Edgar Filing: ADAMS RESOURCES & ENERGY, INC.

form10q.htm

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D. C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2009

Commission File Number 1-7908

ADAMS RESOURCES & ENERGY, INC.

(Exact name of Registrant as specified in its charter)

Delaware		74-1753147
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

4400 Post Oak Pkwy Ste 2700 , Houston, Texas 77027

(Address of principal executive office & Zip Code)

Registrant's telephone number, including area code (713) 881-3600

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. YES x NO o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definition of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 126-2 of the Exchange Act. (Check one)

Large accelerated filer o Accelerated filer o Non-accelerated filer x Smaller Reporting Company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES o NO x

A total of 4,217,596 shares of Common Stock were outstanding at August 12, 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)

	Six Months Ended						Three Months Ended
	June 30,						June 30,
	2009			2008			2009			2008
REVENUES:
Marketing	$	828,619		$	2,201,820		$	501,507		$	1,256,183
Transportation		22,230			35,383			11,287			18,979
Oil and gas		4,362			9,137			2,276			5,190
		855,211			2,246,340			515,070			1,280,352
COSTS AND EXPENSES:
Marketing		814,991			2,189,169			494,033			1,248,250
Transportation		19,955			31,344			9,748			16,657
Oil and gas operations		3,463			4,201			2,028			2,775
General and administrative		4,694			5,420			2,384			2,503
Depreciation, depletion and amortization		4,980			6,072			2,549			3,034
		848,083			2,236,206			510,742			1,273,219

Operating earnings		7,128			10,134			4,328			7,133

Other income (expense):
Interest income		56			571			24			216
Interest expense		(8	)		(45	)		(2	)		(41	)
Earnings before income tax		7,176			10,660			4,350			7,308

Income tax provision		2,572			3,624			1,616			2,483

Net earnings	$	4,604		$	7,036		$	2,734		$	4,825

EARNINGS PER SHARE:
Basic and diluted net earnings per common share	$	1.09		$	1.67		$	.65		$	1.15


DIVIDENDS PER COMMON SHARE	$	-		$	-		$	-		$	-

The accompanying notes are an integral part of these financial statements.

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

	June 30,			December 31,
	2009			2008
ASSETS

Current assets:
Cash and cash equivalents	$	21,978		$	18,208
Accounts receivable, net of allowance for doubtful
Accounts of $1,303 and $1,251, respectively		149,544			119,401
Inventories		10,252			14,207
Fair value contracts		1,783			8,697
Income tax receivable		92			3,629
Prepayments and other		15,483			5,224

Total current assets		199,132			169,366

Property and equipment		124,275			118,863
Less – accumulated depreciation,
Depletion and amortization		(87,625	)		(83,277	)
		36,650			35,586
Other assets:
Fair value contracts		95			-
Deferred income tax asset		1,806			2,035
Cash deposits and other		3,769			3,939
	$	241,452		$	210,926

LIABILITIES AND SHAREHOLDERS’ EQUITY

Current liabilities:
Accounts payable	$	147,569		$	115,183
Accounts payable – related party		66			89
Fair value contracts		1,436			8,196
Accrued and other liabilities		3,855			3,930
Current deferred income taxes		672			409
Total current liabilities		153,598			127,807

Other liabilities:
Fair value contracts		92			-
Asset retirement obligations		1,309			1,260
Other long-term		88			98
		155,087			129,165
Commitments and contingencies (Note 5)

Shareholders’ equity:
Preferred stock - $1.00 par value, 960,000 shares
authorized, none outstanding		-			-
Common stock - $.10 par value, 7,500,000 shares
authorized, 4,217,596 shares outstanding		422			422
Contributed capital		11,693			11,693
Retained earnings		74,250			69,646
Total shareholders’ equity		86,365			81,761
	$	241,452		$	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)

	Six Months Ended
	June 30,
	2009			2008
CASH PROVIDED BY OPERATIONS:
Net earnings	$	4,604		$	7,036
Adjustments to reconcile net earnings to net cash
provided by operating activities -
Depreciation, depletion and amortization		4,980			6,072
Gains on property sales		(58	)		(15	)
Dry hole costs incurred		305			669
Impairment on oil and gas properties		896			872
Provision for doubtful accounts		52			528
Deferred income taxes		492			(744	)
Net change in fair value contracts		151			(189	)
Other, net		239			(178	)
Decrease (increase) in accounts receivable		(30,195	)		(115,017	)
Decrease (increase) in inventories		3,955			(9,696	)
Decrease (increase) in income tax receivable		3,537			2,540
Decrease (increase) in prepayments		(10,259	)		(172	)
Increase (decrease) in accounts payable		32,372			114,253
Increase (decrease) in accrued liabilities		(75	)		2,047

Net cash provided by operating activities		10,996			8,006

INVESTING ACTIVITIES:
Property and equipment additions		(7,280	)		(9,595	)
Insurance and excise tax refunds		(30	)		529
Proceeds from property sales		84			39
Redemption of short-term investments		-			10,000
Investment in short-term investments		-			(10,000	)

Net cash (used in) investing activities		(7,226	)		(9,027	)

Increase (decrease) in cash and cash equivalents		3,770			(1,021	)

Cash at beginning of period		18,208			23,697

C Cash at end of period	$	21,978		$	22,676

The accompanying notes are an integral part of these financial statements.

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED

CONSOLIDATED FINANCIAL STATEMENTS

Note 1 - Basis of Presentation

The accompanying condensed consolidated financial statements are unaudited but, in the opinion of the Company's management, include all adjustments (consisting of normal recurring accruals) necessary for the fair presentation of its financial position at June 30, 2009, its results of operations for the three and six-month periods ended June 30, 2009 and 2008 and its cash flows for the six months ended June 30, 2009 and 2008. Certain information and note disclosures normally included in annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted pursuant to Securities and Exchange Commission rules and regulations. The impact on the accompanying financial statements of events occurring after June 30, 2009 has been evaluated through August 12, 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 Company is engaged in the business of crude oil, natural gas and petroleum products marketing, as well as tank truck transportation of liquid chemicals and oil and gas exploration and production. Its primary area of operation is within a 1,000 mile radius of Houston, Texas. The accompanying consolidated financial statements include the accounts of Adams Resources & Energy, Inc., a Delaware corporation, and its wholly owned subsidiaries (the "Company") after elimination of all significant intercompany accounts and transactions. In order to conform to current year presentations, certain reclassifications have been made to prior year amounts in the Statement of Cash Flows under “Provision for Doubtful Accounts”.

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market funds or federal funds with maturity of 90 days or less. Depending on cash availability and market conditions, investments in municipal bonds may also be made from time to time. The Company invests in tax-free municipal securities in order to enhance the after-tax rate of return from short-term investments of cash.

Inventories

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

	June 30,		December 31,
	2009		2008
Crude oil	$	8,444	$	11,710
Petroleum products		1,808		2,497

	$	10,252	$	14,207

Prepayments

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

	June 30,		December 31,
	2009		2008

Cash collateral deposits for commodity purchases	$	10,243	$	2,082
Insurance premiums		2,559		1,985
Natural gas pipeline imbalances		2,271		369
Rents, license and other		410		788

	$	15,483	$	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 costs of drilling the well are charged to expense. Costs incurred to drill and complete development wells, including dry holes, are capitalized. As of June 30, 2009, the Company had no unevaluated or suspended exploratory drilling costs.

Producing oil and gas leases, equipment and intangible drilling costs are depleted or amortized over the estimated proved reserves using the units-of-production method. Other property and equipment is depreciated using the straight-line method over the estimated average useful lives of three to fifteen years for marketing, three to fifteen years for transportation and ten to twenty years for all others.

The Company periodically reviews its long-lived assets for impairment whenever there is evidence that the carrying value of such assets may not be recoverable. 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 six-month periods ended June 30, 2009 and 2008 there were $222,000 and zero impairment provisions on producing oil and gas properties, respectively. Such provisions also totaled $222,000 and zero for the three-month periods ended June 30, 2009 and 2008, respectively.

On a quarterly basis, management also evaluates the carrying value of non-producing oil and gas properties and may deem them impaired for lack of drilling activity. Accordingly, impairment provisions on non-producing properties totaling $674,000 and $872,000 were recorded for the six-month periods ended June 30, 2009 and 2008, respectively. Such provisions totaled $550,000 and $674,000 for the three-month periods ended June 2009 and June 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.

Fair value measurements for oil and gas properties for the six-month period ended June 30, 2009 summarize as follows (in thousands):

Fair Value Measurements Using

Net Book

Quoted Prices

Significant

Value

In Active

Observable

Unobservable

June 30,

Markets

Inputs

Total

2009

(Level 1)

(Level 2)

(Level 3)

Losses

Producing Properties

13,068

222

Cash deposits and other assets

The Company has established certain deposits to support its participation in its liability insurance program and remittance of state crude oil severance taxes and other state collateral deposits. In addition, the Company has accounts and notes receivable from certain customers that are expected to be collected over a long-term period. Components of cash deposits and other assets are as follows (in thousands):

	June 30,		December 31,
	2009		2008
Insurance collateral deposits	$	2,825	$	2,794
State collateral deposits		278		279
Accounts and notes receivable		319		503
Materials and supplies		347		363
	$	3,769	$	3,939

Revenue Recognition

Commodity purchase and sale contracts utilized by the Company’s marketing businesses qualify as derivative instruments. Further, all natural gas, as well as certain specifically identified crude oil purchase and sale contracts, are designated as trading activities. From the time of contract origination, such trading activity contracts are marked-to-market and recorded on a net revenue basis in the accompanying financial 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 methodology. For normal purchase and sale activities, the Company’s customers are invoiced monthly based upon contractually agreed upon terms and revenue is recognized in the month in which the physical product is delivered to the customer. Such sales are recorded gross in the financial statements because the 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 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 different locations. These contracts are entered into for a variety of reasons, including effecting the transportation of the commodity, to minimize credit exposure, and/or to meet the competitive demands of the customer. 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.

Statement of Cash Flows

Interest paid totaled $8,000 and $45,000 during the six-month periods ended June 30, 2009 and 2008, respectively. Income taxes paid during these same periods totaled $162,000 and $270,000, respectively. The Company also received a $2,000,000 income tax refund during the first six months of 2009. Non-cash investing activities for property and equipment in accounts payable were $524,000 and $124,000 as of June 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

Earnings per share are based on the weighted average number of shares of common stock and potentially dilutive common stock shares outstanding during the period. The weighted average number of shares outstanding was 4,217,596 for 2009 and 2008. There were no potentially dilutive securities during those periods.

Share-Based Payments

During the periods presented herein, the Company had no stock-based employee compensation plans, nor any other share-based payment arrangements.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Examples of significant estimates used in the accompanying consolidated financial statements include the accounting for depreciation, depletion and amortization, revenue accruals, oil and gas property impairments, the provision for bad debts, insurance related accruals, income taxes, contingencies and valuation of fair value contracts.

Use of derivative instruments

The Company’s marketing segment is involved in the purchase and sale of crude oil and natural gas. The Company seeks to make a profit by procuring such commodities as they are produced and then delivering such products to the end use or intermediate use marketplace. As is typical for the industry, such transactions are made pursuant to the terms of forward month commodity purchase and/or sale contracts. These contracts meet the definition of a derivative instrument and therefore, the Company accounts for such contracts at fair value, unless the normal purchase and sale exception is applicable. 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 June 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	$	2,883		$	95	$	-		$	-

Liability Derivatives
- Fair Value Commodity
Contracts at Gross Valuation		-			-		2,536			92

Less Counterparty Offsets		(1,100	)		-		(1,100	)		-

As Reported Fair Value Contracts	$	1,783		$	95	$	1,436		$	92

The Company only enters into commodity contracts with credit worthy counterparties or obtains collateral support for such activities. No credit loss provision has been applied to the Company’s forward commodity contract valuations and the Company currently holds no collateral from its counterparties. The Company has, however, posted margin collateral in support of certain commodity contracts. Such cash collateral held by the Company’s counterparties totaled $10,243,000 as of June 30, 2009. 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 six months ended June 30, 2009 as follows (in thousands):

	Statement of Operations
	Location	(Loss)

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

The impact of commodity contracts on revenues for the six months ended June 30, 2009 is a loss of $151,000. Such 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 June 30, 2009 as follows (in thousands):

	Statement of Operations
	Location	(Loss)

- Fair value commodity contracts	Revenues - marketing	$	(293	)

Fair Value Measurements

The carrying amount reported in the 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 and 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 during any current reporting periods.

Fair value estimates are based on assumptions that market participants would use when pricing an asset or liability and 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 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.

As of June 30, 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	$	424	$	1,359		$	-	$	1,783
- Long-term assets		-		95			-		95
- Current liabilities				(1,436	)		-		(1,436	)
- Long-term liabilities		-		(92	)		-		(92	)
Net Value	$	424	$	(74	)	$	-	$	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 utilize Level 3 inputs, such as credit scores to evaluate the likelihood of default by the Company or its counterparties. As of June 30, 2009, credit valuation adjustments were not significant to the overall valuation of the Company’s fair value contracts. As a result, applicable fair value assets and liabilities in their entirety are classified in Level 2 of the fair value hierarchy.

New Accounting Pronouncements

In December 2008, the Securities and Exchange Commission released Final Rule, Modernization of Oil and Gas Reporting to revise the existing Regulation S-K and Regulation S-X reporting requirements to align with current industry practices and technological advances. The new disclosure requirements include provisions that permit the use of new technologies to determine proved reserves if those technologies have been demonstrated empirically to lead to reliable conclusions about reserve volumes. In addition, the new disclosure requirements require a company to (a) disclose its internal control over reserves estimation and report the independence and qualification of its reserves preparer or auditor, (b) file reports when a third party is relied upon to prepare reserves estimates or conducts a reserve audit and (c) report oil and gas reserves using an average price based upon the prior 12-month period rather than period-end prices. The disclosures required by this ruling will become effective for the Company’s Annual Report on Form 10-K for the year ended December 31, 2009.

In April 2009, the FASB issued FASB Staff Position No. 157-4, “Determining Fair Value When the Volume and Level of Activity for the Asset or Liability have Significantly Decreased and Identifying Transactions that are not Orderly,” (“FSP No. FAS 157-4”). FSP No. FAS 157-4 provides additional guidance for estimating fair value under FAS No. 157 when the volume and level of market activity for an asset or liability have significantly decreased when compared with normal market activity for the asset or liability. If there is a significant decrease in the volume and activity for the asset or liability, transactions or quoted prices may not be determinative of fair value in an orderly transaction and further analysis and adjustment of the transactions or quoted prices may be necessary. FSP No. FAS 157-4 was effective for the quarter ended June 30, 2009 and the Company did not recognize any significant adjustments to its estimates of fair value for assets and liabilities measured at fair value upon adoption.

In April 2009, the FASB issued FASB Staff Position No. FAS 107-1 and APB 28-1, “Interim Disclosures about Fair Value of Financial Instruments,” (“FSP No. FAS 107-1 and APB 28-1”). FSP No. FAS 107-1 and APB 28-1 amends SFAS No. 107, “Disclosures about Fair Value of Financial Instruments” to require disclosures about the fair value of financial instruments for interim reporting periods. FSP No. FAS 107-1 and APB 28-1 is effective for the quarter ended June 30, 2009 and the required disclosures are included in these interim financial statements.

During the second quarter of 2009, the Company adopted the provisions of SFAS No. 165, “Subsequent Events” (“SFAS 165”). The standard clarifies that management must evaluate, as of each reporting period, events or transactions that occur after the balance sheet date through the date that the financial statements are issued and disclose the date through which subsequent events have been evaluated.

On June 30, 2009, FASB issued FASB Statement No. 168, “The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles – a replacement of FASB Statement No. 162.” This statement is effective for financial statements issued for interim and annual periods ending after September 15, 2009. On the effective date of this standard, FASB Accounting Standards Codification (ASC) will become the source of authoritative U.S. accounting and reporting standards for nongovernmental entities, in addition to guidance issued by the Securities and Exchange Commission (SEC). The Company does not expect the adoption of SFAS No. 168 to have any impact on its statements of financial position, results of operations, or cash flows.

Note 3 – Segment Reporting

The Company is primarily engaged in the business of marketing crude oil, natural gas and petroleum products; tank truck transportation of liquid chemicals; and oil and gas exploration and production. Information concerning the Company’s various business activities is summarized as follows (in thousands):

- Six Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended June 30, 2009
Marketing
- Crude Oil	$	773,111	$	9,843		$	1,031	$	650
- Natural gas		7,198		2,005			83		-
- Refined products		48,310		399			267		177
Marketing Total		828,619		12,247			1,381		827
Transportation		22,230		434			1,841		1,793
Oil and gas		4,362		(859	)		1,758		4,660
	$	855,211	$	11,822		$	4,980	$	7,280
Period Ended June 30, 2008
Marketing
- Crude Oil	$	2,083,642	$	11,234		$	902	$	4,627
- Natural gas		6,004		1,282			81		-
- Refined products		112,174		(1,142	)		294		79
Marketing Total		2,201,820		11,374			1,277		4,706
Transportation		35,383		2,131			1,908		397
Oil and gas		9,137		2,049			2,887		4,481
	$	2,246,340	$	15,554		$	6,072	$	9,584

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended June 30, 2009
Marketing
- Crude Oil	$	472,658	$	6,012		$	502	$	-
- Natural gas		3,291		653			42		-
- Refined products		25,558		134			131		40
Marketing Total		501,507		6,799			675		40
Transportation		11,287		612			927		649
Oil and gas		2,276		(699	)		947		1,684
	$	515,070	$	6,712		$	2,549	$	2,373
Period Ended June 30, 2008
Marketing
- Crude Oil	$	1,188,230	$	6,949		$	573	$	258
- Natural gas		3,144		750			41		-
- Refined products		64,809		(527	)		147		18
Marketing Total		1,256,183		7,172			761		276
Transportation		18,979		1,371			951		47
Oil and gas		5,190		1,093			1,322		2,376
	$	1,280,352	$	9,636		$	3,034	$	2,699

Segment operating earnings reflect revenues net of operating costs and depreciation, depletion and amortization. Segment earnings reconcile to earnings from continuing operations before income taxes as follows (in thousands):

	Six months ended						Three months ended
	June 30,						June 30,
	2009			2008			2009			2008
Segment operating earnings	$	11,822		$	15,554		$	6,712		$	9,636
- General and administrative		(4,694	)		(5,420	)		(2,384	)		(2,503	)
Operating earnings		7,128			10,134			4,328			7,133
- Interest income		56			571			24			216
- Interest expense		(8	)		(45	)		(2	)		(41	)
Earnings before income taxes	$	7,176		$	10,660		$	4,350		$	7,308

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

	June 30,		December 31,
	2009		2008
Marketing
- Crude oil	$	131,004	$	85,774
- Natural gas		36,083		46,599
- Refined products		10,402		13,037
Marketing Total		177,489		145,410
Transportation		13,768		14,915
Oil and gas		22,872		21,904
Other		29,323		28,697
	$	243,452	$	210,926

Intersegment 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 half of 2009 and 2008, the Company’s investment commitments totaled approximately $1.4 million and $3 million, respectively, in those oil and gas projects where a related party was also participating in such investments. As of June 30, 2009 and December 31, 2008, the Company owed a combined net total of $66,000 and $89,000, respectively, to these related parties. In connection with the operation of certain oil and gas properties, the Company also charges such related parties for administrative overhead primarily as prescribed by the Council of Petroleum Accountants Society (“COPAS”) Bulletin 5. Such overhead recoveries totaled $71,000 and $66,000 in the six-month periods ended June 30, 2009 and 2008, respectively.

The Company also enters into certain transactions in the normal course of business with other affiliated entities including direct cost reimbursement for shared phone and secretarial services. For the six-month period ended June 30, 2009 and 2008, the affiliated entities charged the Company $27,000 and $33,000, respectively, of expense reimbursement and the Company charged the affiliates $33,000 and $48,000, respectively, for such expense reimbursements.

Note 5 - Commitments and Contingencies

The Company has entered into a commitment letter to provide for a Credit and Security Agreement with Wells Fargo to provide a $40 million letter of credit facility. Pursuant to finalization of the Wells Fargo agreement, the Company will discontinue its present unused working capital lines of credit with Bank of America. The Wells Fargo facility will provide 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. The letter of credit facility will place 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. The Credit and Security Agreement is expected to be completed during August 2009.

Under certain of the Company’s automobile and workers compensation insurance policies, the Company can either receive a return of premium paid or be assessed for additional premiums up to pre-established limits. Additionally, in certain instances the risk of insured losses is shared with a group of similarly situated entities. As of June 30, 2009, management has appropriately recognized estimated expenses and liabilities related to the program. Estimated loss accruals for potentially unknown losses are developed using actual loss histories and other relevant information.

From time to time as incidental to its operations, the Company becomes involved in various lawsuits and/or disputes. Primarily as an operator of an extensive trucking fleet, the Company is a party to motor vehicle accidents, worker compensation claims and other items of general liability as would be typical for the industry. Management of the Company is presently unaware of any claims against the Company that are either outside the scope of insurance coverage, or that may exceed the level of insurance coverage, and could potentially represent a material adverse effect on the Company’s financial position or results of operations.

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

Results of Operations

Marketing

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

	Six Months Ended					Three Months Ended
	June 30,					June 30,
	2009		2008			2009		2008
Revenues
Crude oil	$	773,111	$	2,083,642		$	472,658	$	1,188,230
Natural gas		7,198		6,004			3,291		3,144
Refined products		48,310		112,174			25,558		64,809
Total	$	828,619	$	2,201,820		$	501,507	$	1,256,183

Operating Earnings (loss)
Crude oil	$	9,843	$	11,234		$	6,012	$	6,949
Natural gas		2,005		1,282			653		750
Refined products		399		(1,142	)		134		(527	)
Total	$	12,247	$	11,374		$	6,799	$	7,172

Depreciation
Crude oil	$	1,031	$	902		$	502	$	573
Natural gas		83		81			42		41
Refined products		267		294			131		147
Total	$	1,381	$	1,277		$	675	$	761

Supplemental volume and price information is as follows:

	Six Months Ended				Three Months Ended
	June 30,				June 30,
	2009		2008		2009		2008
Field Level Purchase Volumes – Per day (1)
Crude oil – barrels		67,271		64,700		66,000		66,000
Natural gas – mmbtu’s		390,000		447,000		390,000		435,000

Average Purchase Price
Crude oil – per barrel	$	47.20	$	114.14	$	56.44	$	127.90
Natural Gas – per mmbtu’s	$	3.88	$	9.37	$	3.41	$	10.56

_____________________________

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

Crude oil revenues were reduced for the comparative current period because of significantly lower average crude oil prices as shown in the table above. While overall first half 2009 crude oil prices were reduced, the direction of change in prices was generally increasing during the 2009 period. The average acquisition price of crude oil moved from the $41 per barrel level at the beginning of the year to $64 per barrel for the June 2009 average price. This event produced a first half 2009 inventory liquidation gain of $4,063,000. A similar event occurred in the first half of 2008 as crude oil prices rose from the $90 per barrel range in January 2008 to the $133 per barrel range in June 2008 producing a $5,878,000 inventory liquidation gain. As of June 30, 2009 the Company held 132,319 barrels of crude oil inventory at an average price of $63.81 per barrel.

Natural gas sales are reported net of underlying natural gas purchase costs and thus reflect gross margin. As shown above, such margins were consistent between the periods.

Last year’s refined products segment operating loss occurred because the rate of increase in the crude oil driven supply cost of motor fuel exceeded the rate of increase in the market value of such fuels. As a result, per unit margins narrowed and did not cover fixed operating expenses. Also, the Company’s supplier of biodiesel fuel failed to deliver scheduled product resulting in a direct loss to the Company of approximately $400,000. The product was contracted to the Company at a fixed price and the Company had entered into an offsetting price protection agreement (a swap). Although the underlying material did not ship as scheduled, the Company honored its swap commitment producing the resulting loss. Subsequently, the Company has revised the terms of its biodiesel fuel supply contracts to shift the price risk to the supplier in order to avoid the recurrence of such items.

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

- Transportation

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

	Six Months Ended							Three Months Ended
	June 30,				Increase			June 30,				Increase
	2009		2008		(Decrease)			2009		2008		(Decrease)

Revenues	$	22,230	$	35,383		(37.2	)%	$	11,287	$	18,979		(40.5	)%

Operating earnings	$	434	$	2,131		(79.6	)%	$	612	$	1,371		(55.4	)%

Depreciation	$	1,841	$	1,908		(3.5	)%	$	927	$	951		(2.5	)%

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 few signs of recovery. Typically, as revenues decline, operating earnings decline at a faster rate, as measured by percentage, due to the 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 for the second quarter of 2009.

- Oil and Gas

Oil and gas segment revenues and operating earnings are primarily a function of crude oil and natural gas prices and volumes. Comparative amounts for revenues, operating earnings and depreciation and depletion are as follows (in thousands):

	Six Months Ended								Three Months Ended
	June 30,					Increase			June 30,					Increase
	2009			2008		(Decrease)			2009			2008		(Decrease)
Revenues	$	4,362		$	9,137		(52.3	)%	$	2,276		$	5,190		(56.1	)%

Operating earnings (loss)	$	(859	)	$	2,049		(142.9	)%		(699	)		1,093		(163.9	)%

Depreciation and depletion	$	1,758		$	2,887		(39.1	)%	$	947		$	1,322		(28.4	)%

The revenue and earnings decline for the oil and gas segment is attributable to decreased crude oil and natural gas prices as shown in the tables below. Depreciation and depletion expense is reduced in the current period because a significant decline in hydrocarbon prices at year-end December 31, 2008 caused significant impairment provisions to be recorded. Such charges reduced the level of capitalized costs for amortizing in the current period.

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

	Six Months Ended				Three Months Ended
	June 30,				June 30,
	2009		2008		2009		2008
Crude Oil
Volume – barrels		27,627		25,710		13,365		13,743
Average price per barrel	$	49.35	$	112.54	$	59.73	$	122.91

Natural gas
Volume – mcf		665,900		588,700		336,100		301,000
Average price per mcf	$	4.50	$	10.61	$	4.39	$	11.61

Comparative exploration costs were as follows (in thousands):

	Six Months Ended				Three Months Ended
	June 30,				June 30,
	2009		2008		2009		2008
Dry hole expense	$	305	$	669	$	81	$	579
Prospect impairments		896		872		772		675
Seismic and geological		504		522		319		349

Total	$	1,705	$	2,063	$	1,172	$	1,603

During the first six months of 2009, the Company participated in the drilling of 17 successful wells with four dry holes. Additionally, the Company has an interest in ten wells that were in process on June 30, 2009. Evaluation on the in-process wells is anticipated during the third quarter of 2009. Participation in the drilling of approximately 10 wells is planned for the remainder of 2009 on the Company’s prospect acreage in Arkansas, Louisiana and Texas.

- Outlook

The current softness in natural gas prices has suppressed earnings from oil and gas operations and the current national economy continues to curtail transportation demand. The Company’s crude oil and natural gas marketing businesses, however, have remained stable and profitable. Overall, management continues to forecast steady results for the remainder of the year.

Liquidity and Capital Resources

The Company’s liquidity primarily derives from net cash provided by operating activities and such amount was $10,996,000 and $8,006,000 for each of the six-month periods ended June 30, 2009 and 2008, respectively. As of June 30, 2009 and December 31, 2008, the Company had no bank debt or other forms of debenture obligations. Cash and cash equivalents totaled $21,978,000 as of June 30, 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 $10,243,000 as of June 30, 2009 and such amounts will be recouped during the current third quarter. Working capital, the excess of current assets over current liabilities, totaled $45,285,000 as of June 30, 2009. Management believes current cash balances, together with expected cash generated from future operations, will be sufficient to meet short-term and long-term liquidity needs.

The Company utilizes cash from operations to make discretionary investments in its oil and natural gas exploration, marketing and transportation businesses, which comprise substantially all of the Company’s investing cash outflows for each of the past three years. The Company does not look to proceeds from property sales to fund its cash flow needs. Except for a total of $2.8 million in operating lease payments for transportation equipment and office lease space, the Company’s future commitments and planned investments can be readily curtailed if operating cash flows contract.

Capital expenditures during the first six months of 2009 included $2,620,000 for marketing and transportation equipment additions and $4,660,000 in property additions associated with oil and gas exploration and production activities. For 2009, the Company anticipates expending an additional approximate $7.5 million on oil and gas exploration projects to be funded from operating cash flow and available working capital. In addition, approximately $1.5 million will be expended during the second half of 2009 toward the purchase of 80 tractors scheduled to come off lease financing with funding for such purchase from available cash flow.

Historically, the Company pays an annual dividend in the fourth quarter of each year, and the Company last paid a $.50 per common share or $2,109,000 dividend to shareholders of record as of December 2, 2008. The most significant item affecting future increases or decreases in liquidity is earnings from operations and such earnings are dependent on the success of future operations (see Item 1A Risk Factors in the annual report on Form 10-K for the year ended December 31, 2008). While the Company has available bank lines of credit (see below), management has no current intention to utilize such lines of credit or issue additional equity.

- Banking Relationships

The Company’s primary bank loan agreement with Bank of America provides for two separate lines of credit with interest at the bank’s prime rate minus ¼ of one percent. The working capital loan provides for borrowings based on 80 percent of eligible accounts receivable and 50 percent of eligible inventories. Available capacity under the line is calculated monthly and as of June 30, 2009 the Company elected to establish the line at $5 million. The oil and gas production loan provides for flexible borrowings subject to a borrowing base requested by the Company and approved semi-annually by the bank. The borrowing base was established at $5 million as of June 30, 2009. The working capital facilities are subject to a ½ of one percent commitment fee. The line of credit loans are scheduled to expire on October 31, 2009, with the then present balance outstanding, if any, converting to a term loan payable in eight equal quarterly installments. As of June 30, 2009 and December 31, 2008 there was no bank debt outstanding under the Company’s two revolving credit facilities.

The Company has entered into a commitment letter to provide for a Credit and Security Agreement with Wells Fargo Bank to provide a $40 million letter of credit facility. Pursuant to finalization of the Wells Fargo agreement, the Company will discontinue its present unused working capital lines of credit with Bank of America. The Wells Fargo facility will provide 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. The letter of credit facility will place 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. The Credit and Security Agreement is expected to be completed during August 2009.

Critical Accounting Policies and Use of Estimates

There has been no material changes to the Company’s “Critical Accounting Policies and Use of Estimates” disclosures that have occurred since the disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

There has been no material changes to the Company’s “Quantitative and Qualitative Disclosures about Market Risk” that have occurred since the disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008.

Forward-Looking Statements –Safe Harbor Provisions

This quarterly report for the period ended June 30, 2009 contains certain forward-looking statements covered by the safe harbors provided under Federal securities law and regulations. To the extent such statements are not recitations of historical fact, forward-looking statements involve risks and uncertainties. In particular, statements included herein and/or in the Company’s latest annual report on Form 10-K under the captions (a) Production and Reserve Information, (b) Regulatory Status and Potential Environmental Liability, (c) Management’s Discussion and Analysis of Financial Condition and Results of Operations, (d) Critical Accounting Policies and Use of Estimates, (e) Quantitative and Qualitative Disclosures about Market Risk, (f) Income Taxes, (g) Concentration of Credit Risk, (h) Price Risk Management Activities, and (i) Commitments and Contingencies, among others, contain forward-looking statements. Where the Company expresses an expectation or belief regarding future results of events, such expression is made in good faith and believed to have a reasonable basis in fact. However, there can be no assurance that such expectation or belief will actually result or be achieved.

With the uncertainties of forward looking statements in mind, the reader should consider the risks discussed elsewhere in this report and other documents filed with the Securities and Exchange Commission from time to time and the important factors described in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008, under “Item 1A Risk Factor” that could cause actual results to differ materially from those expressed in any forward-looking statement made by or on behalf of the Company

Item 4. Disclosure Controls and Procedures

The Company maintains “disclosure controls and procedures” (as defined in Rule 13a-15(e) and 15d-15(e) under the Securities and Exchange Act of 1934, as amended (the “Exchange Act”), that are designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Exchange Act are recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely discussions regarding required disclosure. As of the end of the period covered by this quarterly report, an evaluation was carried out under the supervision and with the participation of the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based upon that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that the design and operation of these disclosure controls and procedures were effective as of June 30, 2009.

Changes in Internal Control over Financial Reporting.

There have not been any changes in the Company’s internal control over financial reporting during the fiscal quarter ended June 30, 2009 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1.

From time to time as incident to its operations, the Company becomes involved in various lawsuits and/or disputes. Primarily as an operator of an extensive trucking fleet, the Company may be a party to motor vehicle accidents, worker compensation claims or other items of general liability as would be typical for the industry. 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 are no material changes in the Company’s risk factors from those disclosed in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008.

Item 2. - None

Item 3. - None

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

On May 27, 2009, the Company held its annual meeting of shareholders, at which five directors were elected. The vote totals were as follows:

Director	Votes For		Votes Withheld		Non-Voted
K. S. Adams, Jr.		3,898,065		126,450		193,081
F. T. Webster		3,803,726		220,789		193,081
E. C. Reinauer, Jr.		3,824,338		200,177		193,081
E. J. Webster, Jr.		3,919,260		105,255		197,081
Larry E. Bell		3,920,415		104,100		197,081

Item 5. – None

Item 6. Exhibits

31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	ADAMS RESOURCES & ENERGY, INC
	(Registrant)



Date: August 12, 2009	By /s/K. S. Adams, Jr.
	K. S. Adams, Jr.
	Chief Executive Officer


	By /s/Frank T. Webster
	Frank T. Webster
	President & Chief Operating Officer


	By /s/Richard B. Abshire
	Richard B. Abshire
	Chief Financial Officer

EXHIBIT INDEX

Exhibit
Number	Description

31.1	Certificate of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2	Certificate of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1	Certificate of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2	Certificate of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002