands):

	Balance Sheet Location and Amount
	Current			Other		Current			Other
	Assets			Assets		Liabilities			Liabilities
Asset Derivatives
- Fair Value Commodity
Contracts at Gross Valuation	$	3,303		$	483	$	-		$	-

Liability Derivatives
- Fair Value Commodity
Contracts at Gross Valuation		-			-		2,979			457

Less Counterparty Offsets		(213	)		-		(213	)		-

As Reported Fair Value Contracts	$	3,090		$	483	$	2,766		$	457

The Company only enters into commodity contracts with credit worthy counterparties or obtains collateral support for such activities. No credit loss provision applies to the Company’s forward commodity contract valuations. As of September 30, 2009, the Company is not holding nor has it posted any collateral to support its forward month fair value derivative activity. The Company is not subject to any credit-risk related trigger events.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the nine months ended September 30, 2009 as follows (in thousands):

	Statement of Operations
	Location	(Loss)

- Fair value commodity contracts	Revenues – marketing	$	(151	)

The fair value commodity contracts loss represents a non-cash reduction of earnings and is reflected as such under the caption “Net change in fair value contracts” in the accompanying Unaudited Statement of Cash Flows.

Commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the three months ended September 30, 2009 as follows (in thousands):

	Statement of Operations
	Location	(Loss)

- Fair value commodity contracts	Revenues - marketing	$	-0-

Fair Value Measurements

The carrying amount reported in the ~~balance sheet~~Unaudited Condensed Consolidated 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~~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~~estimates are based on assumptions that market participants would use when pricing an asset or liability and ~~establishes~~the Company uses 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 such adoption did not have a material impact on asset or liability values.~~ As of September 30, ~~2008,~~2009, 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 $ 893 $ 3,394 $ - $ 4,287
- Long-term assets 47 306 - 353
- Current liabilities (538 ) (2,042 ) - (2,580 )
- Long-term liabilities - (266 ) - (266 )
Net Value $ 402 $ 1,392 $ - $ 1,794

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.

	Market Data Inputs
	Level 1		Level 2			Level 3
	Quoted Prices		Observable			Unobservable		Total
Derivatives
- Current assets	$	554	$	2,536		$	-	$	3,090
- Long-term assets		14		469			-		483
- Current liabilities		-		(2,766	)		-		(2,766	)
- Long-term liabilities		-		(457	)		-		(457	)
Net Value	$	568	$	(218	)	$	-	$	350

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 ~~utilizes~~utilize Level 3 inputs, such as credit scores to evaluate the likelihood of default by the Company or its counterparties. As of September 30, ~~2008,~~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 ~~Levels 1 or~~Level 2 of the fair value hierarchy.

~~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,~~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.

As of September 30, 2009, 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. 159Accounting Standards Codification (ASC) which became effective ~~beginning January 1, 2008. Management did not elect~~for the ~~fair value option~~Company. The ASC is now the source of authoritative U.S. accounting and reporting standards for ~~any eligible financial assets~~nongovernmental entities, in addition to guidance issued by the SEC. No changes to accounting standards or ~~liabilities not already carried at fair value.~~

~~In March 2008,~~guidance resulted from the ~~FASB issued SFAS No. 161, “Disclosures about Derivative Instruments~~issuance of the ASC. Any references to accounting guidance in current 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 forfuture financial statements ~~issued for fiscal years and interim periods beginning after November 15, 2008. Early adoption is permitted. The Company is currently evaluating~~will be to the ~~impact the adoption of SFAS No. 161 will have on its financial statements.~~applicable ASC sections.

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. All accounting policies of each segment are consistent with the Company’s accounting policies. Information concerning the Company’s various business activities is summarized as follows (in thousands):

~~- Nine Month Comparison~~

Segment Depreciation Property and
Operating Depletion and Equipment
Revenues Earnings (loss) Amortization Additions
Period Ended September 30, 2008
Marketing
- Crude Oil $ 3,282,421 $ 224 $ 1,479 $ 4,660
- Natural gas 8,511 1,833 122 12
- Refined products 175,497 (862 ) 431 114
Marketing Total 3,466,429 1,195 2,032 4,786
Transportation 53,974 3,746 2,859 508
Oil and gas 14,259 2,607 4,266 8,486
$ 3,534,662 $ 7,548 $ 9,157 $ 13,780
Period Ended September 30, 2007
Marketing
- Crude Oil $ 1,565,456 $ 9,759 $ 473 $ 608
- Natural gas 9,051 3,020 120 105
- Refined products 123,067 755 325 411
Marketing Total 1,697,574 13,534 918 1,124
Transportation 48,854 4,695 3,266 255
Oil and gas 9,981 11,497 2,854 7,878
$ 1,756,409 $ 29,726 $ 7,038 $ 9,257

910

- Nine Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2009
Marketing
- Crude Oil	$	1,304,092	$	13,425		$	1,527	$	724
- Natural gas		10,310		2,197			124		-
- Refined products		77,051		477			398		177
Marketing Total		1,391,453		16,099			2,049		901
Transportation		33,701		1,678			2,852		2,593
Oil and gas		6,356		(2,557	)		2,616		6,011
	$	1,431,510	$	15,220		$	7,517	$	9,505
Period Ended September 30, 2008
Marketing
- Crude Oil	$	3,282,421	$	224		$	1,479	$	4,660
- Natural gas		8,511		1,833			122		12
- Refined products		175,497		(862	)		431		114
Marketing Total		3,466,429		1,195			2,032		4,786
Transportation		53,974		3,746			2,859		508
Oil and gas		14,259		2,607			4,266		8,486
	$	3,534,662	$	7,548		$	9,157	$	13,780

- Three Month Comparison

			Segment			Depreciation		Property and				Segment			Depreciation		Property and
			Operating			Depletion and		Equipment				Operating			Depletion and		Equipment
										Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2009
Marketing
- Crude Oil										$	530,981	$	3,582		$	496	$	74
- Natural gas											3,112		192			41		-
- Refined products											28,741		78			131		-
Marketing Total											562,834		3,852			668		74
Transportation											11,471		1,244			1,011		800
Oil and gas											1,994		(1,698	)		858		1,351
	Revenues		Earnings (loss)			Amortization		Additions		$	576,299	$	3,398		$	2,537	$	2,225
Period Ended September 30, 2008
Marketing
- Crude Oil	$	1,198,779	$	(11,010	)	$	577	$	33	$	1,198,779	$	(11,010	)	$	577	$	33
- Natural gas		2,507		551			41		12		2,507		551			41		12
- Refined products		63,323		280			137		35		63,323		280			137		35
Marketing Total		1,264,609		(10,179	)		755		80		1,264,609		(10,179	)		755		80
Transportation		18,591		1,615			951		111		18,591		1,615			951		111
Oil and gas		5,122		558			1,379		4,005		5,122		558			1,379		4,005
	$	1,288,322	$	(8,006	)	$	3,085	$	4,196	$	1,288,322	$	(8,006	)	$	3,085	$	4,196
Period Ended September 30, 2007
Marketing
- Crude Oil	$	632,729	$	4,098		$	166	$	181
- Natural gas		2,383		528			50		53
- Refined products		44,973		469			113		143
Marketing Total		680,085		5,095			329		377
Transportation		17,208		1,536			1,027		96
Oil and gas		3,002		(511	)		916		1,654
	$	700,295	$	6,120		$	2,272	$	2,127

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

September 30, December 31,

2008

2007

Marketing
- Crude oil $ 191,739 $ 186,163
- Natural gas 41,165 74,585
- Refined products 19,382 21,844
Marketing Total 252,286 282,592
Transportation 19,155 18,282
Oil and gas 27,430 25,267
Other 48,585 30,934
$ 347,456 $ 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):

	Nine months ended						Three months ended
	September 30,						September 30,
	2009			2008			2009			2008
Segment operating earnings	$	15,220		$	7,548		$	3,398		$	(8,006	)
- General and administrative		(6,946	)		(7,458	)		(2,252	)		(2,038	)
Operating earnings (loss)		8,274			90			1,146			(10,044	)
- Interest income		138			879			82			308
- Interest expense		(23	)		(136	)		(15	)		(91	)
Earnings (loss) before income taxes	$	8,389		$	833		$	1,213		$	(9,827	)

Nine Months ended Three months ended

September 30,

September 30,

2008

2007

2008

2007

Segment operating earnings (loss) $ 7,548 $ 29,726 $ (8,006 ) $ 6,120
- General and administrative (7,458 ) (7,491 ) (2,038 ) (2,307 )
Operating earnings 90 22,235 (10,044 ) 3,813
- Interest income 879 1,266 308 443
- Interest expense (136 ) (75 ) (91 ) (12 )
Earnings (loss) before income taxes $ 833 $ 23,426 $ (9,827 ) $ 4,244
Identifiable assets by industry segment are as follows (in thousands):

	September 30,		December 31,
	2009		2008
Marketing
- Crude oil	$	124,605	$	85,774
- Natural gas		26,340		46,599
- Refined products		10,754		13,037
Marketing Total		161,699		145,410
Transportation		13,566		14,915
Oil and gas		21,123		21,904
Other		43,993		28,697
	$	240,381	$	210,926

10Intersegment sales are insignificant. Other identifiable assets are primarily corporate cash, and assets 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. For the first nine months of ~~2008~~2009 and ~~2007,~~2008, the Company’s investment commitments totaled approximately ~~$5.5~~$5.3 million and ~~$5.9~~$5.5 million, respectively, in those oil and gas projects where a related party was also participating in such investments. As of September 30, ~~2008~~2009 and December 31, ~~2007,~~2008, the Company owed a combined net total of ~~$127,000~~$83,000 and ~~$84,000,~~$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 (“COPAS”) Bulletin 5. Such overhead recoveries totaled ~~$99,000~~$111,000 and ~~$94,000~~$99,000 in the nine-month periods ended September 30, 2009 and 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 nine-month period ended September 30, ~~2008~~2009 and ~~2007,~~2008, the affiliated entities charged the Company ~~$42,000~~$53,546 and ~~$74,000,~~$42,000, respectively, of expense reimbursement and the Company charged the affiliates ~~$73,000~~$98,000 and ~~$56,000,~~$73,000, 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 and its insurance carrier have entered in to a tolling agreement to temporarily set aside the claims pending resolution of the underlying matter. 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, in certain instances ~~under the policies,~~ the risk of insured losses is shared with a group of similarly situated entities. As of September 30, ~~2008,~~2009, management has appropriately recognized estimated expenses and ~~liability~~liabilities related to ~~these policies.~~the program. Estimated loss accruals for potentially unknown losses are developed using actual loss histories and other relevant information.

From time to time as ~~incident~~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 ~~may be~~is a party to motor vehicle accidents, worker compensation claims orand other items of general liability as would be typical for the industry. ~~Except as disclosed herein, management~~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):

	Nine Months Ended					Three Months Ended					Nine Months Ended					Three Months Ended
	September 30,					September 30,					September 30,					September 30,
	2008			2007		2008			2007		2009		2008			2009		2008
Revenues
Crude oil	$	3,282,421		$	1,565,456	$	1,198,779		$	632,729	$	1,304,092	$	3,282,421		$	530,981	$	1,198,779
Natural gas		8,511			9,051		2,507			2,383		10,310		8,511			3,112		2,507
Refined products		175,497			123,067		63,323			44,973		77,051		175,497			28,741		63,323
Total	$	3,466,429		$	1,697,574	$	1,264,609		$	680,085	$	1,391,453	$	3,466,429		$	562,834	$	1,264,609

Operating Earnings (loss)
Crude oil	$	224		$	9,759	$	(11,010	)	$	4,098	$	13,425	$	224		$	3,582	$	(11,010	)
Natural gas		1,833			3,020		551			528		2,197		1,833			192		551
Refined products		(862	)		755		280			469		477		(862	)		78		280
Total	$	1,195		$	13,534	$	(10,179	)	$	5,095	$	16,099	$	1,195		$	3,852	$	(10,179	)

Depreciation
Crude oil	$	1,479		$	473	$	577		$	166	$	1,527	$	1,479		$	496	$	577
Natural gas		122			120		41			50		124		122			41		41
Refined products		431			325		137			113		398		431			131		137
Total	$	2,032		$	918	$	755		$	329	$	2,049	$	2,032		$	668	$	755

1213

Supplemental volume and price information is as follows:

	Nine Months Ended				Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				September 30,				September 30,
	2008		2007		2008		2007		2009		2008		2009		2008
Field Level Purchase Volumes – Per day (1)
Crude oil – barrels		66,900		60,950		70,900		60,750		66,200		66,900		64,100		70,900
Natural gas – mmbtu’s		429,800		418,450		395,900		380,650		383,000		429,000		369,000		395,000

Average Purchase Price
Crude oil – per barrel	$	115.14	$	63.56	$	116.88	$	74.29	$	53.14	$	115.14	$	65.41	$	116.88
Natural Gas – per mmbtu’s	$	9.31	$	6.79	$	9.18	$	6.05	$	3.63	$	9.31	$	3.12	$	9.18

_____________________________

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

Crude oil revenues ~~approximately doubled~~were reduced for the comparative current period because of significantly lower average crude oil prices as shown in the ~~current year due to significantly increased commodity~~table above. While comparative overall 2009 crude oil prices through September 30, 2009 were reduced, the direction of change in prices was generally increasing during ~~major portions~~the period. The average acquisition price of crude oil moved from the $41 per barrel level at the beginning of the ~~year. Crude~~year to $69 per barrel for the September 2009 average purchase price. This event produced an inventory liquidation gain of $4,912,000 for the first nine months of 2009. An opposite event occurred in 2008 as crude oil prices ~~rose~~declined from the $90 per barrel ~~level at year-end 2007 to the $140 per barrel level~~range in ~~June 2008 with a subsequent steep decline during September and October~~January 2008 to the ~~$70~~$77 per barrel ~~range. The effect of fluctuating prices was to cause~~range in September 2008 producing a $3,100,000 inventory liquidation ~~gains during~~loss. For the ~~first half of 2008 as prices rose, with inventory liquidation and valuation losses occurring during the~~comparative third quarter ~~as the market price declined. Net inventory driven losses for the full first nine months of~~period in 2008, crude oil prices were ~~$3.1 million,~~falling dramatically with a $11.6 million inventory valuation loss occurring ~~during the third quarter. Included~~ in the ~~third quarter loss was~~three-month period. This compares to a ~~$4.8 million lower of cost or market write-down as~~$849,000 inventory liquidation gain for the three-month period ended September 30, 2009. As of September 30, ~~2008 when prices dropped $27 per barrel in October 2008. The Company’s inventory holdings result from shipments in transit and as of September 30, 2008,~~2009 the Company held ~~178,774~~172,965 barrels of crude oil inventory ~~valued~~ at ~~$76.67~~an average price of $69.62 per barrel. Should the declining price trend continue, additional inventory driven losses will be incurred. The opposite pricing scenario occurred in 2007 as rising crude oil prices produced inventory liquidation gains of $3.1 million and $1.5 million during the nine and three-month periods ending September 30, 2007, respectively.

Excluding the impact of inventory values as discussed above, crude oil operating earnings for the nine months ended September 30, 2008 and 2007 would have been $3,324,000 and $6,659,000, respectively. For the three month periods ended September 30, 2008 and 2007 crude oil operating earnings excluding the impact of inventory values would have been $590,000 and $2,598,000, respectively. Earnings from operations excluding inventory items were reduced during 2008 relative to 2007 primarily as a result of escalated prices for diesel fuel consumed in the trucking function of this business. Diesel fuel expense for the nine and three-month periods ended September 30, 2008 were $5.8 million and $2.4 million, respectively, compared to $3.7 million and $1.1 million during the nine and three-month periods ended September 30, 2007, respectively. Should crude oil prices settle at lower levels, the Company will experience substantial savings on future diesel fuel costs.

Natural gas sales are reported net of underlying natural gas purchase costs and thus reflect gross ~~margin.~~margins. As shown above, ~~operating~~such margins were ~~reduced through~~consistent between the ~~first nine months~~periods except during the third quarter 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 20082009 when mild weather patterns ~~not stimulating localized demand spikes. Excluding temporary volume reductions caused by third quarter 2008 hurricane activity in~~across the ~~Gulf of Mexico, the Company continues~~nation served to ~~add purchase volumes while still attempting to enhance per unit~~suppress price volatility and hence margins.

~~Refined~~Last year, the refined products ~~revenues increased during 2008 consistent with increased commodity prices partially offset by reduced volumes as~~segment operating loss occurred because the Company has reduced its sales activity with less credit worthy accounts. Refined product driven operating earnings are reduced during 2008 as the Company increased the allowance for doubtful accounts receivable through a bad debt chargerate of ~~$750,000. The Company has a number of construction industry customers experiencing significantly increased fuel costs coupled with a downturn~~increase in the ~~housing development market. Since there is an elevated likelihood~~crude oil driven supply cost of ~~this class~~motor fuel exceeded the rate of ~~customer experiencing financial insolvency,~~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 ~~bad debt provision was increased accordingly. Also, adversely impacting results was a supplier’s failure~~supplier of biodiesel fuel failed to deliver ~~biodiesel fuel as~~ scheduled product resulting in a direct loss to the Company of approximately ~~$400,000 during the first quarter of 2008.~~$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 ~~planned,~~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. Also during the third quarter of 2008, refined product prices were declining which, as typically occurs, improved unit margins in the 2008 period as the rate of reduction in product supply acquisition costs exceeded the rate of reduction in end-market wholesale prices.

Historically, prices received for crude oil and natural gas ~~and refined~~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):

	Nine Months Ended							Three Months Ended							Nine Months Ended							Three Months Ended
	September 30,				Increase			September 30,				Increase			September 30,				Increase			September 30,				Increase
	2008		2007		(Decrease)			2008		2007		(Decrease)			2009		2008		(Decrease)			2009		2008		(Decrease)

Revenues	$	53,974	$	48,854		10.5	%	$	18,591	$	17,208		8.0	%	$	33,701	$	53,974		(37.5	)%	$	11,471	$	18,591		(38.3	)%

Operating earnings	$	3,746	$	4,695		(20.2	)%	$	1,615	$	1,536		5.1	%	$	1,678	$	3,746		(55.2	)%	$	1,244	$	1,615		(22.9	)%

Depreciation	$	2,859	$	3,266		(12.5	)%	$	951	$	1,027		(7.4	)%	$	2,852	$	2,859		(.2	)%	$	1,011	$	951		6.3	%

~~Transportation~~Revenues and operating results turned downward for the transportation segment in 2009 due to reduced customer demand. 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 only limited signs of recovery. Typically, as revenues ~~include various component parts,~~decline, operating earnings decline at a faster rate, as measured by percentage, due to the ~~most significant being standard line haul charges, fuel adjustment charges and demurrage. Line haul~~fixed cost components of operating costs. 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. As a result, the rate of decline in operating earnings slowed relative to the rate of decline in revenues ~~increased slightly~~beginning in the second quarter of 2009. In addition during the ~~first nine months~~third quarter of ~~2008~~2009 the Company earned an approximate $467,000 credit against its automobile and workers compensation insurance premiums. Such premium credits served to ~~$38.1 million versus $37.8 million in~~reduce operating expenses and were a direct result of reduced activity within the 2007 period as demand for the Company’s services generally remained strong. Fuel adjustment billings increased to $10.5 million in the first nine months of 2008 compared to $5.5 million in the first nine months of 2007 for comparative additional 2008 revenue of $5 million. However, actual fuel expense incurred increased by $6.3 million during the first nine months of 2008 to $14.5 million. The inability to fully pass along fuel increases during 2008 reduced operating earnings.

transportation segment.

- 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):

	Nine Months Ended								Three Months Ended								Nine Months Ended								Three Months Ended
	September 30,					Increase			September 30,					Increase			September 30,					Increase			September 30,					Increase
	2008		2007			(Decrease)			2008		2007			(Decrease)			2009			2008		(Decrease)			2009			2008		(Decrease)
Revenues	$	14,259	$	9,981			42.9	%	$	5,122	$	3,002			70.6	%	$	6,356		$	14,259		(55.4	)%	$	1,994		$	5,122		(61.1	)%

Operating earnings (loss)																	$	(2,557	)	$	2,607		(198.1	)%	$	(1,698	)		558		(404.3	)%
- From production	$	2,607	$	(581	)		n/c		$	558	$	(511	)		n/c
- From property sales		-		12,078			n/c			-	$	-			n/c

Depreciation and depletion	$	4,266	$	2,854			49.5	%	$	1,379	$	916			50.5	%	$	2,616		$	4,266		(38.7	)%	$	858		$	1,379		(37.8	)%

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 producing property impairment provisions to be recorded. Such charges reduced the level of capitalized costs for amortizing in the current period.

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

Nine Months Ended Three Months Ended

September 30,

September 30,

2008

2007

2008

2007

Crude Oil
Volume – barrels 37,810 51,190 12,100 15,740
Average price per barrel $ 114.96 $ 65.53 $ 120.12 $ 76.22

Natural gas
Volume – mcf 913,800 890,000 325,100 248,000
Average price per mcf $ 10.85 $ 7.45 $ 11.26 $ 7.26

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 depreciation and depletion expense during 2008. Property sales did not recur in 2008 to date. The current year increase in depreciation and depletion is primarily attributable to newly established production on certain fields where the current rate of production as well as capitalized finding costs were elevated relative to estimated proved reserves established for the property. Crude oil volumes are reduced in 2008 as a result of normal production declines while natural gas volumes have increased with favorable drilling results.

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2009		2008		2009		2008
Crude Oil
Volume – barrels		39,148		37,810		11,521		12,100
Average price per barrel	$	54.00	$	114.96	$	65.14	$	120.12

Natural gas
Volume – mcf		981,918		913,800		316,002		325,100
Average price per mcf	$	4.32	$	10.85	$	3.94	$	11.26

Comparative exploration costs are summarized in the table below. As shown, prospect impairment expense was increased in 2009 as certain adverse drilling results lead to unfavorable capitalized costs valuations. Exploration cost components were as follows (in thousands):

	Nine Months Ended				Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				September 30,				September 30,
	2008		2007		2008		2007		2009		2008		2009		2008
Dry hole expense	$	1,860	$	2,847	$	1,191	$	1,471	$	365	$	1,860	$	60	$	1,191
Prospect impairments		1,293		633		421		225		2,761		1,293		1,865		421
Seismic and geological		653		1,399		131		234		676		653		172		131

Total	$	3,806	$	4,879	$	1,743	$	1,930	$	3,802	$	3,806	$	2,097	$	1,743

During the first nine months of ~~2008,~~2009, the Company participated in the drilling of ~~twelve~~22 successful wells ~~six~~with seven dry ~~holes and~~holes. Additionally, the Company has an interest in ~~eight~~nine wells that were in process on September 30, ~~2008.~~2009. Evaluation on the in-process wells is anticipated during the fourth quarter of ~~2008.~~2009. Participation in the drilling of approximately 25five wells is planned for the remainder of ~~2008~~2009 on the Company’s prospect acreage in ~~Arkansas,~~ Louisiana ~~Texas~~ and ~~Wyoming, depending on rig availability.~~Texas.

~~In February 2007, the~~- Outlook

The Company ~~together with~~recently announced its ~~joint interest partners, was awarded a promote license~~successful participation in four wells in the ~~United Kingdom North Sea Blocks 21-1b, 21-2b~~Haynesville Shale formation of Nacogdoches County, Texas. These productive wells should boost fourth quarter 2009 natural gas volumes and ~~21-3d.~~revenues. The ~~Company holds a 30 percent equity interest~~marketing and transportation segments are also forecast to be stable and profitable during the fourth quarter. Absent declines 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. To date, the Company’s investment group has been unsuccessful in obtaining a partner to fund these two projects.

- ~~Outlook~~

~~Presently,~~ crude oil and natural gas ~~commodity~~ prices, ~~are continuing a downward trend for~~upcoming year-end results should show improvement over the ~~fourth quarter~~current level of ~~2008. Such a continued event has 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 and its avoidance of bank debt provides a degree of stability during uncertain periods.

Liquidity and Capital Resources

The Company’s liquidity primarily derives from net cash ~~generated from operations, which~~provided by operating activities and such amount was $26,979,000 and $28,799,000 ~~and $4,617,000~~ for each of the ~~nine months~~nine-month periods ended September 30, 2009 and 2008, ~~and 2007,~~ respectively. Changes in cash from operations for these periods were primarily driven by changes in working capital. Generally, these working capital changes are timing differences that occur in the ordinary course of business, and are not expected to have a significant impact on overall liquidity. However, during the third quarter of 2008, the Company expanded its requirements for certain customers to prepay for product deliveries. This acted to increase cash balances and reduced corresponding accounts receivable. As of September 30, ~~2008~~2009 and December 31, ~~2007~~2008, the Company had no bank debt or other forms of debenture obligations. Cash and cash equivalents totaled ~~$39,045,000~~$36,728,000 as of September 30, ~~2008,~~2009, and such balances are maintained in order to meet the timing of day-to-day cash needs. From time to time, the Company may also make cash prepayments to certain suppliers of crude oil and natural gas to the Company’s marketing operations. Such prepayments totaled $5,504,000 as of September 30, 2009 and such amounts will be recouped during the current fourth quarter as the suppliers deliver product to the Company. The Company also requires certain counterparties to post cash collateral with the Company in order to support their purchases from the Company. Such cash collateral held by the Company totaled $4,754,000 as of September 30, 2009. Working capital, the excess of current assets over current liabilities, totaled ~~$48,999,000~~$49,528,000 as of September 30, ~~2008.~~2009. Management believes current ~~liquidity,~~cash balances, together with expected cash ~~to be~~ generated from future operations, will be sufficient to meet ~~Company’s expected~~ short-term and long-term liquidity needs.

The Company utilizes cash from operations to make discretionary investments in its oil and natural gas exploration, ~~and~~ marketing and transportation businesses, which comprise substantially all of the Company’s investing cash outflows for each of the ~~past three years.~~periods in this filing. The Company does not look to proceeds from property sales to fund its cash flow needs. However, during May 2007, the Company did receive net proceeds of $14,954,000 related to the sale of oil and gas properties. Such sale was made due to attractive pricing. Currently, the Company does not plan to make significant dispositions of its oil and gas properties in the future, but certain oil and gas interests may be disposed of periodically as business conditions warrant. Except for a total of ~~$6.2~~$2.3 million in operating lease ~~commitments~~payments for transportation equipment ~~(see Footnote 9 of~~and office lease space, the ~~annual report on Form 10-K for the year ended December 31, 2007) the~~ Company’s future commitments and planned investments can be readily curtailed if operating cash flows contract.

Capital expenditures during the first nine months of ~~2008~~2009 included ~~$5,294,000~~$3,494,000 for marketing and transportation equipment additions and ~~$8,486,000~~$6,011,000 in property additions associated with oil and gas exploration and production activities. Included in marketing equipment additions was approximately $4 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,~~2009, the Company anticipates expending ~~approximately $5~~an additional approximate $8 million on oil and gas exploration projects to be funded from operating cash flow and available working capital. In addition, approximately ~~$1 million~~$960,000 will be expended during the final quarter of 2009 toward the purchase of 48 tractors scheduled to come off lease financing and an additional ~~equipment purchases within~~approximate $4.8 million for the ~~Company’s marketing and transportation businesses~~purchase of 44 new tractor replacements with funding for such purchase from available cash flow.

Historically, the Company ~~has paid~~pays an annual dividend in the fourth quarter of each year, and the ~~Board of Directors~~Company has declared a $.50 per common share or ~~$2,108,000~~$2,109,000 dividend ~~to be payable~~ to shareholders of record as of December ~~2, 2008.~~1, 2009. 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 ofin the ~~annual report of~~Annual Report on Form 10-K for the year ended December 31, ~~2007)~~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~~In August 2009, the Company entered into a Credit and Security Agreement with Wells Fargo Bank to provide a $40 million letter of credit facility. Pursuant to the Wells Fargo agreement, ~~with Bank of America provides for two separate~~the Company discontinued its previous working capital lines of credit with ~~interest at the bank’s prime rate minus ¼~~Bank of ~~one percent.~~America. The ~~working capital loan~~Wells Fargo facility provides for ~~borrowings~~the issuance of up to $5$40 million of letters of credit to support the Company’s crude oil and natural gas marketing businesses based on ~~80 percent of~~the eligible accounts receivable ~~and 50 percent~~within those operations. Letters of eligible inventories. Available capacity under the line is calculated monthly and as of September 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 $5credit outstanding totaled $19.9 million as of September 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 September 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 $60,909,000. 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 $60 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 September 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 $34.5 million as of September 30, 2008.2009. The letter of credit ~~and demand note facilities are secured by substantially all of Gulfmark’s~~facility places certain restrictions on the Company’s Gulfmark Energy, Inc. and Adams Resources ~~Marketing’s (“ARM”) assets. Under this facility, BNP Paribas has~~Marketing, Ltd. subsidiaries. Such restrictions included the ~~right~~maintenance of a combined 1.1 to ~~discontinue~~1.0 current ratio and the ~~issuance~~maintenance of ~~letters of credit without prior notification to~~positive net earnings as defined among other restrictions. Management believes the ~~Company.~~Company is currently in compliance with all such covenants.

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 September 30, 2008. Letters of credit outstanding under this facility totaled approximately $4.6 million as of September 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~~There has been no material changes 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~~“Critical Accounting Policies and Use of Estimates” disclosures that have occurred since the ~~presentation of financial condition in three important ways.~~

Gross margins, derived from certain aspects of the Company’s ongoing business, are recorded in 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 the period of contract execution 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 and its insurance carrier have entered into a tolling agreement to temporarily set aside the claim pending resolution of the underlying matter. 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 asdisclosures provided in the ~~guidelines of Statement of Financial Accounting Standards No. 5, “Accounting~~Company’s Annual Report on Form 10-K for ~~Contingencies”.~~the year ended December 31, 2008.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

~~The Company is exposed~~There has been no material changes 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~~“Quantitative and Qualitative Disclosures about Market Risk” that have occurred since the ~~interest rate on~~disclosures provided in 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 September 30, 2008. A hypothetical 10 percent adverse change in the floating rate would not have had a material effectAnnual Report on ~~the Company’s results of operations~~Form 10-K for the ~~three-month period~~year ended ~~September 30,~~December 31, 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 September 30, 2008 average natural gas marketing segment sales price realizations ranged from a monthly low of $7.14 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. During October 2008, average crude oil prices for the month declined to approximately $70 per barrel. 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 $2,797,000 for the nine-month period ended September 30, 2008.

Forward-Looking ~~Statements—Safe~~Statements –Safe Harbor Provisions

This quarterly report for the period ended September 30, ~~2008~~2009 contains certain forward-looking statements ~~intended to be~~ covered by the safe harbors provided under Federal securities law and ~~regulation.~~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, ~~(b) Liquidity and Capital Resources, (c)~~(d) Critical Accounting Policies and Use of Estimates, ~~(d)~~(e) Quantitative and Qualitative Disclosures about Market Risk, ~~(e) Fair Value Measurements~~(f) Income Taxes, (g) Concentration of Credit Risk, (h) Price Risk Management Activities, and ~~(f)~~(i) Commitments and Contingencies, among others, contain forward-looking statements. Where the Company expresses an expectation or belief ofregarding future results orof 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~~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 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 Statementsdescribed in the ~~annual report~~Company’s Annual Report on Form 10-K for the year ended December 31, ~~2007.~~

~~Except for~~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 discussion set forth below, there have been no material changes to the risk factors disclosed in Item 1A of Part I in the annual report on Form 10-K for the year ended December 31, 2007. The risk factor set forth below has been updated to provide additional information.

~~Worldwide economic developments could damage operations and materially reduce profitability and cash flows.~~Company.

Recent disruptions in the credit markets and concerns about global economic growth have had a significant adverse impact on global financial markets and commodity prices, both of which may have contributed to a decline in the Company’s stock price and corresponding market capitalization. Further commodity price decreases in the fourth quarter could result in reduced earnings. Since the Company has no bank debt obligations nor covenants tied to its stock price, recent declines in the Company’s stock price do not affect the Company’s liquidity or overall financial condition. Should the capital and credit markets continue to experience volatility and the availability of funds remains limited, the Company’s customers and suppliers may incur increased costs associated with issuing commercial paper and/or other debt instruments and this, in turn, could adversely affect the Company’s ability to secure supply and make profitable sales.

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~~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 (as defined in Exchange Act Rule 13a-15(e)).~~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.~~effective as of September 30, 2009.

~~During the three month period ended September 30, 2008, there~~Changes in Internal Control over Financial Reporting.

There have not been any changes in the Company’s internal ~~controls~~control over financial reporting ~~(as defined in Rules 13a-13(f) and 15d-15(f) of~~during the ~~Exchange Act)~~fiscal quarter ended September 30, 2009 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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PART II. OTHER INFORMATION

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 and its insurance carrier have entered into a tolling agreement to temporarily set aside the claim pending resolution of the underlying matter. 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 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~~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, 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 ~~have been~~are no material changes in the Company’s risk factors from those disclosed in the ~~2007~~Company’s Annual Report on Form 10-K ~~except as follows:~~for the year ended December 31, 2008.

~~Worldwide economic developments could damage operations and materially reduce profitability and cash flows.~~

Item 2. - None

~~Item 2. - None~~

Item 3. - None

Item 4. - None

~~Item 5. –~~

Item 5.

- None

Item 6. Exhibits

4(b) - Credit and Security Agreement between Gulfmark Energy, Inc, Adams Resources Marketing, Ltd and Wells Fargo Bank, National Association dated August 27, 2009

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

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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: November 13, ~~2008~~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

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EXHIBIT INDEX

Exhibit
Number	Description
4(b)	Credit and Security Agreement between Gulfmark Energy, Inc, Adams Resources Marketing, Ltd and Wells Fargo Bank, National Association dated August 27, 2009

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

2621